A method can include receiving sample information for reservoir fluid samples and automatically selecting one or more equations of state from a plurality of different equations of state, which can suitably match the reservoir fluid samples and/or other samples. Such a method can also include automatically generating initial conditions based at least in part on sample information where such initial conditions along with one or more selected equations of state can be utilized in simulating physical phenomena using at least a reservoir model to generate simulation results. Such a method can include outputting at least a portion of the simulation results, which may be utilized in one or more processes.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
A method may include displaying, in a graphical user interface (GUI) of a display device, an image generated from a well log, receiving, via the GUI, a selection of a portion of the image, obtaining, for the portion of the image, search metadata, and deriving, from the portion of the image, a search pattern including a constraint on a value of a search parameter. The method may further include performing, using the search pattern, a search within the image to obtain search results including matching portions of the image, marking, in the GUI, locations of the search results within the image, receiving, via the GUI, a selection of a search result, and presenting, in the GUI, the search result.
G06F 3/04842 - Selection of displayed objects or displayed text elements
G06F 16/583 - Retrieval characterised by using metadata, e.g. metadata not derived from the content or metadata generated manually using metadata automatically derived from the content
Electric submersible pump systems, and more particularly, seals for ESPs, are provided. An electric submersible pump includes a plurality of impellers; a plurality of diffusers; at least one sealing ring positioned axially between two consecutive diffusers of the plurality of diffusers; and at least one O-ring positioned axially between the at least one sealing ring and a lower of the two consecutive diffusers.
A method includes initiating a managed pressure drilling (MPD) operation in an MPD system including a rotating control device (RCD) including at least one sealing element and a plurality of pressures sensors placed relative to the at least one sealing element. The RCD is positioned in the MPD system so as to receive fluid exiting an annulus of a wellbore. Further, the method includes creating a pressure spike in the annulus of the wellbore during the MPD operation, and monitoring a pressure differential between the plurality of pressure sensors to determine whether there is a leakage within the RCD.
A method of generating a wellbore image is disclosed. The method receives trajectory data captured by a sensor(s) within a wellbore at a resource site. The trajectory data may include a plurality of boundary points of the wellbore in a first dimensional space. The method generates a trajectory segment using a center line segment of the wellbore such that the trajectory segment is bounded by a first point on the center line segment and a second point on the center line segment. The method may generate a plurality of multi-dimensional points using the plurality of boundary points and the center line segment. The method may generate a first image of the wellbore using the first plurality of multi-dimensional points. The first image of the wellbore may indicate an image of the wellbore in a second dimensional space that is of a higher order than the first dimensional space.
A fluid displacement pump can include a rotor; and a stator, where the stator includes two materials bonded by a tie layer. A method can include providing materials; bonding two of the materials using another one of the materials as a tie layer to form a stator material; forming a stator of a pump using the stator material.
Embodiments presented provide for high reliability and low cost electronics used in hydrocarbon recovery operations. In embodiments, the low cost electronics are used in subsea applications.
A method can include receiving data files, where the data files include different types of content; training an encoder using the data files to generate a trained encoder; compressing each of the data files using the trained encoder to generate a compressed representation of each of the data files; and processing the compressed representations of the data files to generate groups, where each of the groups represents one of the different types of content, where each of the groups includes members, and where each of the members is associated with a corresponding one of the data files.
Exemplary methods and systems for minimizing noise during seismic modeling are disclosed. The exemplary methods include receiving seismic data associated with a resource site. The exemplary methods may further generate a model based on the seismic data. In one embodiment, the model has a first noise content associated with the seismic modeling. The noise content, in some embodiments, is due to unwanted signal reflections during the seismic modeling. The exemplary methods may further include generating first data and second data using the wavefields associated with the model and combining the first data and the second data to generate output data. The output data, according to one embodiment has an associated noise content than is less than the first noise content.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
A method for wellsite control includes, at a computing device, receiving sensor information from one or more sensors; determining at least one notification option based at least partially on the sensor information; selecting at least one notification option based at least partially on the sensor information; and sending a notification to a notification destination.
H04Q 9/00 - Arrangements in telecontrol or telemetry systems for selectively calling a substation from a main station, in which substation desired apparatus is selected for applying a control signal thereto or for obtaining measured values therefrom
E21B 41/00 - Equipment or details not covered by groups
11.
DEVICES AND SYSTEMS FOR CUTTING ELEMENT ASSEMBLIES
A cutting element assembly includes a cutter support including a cutter bore. A cutting element is in the cutter bore and a resilient element is integral with the cutter support. The resilient element is longitudinally compressible and has a displacement of greater than 0.1 mm and optionally less than 2 mm. Another cutting assembly includes a cutter support coupled to multiple cutting elements. A resilient element of the cutter support is compressible based on a force applied to the cutter support through one or more of the cutting elements. The resilient element can include a slit in the cutter support. A slit may, for instance, extend perpendicular or transverse to an axis of the cutting elements and allow the cutter support to flex and close off or reduce a size of the slit when forces act on one or more of the cutting elements.
