An adapter clamp system for use with a housing of a wellhead includes a clamp assembly configured to apply radial compression to a housing of a wellhead. The adapter clamp system also includes an adapter configured to actuate the clamp assembly to apply the radial compression to the housing of the wellhead, wherein the adapter is configured to couple the housing of the wellhead to another structure stacked axially relative to the wellhead.
A method may include acquiring raw seismic data, computing event location and corresponding P and S wave arrivals, automatically obtaining polarity of the corresponding P and S waves arrivals, measuring fit of P and S wave polarity to a model to obtain a group of accepted solutions, analyzing distribution of the accepted solutions in the model, and identifying a best solution as a focal mechanism.
A method includes receiving input data from external data sources. The input data is received by a data product pipeline. The method also includes extracting a portion of the input data using the data product pipeline to produce extracted data. The method also includes transferring the extracted data from the data product pipeline to a data product raw storage. The method also includes receiving the input data directly from the external data sources. The method also includes transferring the extracted data and the input data from the data product raw storage back to the data product pipeline. The method also includes receiving data products. The method also includes transforming the input data, the extracted data, and the data products into transformed data using the data product pipeline. The method also includes transferring the transformed data to a data product artifact storage.
Embodiments presented provide for stress testing of downhole wireline formation testing equipment. Certain embodiments provide for stress testing of geological stratum which exhibit high permeability.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 33/124 - Units with longitudinally-spaced plugs for isolating the intermediate space
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
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 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.
An apparatus for a rotating packed bed reactor (RPB) that may be used to increase the mass-transfer rate between materials, such as a gas and a liquid, through the RPB. The rotor of the RPB may be rotatably driven within a housing at least in part by the direction of a gas in a tangential direction relative to an outer circumferential surface of the rotor. An RPB may include a housing having a gas inlet, a liquid inlet, a gas outlet, and a liquid outlet. The rotor includes a permeable packing configured to facilitate contact between the liquid and the gas passing through the permeable packing while the rotor rotates with respect to the housing. The gas inlet is configured to direct the gas tangentially with respect to the outer circumferential surface of the rotor to thereby cause the rotor to rotate with respect to the housing.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 53/34 - Chemical or biological purification of waste gases
A downhole tool configured to be located in a wellbore traversing a formation to obtain a formation fluid sample. In some embodiments, the downhole tool can include one or more fluid intake ports configured to receive a formation fluid and a fluid monitor that can be configured to measure one or more formation fluid properties of the received formation fluid. The at least one of the one or more fluid intake ports can be in an open position. The one or more fluid intake ports can be in the open position for a first period of time (t) such that the one or more fluid intake ports are configured to obtain formation fluid located at a first distance from the sidewall of the wellbore within the formation.
A method and apparatus to quickly identify defects in a cable used in hydrocarbon recovery wireline operations. A series of high-speed cameras take pictures along a length of the wireline cable, while artificial intelligence data processing algorithms process the camera data.
A parameter roadmap system receiving reference wellbore data including drilling parameter data for one or more reference wellbores and selects a segmentation parameter set and associated segmentation parameter data from the reference wellbore data. Based on the segmentation parameter data, the parameter roadmap system segments the reference wellbore data into a plurality of depth segments using a statistical segmentation model. The parameter roadmap system identifies a segment threshold for each drilling parameter of the reference wellbore data at each of the plurality of depth segments to generate a drilling parameter roadmap and provides the roadmap for forming a target wellbore.
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 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
10.
COMMUNICATION METHOD FOR UNTETHERED DOWNHOLE SYSTEMS
The disclosure provides methods of communication for untethered systems. The method includes defining a window for sampling a torque-related current and a modulator rotor relative position-related parameter; using the defined window, recording local maximum and local minimum values of the torque-related current versus a modulator rotor relative position-related parameter of a rotor of a rotary pulser system in the untethered system; identifying at least one of consecutive torque-related current minimum values and consecutive torque-related current maximum values based on a periodicity; computing an absolute modulator rotor position based on the periodic maxima and minima of the torque-related current; and controlling the modulator rotor using the absolute modulator rotor position to modulate uplink signals to a surface environment.
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
11.
SYSTEMS AND METHODS FOR INTEGRATION OF GENERATIVE ARTIFICIAL INTELLIGENCE FOR REPORTS AND ACTIONS
A tangible, non-transitory, computer-readable medium comprising instructions that, when executed by processing circuitry, are configured to cause the processing circuitry to retrieve one or more sets of data, transmit the one or more sets of data to an artificial intelligence (AI) model, transmit at least one instruction to the AI model to elicit summarization of one or more sets of data into a summarized one or more subsets of data, selectively extract portions of the one or more subsets of data based on a pre-determined criteria, and generate a report of one or more extracted subsets of data and/or action by the AI model based on at least one instruction of one or more sets of data.