A technique facilitates application of increased force in various well applications while limiting the overall time period of the operation by automatically utilizing two modes of operation. In some well applications, the technique automatically applies increased force to facilitate shearing of a tubular product in a timely manner. By way of example, the system may be utilized to rapidly advance rams to the point of contact with the tubular product extending through well equipment, e.g. through a blowout preventer (BOP), and then to automatically shift to a slower advance but higher force mode. The higher force mode facilitates shearing of a variety of tubular products in a variety of well applications.
A method for correcting elemental yields obtained from gamma ray spectra includes acquiring a plurality of elemental yields corresponding to a plurality of time intervals; summing one of the plurality of elemental yields with an accumulated negative yield to compute a corrected yield; setting the accumulated negative yield to a minimum of zero and the computed corrected yield; resetting the corrected yield to a maximum of zero and the computed corrected yield; and repeating the summing, the setting, and the resetting, for each of the acquired plurality of elemental yields to compute a corresponding plurality of corrected elemental yields.
H04B 13/02 - Transmission systems in which the medium consists of the earth or a large mass of water thereon, e.g. earth telegraphy
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
G01S 11/06 - Systems for determining distance or velocity not using reflection or reradiation using radio waves using intensity measurements
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
14.
DOWNHOLE INSTRUMENT ACQUISITION AND TELEMETRY SYSTEM
A method may include acquiring NMR data using a NMR unit disposed in a borehole in a formation, where the NMR data represent characteristics of the formation. The method may also include compressing the NMR data using projection followed by adaptive quantization to generate multiple, quantized data structures, where the adaptive quantization selects a gain value from a plurality of gain values. The method may further include transmitting the multiple, quantized data structures using borehole telemetry, where the multiple, quantized data structures include an indicator for the selected gain value.
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
G01V 3/28 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
An apparatus and method of creating a window in a composite casing section. The composite casing section has a metallic casing, an indexing locator and a composite joint. The composite joint is positioned between the metallic casing and indexing locator. The indexing locator is configured to locate a departure device within the wellbore. The departure device directs the milling device to mill the window through the composite joint. A lateral wellbore is created after the window is milled through the composite joint.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 17/04 - Couplings; Joints between rod and bit, or between rod and rod
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
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
A bridge racker includes a bridge crane, a vertical column connected to the bridge crane, an extender connected to the vertical column, and a tool connected to the extender. The tool is configured to hold a tubular and the extender is configured to adjust a horizontal offset between the vertical column and the tool.
A method for gain correcting a gamma ray spectrum includes acquiring a gamma ray spectrum including gamma ray counts distributed into a plurality of energy channels, evaluating the acquired gamma ray spectrum to determine an energy of a calibration feature therein, comparing the energy of the calibration feature in the acquired spectrum to a standard spectral energy to determine a deviation between the energy of the calibration feature and the standard spectral energy, and adjusting the acquired spectrum so that the energy of the calibration feature is equal to the standard spectral energy to obtain a gain calibrated spectrum.
G16C 20/10 - Analysis or design of chemical reactions, syntheses or processes
G01N 23/22 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material
Seismic data for a subsurface region is obtained. Individually, for each factor of multiple factors, a corresponding set of factor cubes specific to the factor is generated to obtain sets of factor cubes. Each factor cube includes cells having a value for the factor cube that is for a particular location in the subsurface region. An unsupervised machine learning clustering model is executed on the sets of factor cubes to determine a corresponding weight for each factor. According to the corresponding weight, the sets of factor cubes are aggregated to generate an aggregated cube, which is presented.
An automated system for managing gas in an annulus of a production well at a well site, the automated system including: an electrically-controlled valve fluidly coupled to the annulus of the production well, wherein the valve is located at or near the surface at the well site; at least one well sensor configured to measure operational characteristics of the production well at or near the surface; and a gateway device, located at the well site and operably coupled to the valve and the at least one well sensor, wherein the gateway device is configured to collect first sensor data communicated from the at least one well sensor, and process the first sensor data in autonomous control operations that automatically generate and issue commands that are communicated from the gateway device to the valve to regulate the outflow of accumulated gas from the annulus of the production well over time.
A method can include receiving realizations of a model of a reservoir that includes at least one well where the realizations represent uncertainty in a multidimensional space; selecting a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimizing an objective function based at least in part on the selected portion of the realizations; outputting parameter values for the optimized objective function; and generating at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.
The present disclosure relates to a method. The method includes receiving, via one or more processors, colorimetric data corresponding to a portion or integrality of a surface of a field component. The method also includes determining, via the one or more processors, a color value associated with the surface. Further, the method includes retrieving, via the one or more processors, trend data indicating relationships between a plurality of color values and a plurality of conditions corresponding to the field component. Further still, the method includes determining, via the one or more processors, a condition of the plurality of conditions correspond to the field component based on the trend data and the color value. Even further, the method includes generating, via the one or more processors, a condition output based on the determined condition.
A method for estimating net inelastic gamma ray counts includes acquiring a burst gamma ray count measured during a neutron burst time interval, acquiring a capture gamma ray count measured during at least one neutron capture time interval, acquiring a neutron count during at least the neutron burst time interval, and subtracting a portion of the capture gamma ray count and a portion of the neutron count from the burst gamma ray count to estimate the net inelastic gamma ray count.
G16C 20/10 - Analysis or design of chemical reactions, syntheses or processes
G01N 23/22 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material
23.
DEVICES, SYSTEMS, AND METHODS FOR AUTOMATED SCHEDULING
A rig scheduling system prepares a candidate schedule. The candidate schedule is constrained by a set of constraints. The rig scheduling system identifies a neighborhood for alternative schedules to the candidate schedule. The neighborhood is defined by relationships between constraints within the set of constraints. The rig scheduling system prepares a plurality of alternative schedules within the neighborhood and selects a favorite alternative schedule of the plurality of alternative schedules based on one or more quality metrics.
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 systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 41/00 - Equipment or details not covered by groups
24.
DEVICES, SYSTEMS, AND METHODS FOR DOWNHOLE SURVEYING
A drilling system may include a steering tool configured to engage a wellbore wall to direct an orientation of a toolface, the steering tool being rotatable about a rotational axis. A drilling system may include an azimuth sensor package, the azimuth sensor package including at least one of a multi-axis gyroscopic azimuth sensor rotatable about the rotational axis of the steering tool, a multi-axis magnetic azimuth sensor rotatable about the rotational axis of the steering tool, or an accelerometer azimuth sensor rotatable about the rotational axis of the steering tool.
E21B 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
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 systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
Techniques for controlling tortuosity of fluid flow through a subterranean formation include introducing a diversion fluid into a wellbore, introducing a first fluid into the wellbore, collecting a second fluid from the wellbore or a second wellbore, and recovering heat from the second fluid. Techniques for increasing the likelihood that a fluid will absorb heat as it flows through rock fractures include introducing a first fluid into a first wellbore, introducing a particulate fluid into the first wellbore, collecting a second fluid from a second wellbore, and recovering heat from the second fluid. Techniques for recovering heat from a subterranean formation include observing a first parameter of a first fluid introduced into a first wellbore, observing a second parameter of a second fluid collected from a second wellbore, recovering heat from the second fluid, and introducing a diversion fluid into the first wellbore.
A bridge racker includes a bridge crane, a vertical lifting assembly connected to the bridge crane and with access to a limited vertical range at the bridge crane, and a winch assembly connected to the bridge crane and with access to an entire vertical range between a drill floor and the bridge crane.
E21B 19/15 - Racking of rods in horizontal position; Handling between horizontal and vertical position
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
E21B 19/20 - Combined feeding from rack and connecting, e.g. automatically
B66C 23/26 - Cranes comprising essentially a beam, boom or triangular structure acting as a cantilever and mounted for translatory or swinging movements in vertical or horizontal planes or a combination of such movements, e.g. jib cranes, derricks or tower cranes specially adapted for use in particular locations or for particular purposes constructed, e.g. with separable parts, to facilitate rapid assembly or dismantling, for operation at successively higher levels, for transport by road or rail
B66C 1/42 - Gripping members engaging only the external or internal surface of the articles
B66C 7/02 - Runways, tracks, or trackways for trolleys or cranes for underhung trolleys or cranes
B66C 11/16 - Rope, cable, or chain drives for trolleys; Combinations of such drives with hoisting gear
27.
Methods and systems for stimulation of a subterranean formation using at least one self-resonating nozzle
Methods and equipment are provided for stimulating recovery of hydrocarbons from a subterranean formation traversed by a wellbore, which employ at least one self-resonating nozzle. Fluid under pressure is supplied to the at least one self-resonating nozzle to create a channel in a surface of the subterranean formation facing the at least one self-resonating nozzle. In embodiments, the equipment can be a downhole tool or completion equipment (such as a liner) that is deployed in the wellbore.
A process mimicking forward modeler with deposition and erosion at each specific geological time step. The 3D derived properties are high resolution depositional environments and rock properties that are used to generate multiscale labelled synthetic data. These synthetic data can range from 1D logs such as grain size, gamma ray, density, and velocity, to 3D synthetic seismic, and are used directly as training data for various AIML applications.
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
29.
FLUID DENSITY AND VISCOSITY MEASUREMENT TOOL WITH NOISE CANCELLATION
A system including a sensor housing including a channel, and cantilever beam connected to the sensor housing and disposed within the channel. The system also includes an actuator connected to the cantilever beam and configured to cause the cantilever beam to vibrate. A sensor is connected to the cantilever beam and is configured to generate a first signal representing a cantilever beam vibration of the cantilever beam. The system also includes an accelerometer connected to at least one of the sensor and the sensor housing, the accelerometer configured to generate a second signal representing an external vibration of the sensor housing. The external vibration changes the cantilever beam vibration. The system also includes a signal processor configured to receive, as input, the first signal and the second signal and to generate, as output, a filtered signal that reduces an effect of the external vibration on the cantilever beam vibration.