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
A system and method that includes the use, over both space and time domains, of a single pair source-receiver to map in a focused manner at a very low operational and processing cost, the change in ‘fluid’ content at a specific location. The source-receiver may include multiple embodiments including a single source with multiple receivers, multiple sources with multiple receivers, or multiple sources with a single receiver.
A method of depressurizing a volume of trapped CO2. The method including injecting displacement fluid in a closed system to displace the volume of trapped CO2 and releasing the trapped CO2 out of the trapped system through a depressurization line while maintaining pressure in the closed system above a CO2 saturation pressure.
Methods and apparatus for treatment of solids containing hydrocarbon are described herein. The solids are treated by adding a cavitation cleaner to the stream; introducing the stream, with the cavitation cleaner, to a cavitation unit; and separating oil from the solids using a cavitation process within the cavitation unit.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B08B 3/08 - Cleaning involving contact with liquid the liquid having chemical or dissolving effect
B08B 7/02 - Cleaning by methods not provided for in a single other subclass or a single group in this subclass by distortion, beating, or vibration of the surface to be cleaned
15.
SETTABLE SCAVENGER SPACER FLUID FOR DISPLACING DRILLING MUD
Described herein are settable spacer fluids and methods of making and using such fluids. The settable spacer fluids generally contain a polymerizable raw material and activator in aqueous medium, where the spacer fluid is configured to have density sufficient to displace fluids within a well and to solidify after a duration sufficient to allow use of the spacer fluid to aid in well development and placement of the spacer fluid at a target location prior to significant transformation. The spacer fluid solidifies over time, but can be used with final compressive strength as low as 50 psi.
C09K 8/40 - Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/44 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing organic binders only
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 33/138 - Plastering the borehole wallInjecting into the formation
A system for, and method of, drill deviation handling within a stand while drilling a wellbore are presented. The techniques include: receiving, by an electronic processor and during a stand, drill state data; comparing, by the electronic processor and during the stand, the drill state data to an active drill plan; detecting, by the electronic processor and based on the comparing, an out-of-tolerance deviation of a drill parameter; and providing, by the electronic processor, an alert of the out-of-tolerance deviation.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A system 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.
A fluid displacement pump can include a rotor; and a stator, where the stator includes an elastomeric material with a non-uniform thickness, and where the rotor and the stator have a one-to-two lobe ratio.
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 2/08 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
19.
SYSTEMS AND METHODS FOR NON-CONTACT MEASUREMENT FOR CENTRIFUGE 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.
A method for extracting data from a database for use in a well construction process includes receiving a question from a user. The question is in a well construction language. The method also includes determining context based upon the question. Determining the context includes retrieving key performance indicators (KPIs) based upon the question, and retrieving a plurality of tables from the database. The tables are retrieved based upon the question. The method also includes generating a prompt based upon the question and the context. The method also includes generating a structured query language (SQL) query based upon the prompt using a large language model (LLM). The method also includes running the SQL query against the tables in the database in an attempt to produce a new table. The method also includes performing a wellsite action in response to the new table.
A system and method for determining the location of a droppable object in a wellbore. The droppable object includes an integrated locating system that detects completion components as the object moves through a casing string. The locating system includes an actuation device that is activated based on detection of the components. When activated, the actuation device exerts a radially directed frictional pressure against the inner wall of the casing string, thereby generating pressure pulse telemetry signals that are detected and analyzed by surface equipment to determine the object's downhole location.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
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
22.
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
Aspects of the present disclosure provide a method for modifying a mud-logging operation based on a total gas baseline. The method includes determining an offset between a total gas sensor and one or more gas chromatographs, supplying an operating gas containing hydrocarbons to the total gas sensor and the one or more gas chromatographs during a mud-logging operation, supplying a carrier gas to the total gas sensor and the one or more gas chromatographers from a first carrier gas source during the mud-logging operation; calculating a theoretical total gas baseline based on the offset and a measured gas chromatograph baseline; determining a drift of theoretical total gas baseline; and switching from the first carrier gas source to a second carrier gas source.
A method for reconditioning a gas chromatography apparatus at a rig site includes providing a gas chromatography (GC) apparatus including at least a trapping column, a main column, and a detector. The main column is configured to separate at least methane, ethane, propane, butane, and pentane compounds in a gas stream. The trapping column is configured to remove interfering alkene or alcohol compounds from the gas stream. A plurality of GC measurements is made at the rig site by flowing the gas stream in a forward direction through the trapping column and the main column to the detector. A reconditioning gas is flowed in a reverse direction through the trapping column on the rig site after completing the plurality of GC measurements while heating the trapping column to a temperature of at least 120 degrees C. to recondition the trapping column.
A method for estimating a cuttings lag time or lag time distribution during a drilling operation includes circulating drilling fluid in a wellbore while drilling. Colored magnetic markers are introduced into the circulating drilling fluid while drilling. A magnetic or electromagnetic trap is used to remove colored magnetic markers from the circulating drilling fluid. The removed colored magnetic markers are detected based upon their color using an optical sensor. Surface arrival times of the detected colored magnetic markers are evaluated to estimate the lag time or the distribution of lag times.