A method can include operating a field system using a first partition as an active partition and a second partition as a passive partition; responsive to receipt of a system update, changing a bootloader configuration from the first partition to the second partition; performing root of trust measurements for the update where the measurements account at least for the change in the bootloader configuration; responsive to establishing trust via the measurements, accessing an encryption key; decrypting, using the encryption key, at least the second partition for use by the system; and rebooting the field system using the second partition as an active partition and the first partition as a passive partition for a system rollback responsive to detection of a system update issue.
G06F 21/53 - Monitoring users, programs or devices to maintain the integrity of platforms, e.g. of processors, firmware or operating systems during program execution, e.g. stack integrity, buffer overflow or preventing unwanted data erasure by executing in a restricted environment, e.g. sandbox or secure virtual machine
G06F 21/57 - Certifying or maintaining trusted computer platforms, e.g. secure boots or power-downs, version controls, system software checks, secure updates or assessing vulnerabilities
G06F 21/71 - Protecting specific internal or peripheral components, in which the protection of a component leads to protection of the entire computer to assure secure computing or processing of information
G06F 21/00 - Security arrangements for protecting computers, components thereof, programs or data against unauthorised activity
31.
RESERVOIR MODELING AND WELL PLACEMENT USING MACHINE LEARNING
A method includes training a proxy machine learning model to predict an output of a simulation of a physics-based model of a subsurface volume, based on simulation results generated based on the physics-based model and historical data, applying a respective set of uncertainty parameters to the trained proxy machine learning model to generate a solution, returning the generated solution as a solution responsive to determining that a difference between the generated solution and the historical data is less than an error tolerance, and visualizing one or more properties of a subsurface volume using the trained proxy model.
An annular blowout preventer includes an annular body including a central bore extending therethrough, a plurality of electric motors disposed circumferentially around the annular body, a packer assembly disposed within the annular body about the central bore, and a plurality of pusher plates disposed in the annular body, each pusher plate configured to radially engage the packer assembly. The packer assembly includes a packer element and a donut that circumferentially surrounds the packer element. The plurality of pusher plates is correspondingly connected to the plurality of electric motors via a connecting rod.
A shckline stuffing box includes one or more packer elements that are configured to compress axially and expand radially to seal around a slickline to contain a. pressure within a wellbore therebelow during a slickline wellbore intervention. The slickline stuffing box also includes a valve configured to be positioned below the one or more packer elements in a first configuration of the slickline stuffing box and above the one or more packer elements in a second configuration of the slickline stuffing box. The valve is configured to contain the pressure within the wellbore in response to the slickline breaking and falling down and out of the slickline stuffing box.
E21B 33/072 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
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
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A slickline stuffing box includes a piston configured to move in response to a force exerted thereon by a pressurized fluid. The slickline stuffing box also includes a packer element positioned above the piston. The packer element is configured to compress axially and expand radially, in response to movement of the piston, to seal around a slickline to contain a pressure within a wellbore during a slickline wellbore intervention. The slickline stuffing box also includes a valve configured to be positioned below the packer element in a first configuration of the slickline stuffing box and above the packer element in a second configuration of the slickline stuffing box. The valve is configured to contain the pressure within the wellbore in response to the slickline breaking and falling down and out of the slickline stuffing box.
E21B 33/072 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
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
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A system includes rotational ball seat (RBS), remote operated, and electrical/hydraulic sections. The RBS section includes a spring, a first internal sleeve, and an upper RBS. The remote operated section includes a lower rotational ball valve (RBV) disposed between second and third internal sleeves, and a setting sleeve operatively connected to the lower RBV. During miming-in-hole, the upper RBS is in a restricted position, and the lower RBV is in an open position. The spring compresses the internal sleeves, which sandwich the upper RBS and the lower RBV, until a shear event occurs. An inner diameter of the system closes to facilitate setting of hydraulic equipment. Thereafter, the shear event releases the spring, thereby pushing the internal sleeves, the upper RBS, and the lower RBV downhole, which rotates the upper RBS and the lower RBV into open positions, thereby opening the inner diameter of the system.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
A technique facilitates stimulation of multiple well zones along a multilayered reservoir. The technique utilizes equipment constructed to enable performance of the stimulation job along the multiple well zones, i.e. two or more well zones, prior to gravel packing the multiple well zones. The equipment enables performance of the stimulation job during a single trip downhole. Subsequent actuation of the equipment further enables a multizone gravel packaging operation during the same trip downhole.
A gyroscope assembly is maintained in a park position during drilling activities. In the park position, a sensitive axis of a gyroscope in the gyroscope assembly is perpendicular or approximately perpendicular to a longitudinal axis of a downhole tool. Maintaining the park position during drilling activities reduces the drift bias caused by overloading the input signal of the gyroscope due to rotation of the downhole tool.
An aqueous composition includes an acid, or an ammonium or salt thereof; a hydrogen fluoride (HF) source; and a fluoride scale inhibitor. Various methods include providing the aqueous composition and performing a treatment operation using the aqueous composition.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
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
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
A system can include a processor; memory operatively coupled to the processor; and processor-executable instructions stored in the memory to instruct the system to: receive a marker on a well log for a well in a geographic region; and iteratively propagate the marker automatically to a plurality of well logs for other wells in the geographic region.
A method, sensor, and non-transitory computer-readable storage medium are provided for estimating actual amplitudes of a waveform. A machine learning model may be trained for an embedded system of a first three-axes sensor having a limited range to estimate the actual amplitudes of a waveform that saturates the first three-axes sensor in a direction of one of the three axes. The embedded system acquires a second waveform during use of a tool including the first three-axes sensor. The second waveform that occurs after a second waveform producing event is isolated. The embedded system extracts a multi-dimensional feature from the isolated second waveform and estimates, using the machine learning model, the actual amplitudes of the second waveform based on the extracted multi-dimensional feature.
A method, computer-assisted system, and computer program product including training a proxy model to predict output from a numerical model of a volume of interest, receiving data representing an subsurface operation performed at least partially in the volume of interest, predicting one or more performance indicators for the subsurface operation using the proxy model, and updating the numerical model based at least in part on the one or more performance indicators predicted in the proxy model.
G05B 17/00 - Systems involving the use of models or simulators of said systems
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
Machine learning techniques for reconstructing a target well log are presented. The techniques include: storing a dictionary that includes a statistical distribution similarity quantification for each common feature of each pair of well logs in a well log data set; for at least one cluster of the target well log, ranking the well logs in the well log data set based on the dictionary, where the ranking is according to a statistical distribution similarity to the target well log; selecting a validation set of well logs and a training set of well logs; iteratively producing a reconstruction model, where each step of the iteration includes training using the training set of well logs and validating using the validation set of well logs; reconstructing a feature in the target well log using reconstructed values for the feature output by the reconstruction model; and providing the reconstructed target well log.
Disclosed are methods, systems, and computer programs for placing one or more optimal infill well locations within a reservoir. The methods include: generating a first multi-dimensional reservoir model of a first reservoir that is parameterized; assigning well placement data to the first reservoir model to generate a simulation model; applying a stochastic optimization process in a first simulation on the simulation model; determining infill well locations data based on the first simulation; configuring a second multi-dimensional reservoir model based on the infill well locations data; and generating using the second multi-dimensional reservoir model, one or more of: pressure delta data for one or more infill locations associated with a second reservoir, and a simulation opportunity index indicating reservoir properties for the one or more infill locations associated with the second reservoir.
G05B 17/00 - Systems involving the use of models or simulators of said systems
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 30/3308 - Design verification, e.g. functional simulation or model checking using simulation
G06F 17/18 - Complex mathematical operations for evaluating statistical data
A method can include accessing a hexahedral cell grid, defined by corner nodes, that represents a geologic environment, where hexahedral cells of the hexahedral cell grid overlap in a region of the geologic environment that includes a fault, where the fault is represented by discrete elements defined by element nodes; generating a depositional space grid that represents the geologic environment in a depositional space using the hexahedral cell grid and zero gap corner node displacement constraints for overlapping hexahedral cells that represent different sides of the fault, where the zero gap corner node displacement constraints are formulated using the element nodes of the fault that are embedded in the overlapping hexahedral cells to constrain corner node displacements to prevent gapping between opposing sides of the fault; and characterizing the geologic environment with respect to hydrocarbon production using the depositional space grid.
A method including receiving injector-producer pair parameters for injectors and producers in a target underground region. The injectors and the producers may be characterized as injector-producer pairs. The method also includes converting the injector-producer pair parameters into coefficients stored in a data structure. The coefficients represent estimates of connection strengths between the injectors and producers. The method also includes generating, from the coefficients, a performance indicator that represents an operational relationship between a corresponding injector and a corresponding producer in an injector-producer pair. The method also includes transmitting the performance indicator to a pattern flood management application.
G06F 7/48 - Methods or arrangements for performing computations using exclusively denominational number representation, e.g. using binary, ternary, decimal representation using unspecified devices
G06G 7/48 - Analogue computers for specific processes, systems, or devices, e.g. simulators
46.
SYSTEM FOR AUTOMATED MODEL BUILDING AND SCENARIO EVALUATION THROUGH CONCEPT GENERATION
Systems and methods for executing automated model generation and scenario-based evaluation operations at a resource site are presented. The systems may be used to generate a first framework and a second framework associated with a plurality of domains comprising a plurality of specialization areas associated with developing the resource site. In one embodiment, the systems facilitate generating one or more models and executing one or more simulations on said models based on one or more development scenarios. In one embodiment, the systems and methods enable generation of output data (e.g., well design data, subsea design data, subsurface production data) in response to executing the simulations. The output data according to some embodiments, used to generate one or more visualizations that are displayed on a graphical user interface.