E21B 47/11 - Locating fluid leaks, intrusions or movements using tracersLocating fluid leaks, intrusions or movements using radioactivity
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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 drill cuttings lag time during a drilling operation includes circulating drilling fluid in a wellbore to drill. A plurality of radio frequency identification device (RFID) tags and/or a colored dye are introduced into the circulating drilling fluid while drilling. Arrival times of the RFID tags or the colored dye at the surface are evaluated to estimate the drill cuttings lag time.
A leak emissions sensor system for a facility. In some embodiments, the leak emissions sensor system can include one or more detector assemblies. Each detector assembly can include a sensor assembly for obtaining and sending emission information and a displacement apparatus. The sensor assembly can include a leak emission detection sensor, a sensor processor, a GPS, a real-time clock, a wind sensor, and a sensor communicator. The sensor assembly can be disposed on the displacement apparatus. The displacement apparatus can be configured to relocate the sensor assembly within the facility.
G01M 3/16 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point using electric detection means
G01D 3/10 - Measuring arrangements with provision for the special purposes referred to in the subgroups of this group with provision for switching-in of additional or auxiliary indicators or recorders
G01D 11/30 - Supports specially adapted for an instrumentSupports specially adapted for a set of instruments
G01D 21/02 - Measuring two or more variables by means not covered by a single other subclass
G01S 19/14 - Receivers specially adapted for specific applications
31.
SYSTEMS AND METHODS FOR DETERMINING REAL-TIME PERFORMANCE OF COILED TUBING CLEANOUT OPERATIONS
Systems and methods presented herein facilitate improvement of coiled tubing cleanout operations (CTCOs), and generally relate to systems and methods for providing real-time diagnostics of the CTCOs. For example, an example method includes acquiring, via one or more sensors of a coiled tubing system, data relating to a CTCO performed at least partially within a wellbore of the coiled tubing system; analyzing, via a processing and control system, the acquired data to provide real-time diagnostics of downhole conditions within the wellbore during performance of the CTCO; providing, via the processing and control system, one or more outputs relating to the real-time diagnostics of the downhole conditions within the wellbore during performance of the CTCO; and adjusting, via the processing and control system, one or more operational parameters of the CTCO based at least in part on the one or more outputs.
A method can include receiving log data for different types of logs; identifying a portion of the log data that corresponds to a type of formation; defining combinations of the portion of the log data that correspond to the type of formation; implementing a machine learning model that generates scores for the combinations, where each of the scores indicates an ability of each of the combinations to predict one or more target logs therein as selected from the different types of logs; and outputting, based on a ranking of the scores, at least a top ranked one of the combinations that corresponds to the type of formation.
A method of bonding a cutting element to a downhole drilling tool includes orienting an induction coil with respect to a cutting element pocket and applying an energy input to the induction coil to heat the cutting element pocket to a brazing temperature. The method further includes determining a pocket temperature of the cutting element pocket and, based on the pocket temperature, controlling the energy input to the induction coil to maintain the pocket temperature at the brazing temperature for a brazing period.
Systems and methods presented herein relate to a stator lining. A mud motor system includes a stator housing with an inner surface and an anisotropic elastomer reinforcement lining disposed on the inner surface. The anisotropic reinforcement lining has a plurality of lobes arranged helically. The anisotropic elastomer reinforcement lining includes one or more elastomer materials and a plurality of reinforcement fibers. A major axis of the plurality of reinforcement fibers is substantially perpendicular to a helical direction of the plurality of lobes.
B29C 70/22 - Fibrous reinforcements only characterised by the structure of fibrous reinforcements using fibres of substantial or continuous length oriented in at least two directions forming a two dimensional structure
B29C 70/42 - Shaping or impregnating by compression for producing articles of definite length, i.e. discrete articles
F04C 2/10 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member
35.
SOLIDS SEPARATION SCREEN WITH PATTERNED ENCAPSULATION
Solids separation screens are described herein that have a primary separation layer comprising a wire mesh and a patterned fusible encapsulant structure encapsulating a portion of the wire mesh in a pattern.
Methods for determining a compressibility factor are disclosed. A method may include disposing a downhole fluid analysis tool within a wellbore, extracting a formation fluid from the wellbore, pumping the formation fluid through the downhole fluid analysis tool, measuring at least one of a flowline temperature, a flowline pressure, a formation fluid mass density, and a pumped volume, measuring compositions (wt %) of CO2, C1, C2, C3, C4, C5 and C6+ (wj, where j=CO2, C1, C2, C3, C4, C5 and C6+) in the formation fluid, estimating pluralities of molecular weight of C6+ in the formation fluid, estimating pluralities of molecular weight of the formation fluid, calculating the compressibility factor of the formation fluid based upon the flowline temperature, the flowline pressure, the formation fluid mass density, and the molecular weight of the formation fluid, and outputting the compressibility factor of the formation fluid.
Methods of cementing a subterranean well using a geopolymer composition are provided herein. In one aspect, the geopolymer composition can be a pumpable mixture comprising an aluminosilicate source, an activator, a carrier fluid, and a fluid loss composition comprising at least two materials selected from the group consisting of a water soluble polymer, a polymer particle dispersion, a particulate additive, and a dispersant. The geopolymer composition is placed in the subterranean well and allowed to harden into a solid geopolymer. Other methods herein include preparing a dry geopolymer slurry precursor comprising an aluminosilicate source, a metal silicate, an activator, a fluid loss control agent, and a fluid loss control agent enhancer; mixing the dry geopolymer slurry precursor with water to form a pumpable geopolymer precursor; pumping the geopolymer precursor into a subterranean well; and hardening the geopolymer precursor into a solid geopolymer within the subterranean well.
C04B 24/26 - Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
C04B 24/38 - Polysaccharides or derivatives thereof
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
C04B 40/00 - Processes, in general, for influencing or modifying the properties of mortars, concrete or artificial stone compositions, e.g. their setting or hardening ability
C04B 103/00 - Function or property of the active ingredients
C04B 111/00 - Function, property or use of the mortars, concrete or artificial stone
C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C09K 8/514 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
E21B 33/138 - Plastering the borehole wallInjecting into the formation
38.
SYSTEMS AND METHODS FOR GENERATING ONTOLOGICAL DATASETS FOR ENERGY DEVELOPMENT
This disclosure is directed to methods and systems for generating ontological datasets using cloud data for energy development operations. According to one embodiment, a data processing engine stored in a memory device may receive cloud data from a plurality of sources and generate an ontology dataset based on parsing the cloud data. The data processing engine may initiate provisioning of an electronic dashboard on a display device based on a first user input. The electronic dashboard may include one or more display elements associated with the ontology dataset. Moreover, the one or more display elements of the electronic dashboard are activatable to load a computing resource associated with the cloud data. Furthermore, the one or more display elements of the electronic dashboard: are electronically linked to the computing resource; and may comprise picture data, video data, audio data, or textual data.
A method implements automation of product carbon footprint computations. A process map view is displayed, including multiple process nodes and product nodes. A process view is displayed for a process model associated with one of the process nodes. The process map view is updated with a footprint node that is connected to one or more process nodes. A set of process models, including the selected process model, is processed using footprint data from the footprint node to calculate process emissions. The process map view is updated to display the calculated emissions for the connected process nodes. The process emissions are further processed to determine an overall emission value. A dashboard view is displayed showing the emission value for a product represented by a product node.
A method for monitoring valve health. The method may include receiving valve data from a source, pre-processing the received valve data, and detecting at least one event based on the pre-processed valve data to provide event signature data. The method may also include determining that the detected event is an anomaly based on the event signature data, classifying the anomaly based on the event signature data, and performing an action based on the classified anomaly. The method may also include training an event classification model to classify the anomaly according to the event signature data. Training the event classification model to classify the anomaly may include reviewing and labeling a plurality of plots of the event signature data by a subject matter expert and then providing the labeled event signature data to the event classification model, and validating the classification model by the subject matter expert.
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
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
A system for consolidating particles in a subterranean formation includes a treatment fluid (e.g., a consolidation fluid) having a viscosity lower than 5 cP. The treatment fluid includes a resin system, a surfactant, and a curing agent. A method for consolidating particles in a subterranean formation includes preparing the treatment fluid, introducing the treatment fluid into the subterranean formation, and allowing the treatment fluid to cure to consolidate the particles in the subterranean formation.
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
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
47.
SEQUENTIAL SENSOR PLACEMENT FOR GAS EMISSION DETECTION USING RECORD COUNT
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.
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 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 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 displacement unit. The displacement unit may include a body, a head shaft, a base shaft, a middle shaft, and radial bearings. The body may include a head and a base. The head shaft may extend through the head of the body. The base shaft may extend through the base of the body. The middle shaft may be coupled to the head shaft via a first flexible coupling and coupled to the base shaft via a second flexible coupling. The radial bearings may be disposed within body to support at least one of the head shaft, the middle shaft, or the base shaft.
A technique facilitates utilization of an electric submersible pumping system able to provide a desired production output with a reduced length. The electric submersible pumping system is sized for deployment in a borehole, e.g. within a borehole casing, and utilizes contra rotating impellers mounted on contra rotating shafts. To enable the contra rotation, the shafts may comprise a first shaft rotatably disposed within a hollow interior of a second shaft. This type of construction allows operation of the contra rotating impellers so as to enhance production without the length of sequential, traditional impellers.
Systems and methods presented herein facilitate operation of well-related tools. In certain embodiments, a priori data may be obtained to enable optimization of operations related to the well-related tools. In certain embodiments, the a priori data may be provided as advisory data in one or more visualizations, used to facilitate automatic detection of one or more milling events, and/or used to automate one or more milling processes.
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 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
E21B 47/002 - Survey of boreholes or wells by visual inspection
53.