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G06G 7/48 - Analogue computers for specific processes, systems, or devices, e.g. simulators
G06G 7/00 - Devices in which the computing operation is performed by varying electric or magnetic quantities
An actuation assembly. The actuation assembly may include a housing, a mandrel disposed within the housing and shiftable within the housing to open and close an isolation valve, and a piston assembly disposed between the housing and the mandrel. The piston assembly may include a first hydraulic chamber fluidly couplable to a first trigger, a second hydraulic chamber fluidly couplable to the first trigger and a second trigger, a third hydraulic chamber fluidly couplable to the second trigger, a close collet piston positioned between the first hydraulic chamber and the second hydraulic chamber and close collet piston operable to shift the mandrel to close the isolation valve when the first trigger is activated, and an open collet piston positioned between the second hydraulic chamber and the third hydraulic chamber and open collet piston operable to shift the mandrel to open the isolation valve when the second trigger is activated.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
48.
CARBONATES CHARACTERIZATION VIA DIFFUSE REFLECTION INFRARED MEASUREMENT
A method can include irradiating a rock sample with infrared radiation from at least one radiation source; detecting infrared radiation reflected from the rock sample for two different wavelength bands using a photodetector; and, based on a comparison of the infrared radiation for the two different wavelength bands, using a processor, determining whether the rock sample includes carbonate.
G01N 21/31 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry
G01N 21/3563 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing solids; Preparation of samples therefor
A method, computer system, and computer program product are provided for identifying missing reserves in a reservoir. Well site data for well sites in a reservoir are ingested. A first machine learning model generates behind casing opportunities and reservoir quality indicators from the plurality of logs. A second machine learning model determines missing reserves based on the reservoir quality indicators for the well sites and in between the wells. A third machine learning model determines candidate wells based on the missing reserves. A fourth machine learning model predicts economic outcomes for intervention options for the candidate wells. An oilfield decision is supported based on the predicted economic outcomes.
E21B 47/005 - Monitoring or checking of cementation quality or level
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 systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
Methods and systems for geological fault modeling are presented. The methods comprise: receiving interpretation data associated with one or more geological faults based on extracted data from a geological site; optimizing the interpretation data using one or more formatting operations associated with a signal processing module; generating one or more gridding representations of the interpretation data using the formatted interpretation data; executing, using the one or more gridding representations of the interpretation data, one or more inference operations based on one or more fault relationships associated with the formatted data to generate a fault model; executing, using the fault model, one or more of a sensitivity operation or an uncertainty analysis operation based on one or more parametric configurations of the fault model during a simulation to generate output data; and initiating generation of a visualization associated with the one or more geological faults based on the output data.
A method can include accessing a finite element cell grid in a depositional space for a geologic environment, where finite element topological cells spatially overlap in a region of the depositional space that includes a discontinuity; processing the finite element topological cells using one or more scalar fields to generate depositional grid cells, where each of the depositional grid cells includes a surface defined by the discontinuity and at least one surface defined by at least one of the one or more scalar fields; and assigning one or more physical properties to each of the depositional grid cells to generate a computational model that characterizes the geological environment.
E21B 41/00 - Equipment or details not covered by groups
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G09B 23/40 - Models for scientific, medical, or mathematical purposes, e.g. full-sized device for demonstration purposes for geology
52.
PREDICTION OF GAS CONCENTRATIONS IN A SUBTERRANEAN FORMATION
A method for estimating a formation gas concentration while drilling includes making first gas concentration measurements in drilling fluid as the drilling fluid exits a wellbore or second gas concentration measurements in drilling fluid before the drilling fluid is pumped into the wellbore while drilling the wellbore. The first gas concentration measurements or the second gas concentration measurements may be evaluated with a model to estimate the formation gas concentration.
Methods and systems for subsurface modeling are disclosed. The methods include: generating a set of fault models using fault interpretation data derived from one or more of geological data captured by one or more sensors at a geological site or aggregated historical geological data generated from a plurality of geological sites; executing a filtering operation on the set of fault models to select one or more fault models with a shared property; applying one or more geometry constraints on the one or more fault models to generate a constrained set of fault models; generating a subsurface framework model using the constrained set of fault models, the subsurface framework model indicating consistent horizon data for the geological formation; testing the subsurface framework model based on one or more simulations to generate output data; and initiating generation of one or more visualizations based on the output data for viewing on a graphical display device.
A computing system for providing standardized seismic processing workflows includes a workflow template registry configured to register a plurality of workflow templates that each include one or more steps that produce output seismic data. The computing system also includes a workflow execution track template registry configured to register a plurality of track templates. Each track template includes one or more of the workflow templates. The computing system also includes a workflow execution graphical user interface configured to enable a definition of a seismic processing project. The seismic processing project includes a plurality of tracks and a sequence of seismic processing activities. The computing system also includes a workflow execution dispatcher configured to cause the one or more steps to interact with a cloud computing environment. The computing system also includes an output data registry.
An integrated autonomous operation system that holistically renders the operation in digital form at multiple scales, including reservoir, surface infrastructure, workflows, processes, and the real asset. The system provides an end-to-end digital twin connecting subsurface to production. A subsurface model identifies and monitors water-producing zones for strategic decisions. The models use intelligent Al to provide optimum water injection setpoints. The models provide data to systems that automatically control the chokes and valves to meet the setpoints, thus achieving fully integrated, autonomous operations.
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 systems; Systems 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
56.
FEEDBACK LOOP MODEL FOR INJECTOR-PRODUCER RELATIONSHIP IN HYDROCARBON RESERVOIRS
Certain aspects of the disclosure provide a method for generating allocation factors describing an injector-producer relationship between injection wells and a production well of a reservoir. The method generally includes obtaining geospatial location data for multiple injection wells and at least one production well within the reservoir; using a liquid rate model to estimate liquid flow rates for a specified well pattern within the reservoir, wherein the liquid rate model incorporates a distance parameter representing the spatial separation between each injection well and the production well; calculating a water-cut profile for the production well based on fractional flow models and the estimated liquid flow rates; and generating allocation factors for each injection well in relation to the production well based on at least one of the estimated liquid flow rates and the water-cut profile, wherein the allocation factors describe contributions of the injection wells towards the production well.
A method includes receiving, via one or more processors, resource data from a plurality of source. The method also includes determining, via the one or more processors, location data associated with the resource data from the plurality of sources. Further, the method includes receiving, via the one or more processors, criteria data corresponding to a user accessing the resource data. Further still, the method includes generating, via the one or more processors, a geographic data visualization of the resource data based on the location data. The geographic data visualization includes a plurality of visual resource representations indicative of at least a portion of the resource data.
G06F 16/16 - File or folder operations, e.g. details of user interfaces specifically adapted to file systems
G06F 16/587 - 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 method for estimating surface concentrations of gas in a drilling fluid in use in a drilling rig includes measuring gas-out or gas-in concentrations while drilling a wellbore and processing the gas-out measurements or the gas-in measurements with a calibrated model to estimate corresponding gas-in concentrations or gas-out concentrations.
Methods, computing systems, and computer-readable media for a machine learning method of modeling fault-related properties of a geological region are presented. The techniques include: obtaining seismic geological data for a geological region; obtaining from a user identifications of a plurality of faults in the geological region; automatically generating values for descriptors of respective faults of the plurality of faults; automatically partitioning faults of the plurality of faults into a plurality of groups according to the values for the descriptors; obtaining a mapping of respective groups of the plurality of groups to modeling parameter values; applying the mapping to a fault in the geological region outside of the plurality of faults to obtain a modeling parameter value for the fault outside of the plurality of faults; and modeling a fault-related property of the geological region based on the modeling parameter value for the fault outside of the plurality of faults.
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 including receiving a reservoir model of a target underground region. The method also includes extracting, from the reservoir model, a historic pressure distribution in grid cells of the target underground region. The method also includes extracting, from the reservoir model, distances. Each distance represents a distance between a grid cell and a corresponding lineament in the target underground region. The method also includes receiving historic earthquake data of past earthquakes in the target underground region. The method also includes generating a vector. The vector includes features and corresponding values for at least i) the historic pressure distribution, ii) the distances, and iii) the historic earthquake data. The method also includes training a trained machine learning algorithm by recursively executing a machine learning algorithm on the vector until convergence.
A method for oilfield workflow processing includes receiving a script from a first computing device at a data aggregation platform, the data aggregation platform comprising one or more processors and oilfield data, executing the script using the one or more processors and the oilfield data of the platform, and transmitting one or more results of the execution of the script back to the first computing device. At least some of the oilfield data that was used in executing the script is not transmitted back to the first computing device.
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
62.
INTEGRATED MULTI MODAL EMISSION MEASUREMENTS LIFECYCLE
The disclosed methods and systems are directed to mitigating against one or more emissions events at a facility. The method comprises receiving first emissions data associated with the facility and formatting same based on a predefined data structure or a source type associated with the plurality of emissions sources of the facility. The method further comprises tracking using one or more sensors a plurality of emissions records generated using the emissions data. The data from the tracked emissions records may be used to generate an emissions inventory that may be used to generate one or more models which are used in one or more simulations to generate second emissions data. The second emissions data may enable tracking of one or more emissions sources associated with the facility. The second emissions data may enable execution of control operations that mitigate against one or more emissions sources associated with the facility.