CASCADED DEEP-LEARNING TECHNIQUES FOR GENERATING HIGH RESOLUTION HORIZON DATA
The present disclosure describes techniques including receiving seismic data corresponding to a subsurface region. The techniques also include filtering the seismic data. The filtered seismic data corresponds to one or more depth ranges within the subsurface region. Further, the techniques include applying a first horizon model to the filtered seismic data. The first horizon model outputs a first set of horizon data having a first resolution indicating an expected location of a horizon within the one or more depth ranges. Even further, the techniques include applying a second horizon model to a portion of the seismic data centered based on the first set of horizon data. Further still, the techniques include generating a second set of horizon data based on the portion of seismic data, the first set of horizon data, and the second horizon model. The second set of horizon data has a higher resolution than the first resolution.
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.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
55.
SYSTEMS AND METHODS FOR DETERMINING DOWNLINKS FOR TRANSMITTING TO A DOWNHOLE TOOL
In some embodiments, a method of implementing an operation of a downhole tool within a wellbore includes identifying a tool command for a downhole tool to change a current state of the downhole tool to a target state. The method further includes determining, from a set of candidate downlink commands, a set of one or more downlink commands associated with executing the tool command. The method further includes generating a downlink sequence of one or more downlinks for communicating the set of one or more downlink commands to the downhole tool. The method further includes. providing the downlink sequence for transmitting to the downhole tool
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
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
56.
Methods for Determining Positions of Fluid Interfaces and Detecting Cement Setting in a Subterranean Wellbore
Methods for locating fluid interfaces in a cased wellbore include generating vibrations in the casing, thereby forming oscillations in the wellbore fluids and the casing. The oscillations are detected by a vibration detector. The oscillations are recorded by a data acquisition system. Mathematical processing of the oscillations by cepstrum analysis is performed to determine the depths of interfaces between fluids in the annulus. The methods may also be employed to determine the time at which a cement slurry begins to set and harden. The methods may be performed in real time.
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
A spring shoulder kit includes an expanding shoulder and a retaining sleeve. The expanding shoulder includes a wedge outwardly radially extending from a radially flexible finger. The retaining sleeve is slidably insertable into the expanding shoulder to block inward radial movement of the wedge.
F16L 37/098 - Couplings of the quick-acting type in which the connection between abutting or axially-overlapping ends is maintained by locking members combined with automatic locking by means of flexible hooks
F16L 37/091 - Couplings of the quick-acting type in which the connection between abutting or axially-overlapping ends is maintained by locking members combined with automatic locking by means of a ring provided with teeth or fingers
A device may include a body having a longitudinal axis. A device may include a deployable steering pad radially movable relative to the body, wherein the deployable steering pad has a retracted state defining a retracted radius from the longitudinal axis and a deployed state defining a deployed radius from the longitudinal axis. A device may include a kicker plate connected to the body longitudinally adjacent to the deployable steering pad, wherein the kicker plate has a kicker radius from the longitudinal axis greater than the retracted radius. A device may include a cutting element positioned on the kicker plate and defining a cutting radius between the retracted radius and the deployed radius.
A wellbore seal includes a eutectic plug and a gauge assembly. The eutectic plug is configured to sealably engage a casing or a formation. The gauge assembly is connected to a lower side of the eutectic plug. The gauge assembly includes a pressure gauge configured to measure a pressure of a fluid, and an acoustic transceiver in communication with the pressure gauge and configured to transmit an acoustic signal based on the pressure through the eutectic plug.
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
63.
FORMATION CHARACTERIZATION USING IMAGES OF WET AND DRY CUTTINGS PARTICLES
A method for estimating a characteristic of cuttings particles obtained from a subterranean formation during a drilling operation includes measuring at least first and second bidirectional reflectance distribution functions (BRDFs) of cuttings particles acquired during a drilling operation, the first BRDF measured when the cuttings particles are wet and the second BRDF measured when the cuttings particles are dry and estimating the characteristic of the cuttings particles from the first and second BRDFs.
E21B 47/002 - Survey of boreholes or wells by visual inspection
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
G01B 11/30 - Measuring arrangements characterised by the use of optical techniques for measuring roughness or irregularity of surfaces
A method can include receiving seismic data from a seismic survey of a subsurface geologic environment that includes one or more reflectors; performing a model-based iterative least squares inversion of the seismic data; for at least one iteration of the model-based iterative least squares inversion, determining a value of a regularization parameter by approximating a first function representative of a residuals norm and a second function representative of a solution norm, where the first function and the second function depend on the regularization parameter; and performing a subsequent model-based iterative least squares inversion of the seismic data using the regularization parameter to determine a position of at least one of the one or more reflectors.
The disclosed methods and systems are directed to water flooding optimizations at a resource site for increased production of hydrocarbons. According to some implementations, the methods include receiving at least one of: fluid production rate data and fluid injection rate data using one or more sensors at a resource site. The methods may also include generating a forecasting model based on one or more of the fluid production rate data and the fluid injection rate data. The disclosed methods further comprise executing, using the forecasting model, one or more sensitivity tests to generate a production forecast report.
E21B 47/08 - Measuring diameters or related dimensions at the borehole
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method can include applying a carbon nanotubule coating to one or more components of a fiber optics cable assembly; deploying the fiber optics cable assembly in a downhole environment; and utilizing the fiber optics cable assembly in the downhole environment and a fiber optics cable assembly can include components, where the components include at least one optical fiber; and one or more carbon nanotubule coatings disposed on at least one of the components.
E21B 47/135 - 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 using light waves, e.g. infrared or ultraviolet waves
E21B 47/007 - Measuring stresses in a pipe string or casing
A method can include receiving a seismic model for a geologic region, where the seismic model includes an acoustic portion that accounts for wavefield kinematics using one or more acoustic velocity parameters and an elastic portion that accounts for wavefield elastic plane-wave reflectivity using one or more elastic vector reflectivity parameters; performing a wavefield simulation using the seismic model; during the wavefield simulation, determining angle dependent wavefield amplitude correction terms, subject to one or more structural dip-based angle criteria, using the elastic portion of the model; during the wavefield simulation, applying the angle dependent wavefield amplitude correction terms to wavefield amplitudes of the wavefield simulation to enhance seismic energy-based accuracy of the wavefield simulation; and generating a simulated wavefield as an output of the wavefield simulation.
A quick disconnect system. The quick disconnect system may include a head, a base, and a seal positioned between the head and the base. The head may include a receptacle and a channel having a locking portion. The base may include a sealing portion sized to be positioned within the receptacle of the head, a pin extending radially from the sealing portion of the base, and a locking nut. The pin may be sized to be positioned within the channel of the head such that relative rotation of the head and the base positions the pin within the locking portion. The locking nut may be positioned on a threaded portion of the base such that, when the pin is positioned within the locking portion of the channel, tightening the locking nut compresses the pin against a wall of the channel to prevent separation of the base and the head.
E21B 17/046 - CouplingsJoints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A boost system for a hoisting system includes a track configured to couple to a mast. The boost system also includes a boost assembly with an upper climb unit with a respective hook configured to selectively engage openings in the track, a lower climb unit with a respective hook configured to selectively engage the openings in the track, and a boost actuator configured to drive the upper climb unit along the track and relative to the lower climb unit to provide a supplemental force to a yoke of the hoisting system.
A method may include generating an optimal operational window (OOW) that specifies operational parameter values for drilling operations using equipment at a rig site, based on data indicative of rig state and formation characteristics, and based on mutation-based optimization of the operational parameter values; and instructing a control system to perform the drilling operations according to the OOW using the equipment at the rig site.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
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
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.
Embodiments presented provide for an arrangement and method of using a static mixer in heat exchanging wellbores. In embodiments, a high-efficiency geothermal system is created that allows a static mixer to be used in conjunction with a power production system that creates an efficient power production cycle with reduced maintenance and efficiency greater than conventional systems.
F24T 10/20 - Geothermal collectors using underground water as working fluidGeothermal collectors using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
Systems and methods disclosed herein are generally directed to an interpretation system that may receive measurements from multi-finger caliper tools and output various properties of a wellbore based on the measurements and/or models (e.g., computer models having algorithms) associated with the multi-finger caliper tools. For example, the interpretation system may generate and output defect maps (e.g., maps of defects according to axial position and circumferential position) based on an interpretation of the measurements. In another example, the interpretation system may determine a state of the wellbore based on the interpretation. If the state is clear, then the interpretation system may instruct one or more components of the hydrocarbon well site to initiate production operations. If the state is not clear (e.g., corrosion), then the interpretation system may identify an interval of interest within the wellbore and/or perform a corrective action at the interval of interest.
E21B 47/08 - Measuring diameters or related dimensions at the borehole
G01B 3/38 - Gauges with an open yoke and opposed faces, i.e. calipers, in which the internal distance between the faces is fixed, although it may be preadjustable
G01B 5/12 - Measuring arrangements characterised by the use of mechanical techniques for measuring diameters internal diameters
A method for determining a recalibration trigger for a downhole survey sensor includes obtaining historical calibration and recalibration data for a plurality of downhole survey sensors. The historical calibration data is evaluated to determine calibration changes for selected ones of the survey sensors. A probabilistic model is constructed from the determined calibration changes over a predetermined range of temperatures and benchmarked against at least one industry standard to estimate the recalibration trigger.
A method for generating a segmented image of cuttings particles includes acquiring and preparing the cuttings particles for imaging and placing the prepared cuttings particles in front of a digital camera. At least three digital images of the cuttings particles are acquired at corresponding non-coplanar illumination angles and then combined to generate a photometric stereo image of the cuttings particles. The segmented image may be generated from the photometric stereo image.
A wireless communications system includes a network of acoustic modems for communicating messages between downhole equipment and a surface control and telemetry system. The acoustic modems include multi-channel acoustic receivers that are uniquely deployed along an acoustic transmission medium to provide spatial diversity. Acoustic signals received on the multiple receiver channels are combined and filtered using a Bayesian-type filter to reduce noise.
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
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
Systems and techniques are provided for seismic acquisition operations. The displacements among activation positions of the seismic sources are random values or selected from a predefined list to accelerate progress to cover the area of interest. Regular or irregular perturbations (e.g., random values or selected from a predefined list) in a crossline direction are used for source line spacings and sail line move ups. The source line spacings are fixed or varied with respect to time during the seismic survey. The seismic sensors are spaced at regular or irregular intervals. Complete coverage are attained by performing interpolation techniques to the acquired seismic data. An image reconstruction from the collected seismic survey data, which are processed with compressive sensing techniques before the reconstruction, are generated based in part on an inversion technique or an imaging algorithm.
Systems and methods presented herein provide for well decommissioning in through-tubing applications. A carrier for well decommissioning in through-tubing applications, can comprise a perforating assembly that includes at least one of (1) gun charges, and (2) a mechanical cutting device. The carrier can also include a sensor package that determines geometry of tubulars installed in a wellbore, including eccentricity of the tubulars. The carrier can further include an orienting device that orients the carrier to control the perforating assembly. The carrier can also include a roller assembly that allows the carrier to move longitudinally and rotate around a central axis.
A method can include acquiring motion sensor data using a motion sensor at a motion sensor location of a tool string disposed in a borehole during a field operation; transmitting the motion sensor data to transfer function circuitry of the tool string; operating the transfer function circuitry to apply a transfer function to the motion sensor data to determine one or more of lateral displacement and velocity at a location of the tool string that is a distance from the motion sensor location; and characterizing sensor data acquired by a sensor at the location using at least one of the one or more of the lateral displacement and the velocity.
A safety valve of a well string may include a fluid conduit, disposed about an axis, for conveying a fluid through the safety valve and a valve closure member articulatable between a first state and a second state to selectively block a flow of the fluid through the fluid conduit. The safety valve may also include a power spring to bias the valve closure member toward the first state via a power spring force, a piston to operatively overcome the power spring force and articulate the valve closure member toward the second state, and an adjustable stop disposed at one of multiple different positions within the safety valve such that the power spring is compressed between the piston and the adjustable stop. Moreover, the power spring force may be different at the different positions of the adjustable stop.
A method for correcting photoelectric logging measurements includes acquiring a photoelectric factor image including photoelectric factor measurements in at least first and second azimuthal sectors in a borehole. The photo electric factor image is processed using a system of equations to compute a photoelectric factor of a formation through which the borehole penetrates and photoelectric factor of the drilling fluid in the borehole.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
E21B 47/024 - Determining slope or direction of devices in 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 rotating control device (RCD) for a drilling system includes an outer housing, a seal element positioned within the outer housing and configured to form an annular seal about a tubular, and a damper assembly positioned with the outer housing and configured to dampen forces exerted on the seal element as the tubular rotates, moves axially, or both.
A technique facilitates cooling of a motor protector which may be used in an electric submersible pumping system having a submersible pump powered by a submersible motor. The motor protector may be constructed with a plurality of thrust bearing chambers which can be at least partially filled with an internal motor fluid. Each thrust bearing chamber has a thrust bearing positioned to absorb loads generated during operation of the submersible pump. Additionally, the motor protector comprises an enhanced cooling system to facilitate improved removal of heat created at the thrust bearings. The enhanced cooling system may comprise various components which help transfer heat away from the thrust bearing chambers.
A technique facilitates handling of thrust loads in a pump, such as a submersible pump which may be used in an electric submersible pumping system. For example, the submersible pump may comprise a plurality of pump stages disposed within an outer pump housing. Individual pump stages of the plurality of pump stages each have an impeller and a diffuser with the impeller being rotatable relative to the diffuser via a shaft. Each individual pump stage also comprises a stage thrust bearing assembly to handle thrust loads generated during operation of the submersible pump via rotation of the impellers.
A method can include receiving workflow specifications for an operational workflow performed using equipment in a field to produce hydrocarbons; configuring a dynamic reservoir simulation system according to the workflow specifications; receiving, by the dynamic reservoir simulation system, field data from the equipment; responsive to receipt of the field data, updating a model representative of one or more hydrocarbon production related physical phenomena in the field to generate an updated model of the dynamic reservoir simulation system; generating model-based results using the updated model; assessing quality of the model-based results to generate one or more quality metrics; and outputting, based at least in part on the model-based results, a control action for the operational workflow and at least one of the one or more quality metrics.
A method can include receiving seismic data-based interpretations for discontinuities in a subsurface geologic region; automatically assessing the interpretations, with respect to a type of action for joining individual pairs of the discontinuities, to generate ranked individual pairs of the discontinuities; and performing the type of action for joining a number of the ranked individual pairs of the discontinuities to improve accuracy of a model of the subsurface geologic region.
A bit includes a matrix body including a matrix material that is a matrix material powder bound by an infiltrant. An integral metallic connection includes a matrix portion embedded in the matrix body and a connection portion extended from the matrix body. The connection portion and the matrix portion are integrally formed with each other. The integral metallic connection has a treated strength that is greater than or equal to 90 ksi. The integral metallic connection allows for a drill bit connection to a drill string without the usage of a joining methods (2-piece construction) typical for matrix body bit constructions.
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
B23K 1/00 - Soldering, e.g. brazing, or unsoldering
B23K 101/00 - Articles made by soldering, welding or cutting
The present disclosure relates to a shaped charge liner. The shaped charge liner includes a first liner portion formed a first material. The first liner portion has an apex and a skirt section that define an interior volume of the first liner portion. The shaped charge liner also includes a second liner portion formed of a second material. The second liner portion is coupled to the first liner portion such that the second liner portion is an edge of the interior volume.
The effectiveness of expansive cement systems may be diluted when, during a well cementing operation, commingling takes place between the cement slurry and a spacer fluid, a drilling fluid, or both. Incorporating expansive agents in the spacer fluid or drilling fluid may reduce or negate the loss of expansion at the cement slurry/spacer interface or the cement slurry/drilling fluid interface, thereby promoting zonal isolation throughout the cemented interval.
A cutting element may include a substrate having a base. A cutting element may include an ultrahard layer bonded to the substrate, the ultrahard layer formed from an ultrahard material, the ultrahard layer including: a side surface adjacent to the base, the side surface including a plurality of cutting surfaces; and an upper surface extending into the ultrahard layer.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
95.
SYSTEMS AND METHODS FOR ANALYSIS OF DRILLING FLUID
A method of operating a drilling fluid analysis system includes obtaining multiple samples of a drilling fluid at different times over a time period. The method also includes placing the multiple samples into a capillary electrophoresis device. The method further includes determining a respective concentration of a component in each of the multiple samples of the drilling fluid with the capillary electrophoresis device.
A system includes a processor and a memory, accessible by the processor, the memory storing instructions that, when executed by the processor, cause the processor to receive, from a density sensor with an integrated temperature probe, first data indicative of a density of an aqueous liquid flowing through a line, and second data indicative of a temperature of the aqueous liquid flowing through the line, receive, from an electromagnetic sensor, third data indicative of a dielectric property of the aqueous liquid flowing through the line, apply an interpretation model to the first data, the second data and the third data to determine a concentration of hydrate inhibitor of the aqueous liquid flowing through the line based on the density, the temperature and the dielectric property of the aqueous liquid flowing through the line, and generate an indication of the concentration of hydrate inhibitor of the aqueous liquid flowing through the line.
A method for designing, monitoring, and updating a trajectory of a wellbore at a wellsite. The method includes receiving a plurality of inputs related to the trajectory for the wellbore. The inputs may include a starting point of the trajectory. A zone may be defined within a subsurface beneath the wellsite as safe. The method further includes defining a first set of control points within the zone of the subsurface, and generating a proposed path of the trajectory by connecting the starting point of the trajectory to a plurality of trajectory targets via the first set of control points. The method also includes validating that the proposed path of the trajectory is within the zone of the subsurface.
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 device may include an inner shell including an inner groove having an inner groove angle relative to the rotational axis. A device may include an intermediate shell circumferentially around the inner shell and having a slot therein, the slot being at least partially oriented in a longitudinal direction of the rotational axis. A device may include an outer shell circumferentially around the intermediate shell and including an outer groove having an outer groove angle relative to the rotational axis different from inner groove angle. A device may include a bearing positioned in the slot and contacting the inner groove and the outer groove.
E21B 4/00 - Drives for drilling, used in the borehole
F16H 13/08 - Gearing for conveying rotary motion with constant gear ratio by friction between rotary members with members having orbital motion with balls or with rollers acting in a similar manner
99.
Identification and mitigation of whirl within a drilling system
Whirl in a drilling system may be identified and mitigated by monitoring signals from a plurality of sensors positioned at various axial locations along a drill string of the drilling system, determining a respective frequency component and a respective amplitude component for each of the signals, identifying whirl in the drill string based on at least two of the respective frequency components and their respective amplitude components, and mitigating the whirl by introducing noise into the drilling system to reduce or eliminate the whirl without removing the drill string from a bottom of a borehole and without terminating all rotation of the drill string.
A method may include receiving a selection of a command of a plurality of commands, where the command is part of the plurality of commands and is associated with controlling one or more operations of a downhole tool, and where the plurality of commands is organized according to a JavaScript Object Notation (JSON) schema. The method may also include generating a downlink signal based on the command and transmitting the downlink signal to the downhole tool when the downhole tool is disposed within a wellbore of a geological formation, where the downhole tool is configured to implement a change in the one or more operations in response to receiving downlink signal. The method may further include receiving feedback data from the downhole tool after the downhole tool implements the command, where the feedback data includes one or more measurements associated with the downhole tool implementing the command.
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
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