G01N 1/22 - Devices for withdrawing samples in the gaseous state
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
G06Q 10/06 - Resources, workflows, human or project management; Enterprise or organisation planning; Enterprise or organisation modelling
A wellbore is plugged using a bismuth alloy. In one embodiment, the bismuth alloy comprises an alloy of bismuth and tin. In another embodiment, the bismuth alloy comprises an alloy of bismuth and silver. The wellbore can be arranged so that a liquid bismuth alloy sets with an excess pressure of the plug relative to the borehole fluid pressure along a desired seal height distance. Other aspects are described and claimed.
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
E21B 29/12 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground specially adapted for underwater installations
A ranging workflow to interpret the ultradeep harmonic anisotropic attenuation (UHAA) measurements and estimate the distance and orientation of the existing cased well from the well being drilled is presented herein. The ranging workflow applies to scenarios in which the wells are near parallel to each other and performs reasonably well in boreholes which are more or less perpendicular to the formation layers. The ranging workflow generally includes deploying a deep directional resistivity (DDR) tool into a new wellbore; collecting UHAA data via the DDR tool; determining resistivity values based at least in part on the UHAA data; and determining a distance of the DDR tool from a casing of an existing wellbore proximate the new wellbore based at least in part on the resistivity values and a UHAA response table for the DDR tool.
G01V 3/20 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
E21B 47/024 - Determining slope or direction of devices in the borehole
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
65.
INTEGRATED AUTONOMOUS OPERATIONS FOR INJECTION-PRODUCTION ANALYSIS AND PARAMETER SELECTION
An integrated autonomous operation system that holistically renders the operation in digital form at multiple scales, including reservoir, surface infrastructure, workflows, processes, and the real asset. The system provides an end-to-end digital twin connecting subsurface to production. A subsurface model identifies and monitors water-producing zones for strategic decisions. The models use intelligent AI to provide optimum water injection setpoints. The models provide data to systems that automatically control the chokes and valves to meet the setpoints, thus achieving fully integrated, autonomous operations.
A fluid system component can include a body that includes a multidimensional shape defined in orthogonal directions and layers stacked along one of the orthogonal directions, where at least one of the layers includes polymeric material and graphene nanoplatelets formed in situ from the polymeric material, and where the graphene nanoplatelets increase stiffness of the polymeric material.
B23K 26/00 - Working by laser beam, e.g. welding, cutting or boring
B29C 64/188 - Processes of additive manufacturing involving additional operations performed on the added layers, e.g. smoothing, grinding or thickness control
C08J 5/00 - Manufacture of articles or shaped materials containing macromolecular substances
C08K 7/00 - Use of ingredients characterised by shape
C08L 101/12 - Compositions of unspecified macromolecular compounds characterised by physical features, e.g. anisotropy, viscosity or electrical conductivity
67.
SYSTEMS AND METHODS FOR ANALYZING UNCERTAINTY AND SENSITIVITY OF FAULT POPULATIONS
A method for determining an uncertainty of a representation of a fault population includes receiving seismic data representing a subterranean domain. The subterranean domain includes a plurality of faults. The method also includes generating a plurality of fault volumes based upon the seismic data. The method also includes generating a plurality of fault populations based upon the fault volumes. The fault populations are generated by extracting one or more fault objects from one or more of the fault volumes. The method also includes generating quantitative values based upon the fault populations. The quantitative values represent on or more of the fault objects, one or more of the fault populations, or both. The method also includes comparing the quantitative values to determine the uncertainty of the representation of the fault populations. The method also includes generating or updating a visual representation based upon the comparison.
Embodiments presented provide for a method of monitoring emissions. A calibration of a metal oxide sensor is accomplished in order to monitor fugitive methane gas emissions on a consistent and constant basis.
A downhole valve assembly includes a safety valve and an actuator that opens and/or closes the valve. The actuator can be an electro-hydraulic actuator (EHA), an electro mechanical actuator (EMA), or an electro hydraulic pump (EHP). The downhole safety valve can also include an electric magnet. The electric magnet can act as or control a magnetic decoupling mechanism to control closure of the safety valve.
A method of forward modeling reservoir fluid geodynamics that accounts for both slow processes and fast processes. The method provides a model that accounts for the fluid geodynamics from charge to current time.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
A method can include generating a visual group of datasets; receiving a visualization mesh that intersects at least two of the datasets; executing a shader using graphics hardware to generate values for the visualization mesh, where the values depend on data within at least one of the at least two datasets; and rendering a visualization to a display using the values.
A method can include receiving seismic survey data of a subsurface environment from a seismic survey utilizing water bed receivers, where each of the receivers includes a clock; assessing one or more clock calibration criteria; based on the assessing, selecting a clock drift processor for processing at least a portion of the seismic survey data from a plurality of different clock drift processors; using at least the clock drift processor, performing a simultaneous inversion for values of model-based parameters; and, using at least a portion of the values, generating processed seismic survey data that represents one or more geological interfaces in the subsurface environment.
Aspects provide for methods that successfully evaluates multiple compressional and shear arrival events received by a sonic logging tool to evaluate the presence of structures, such as shoulder beds, in downhole environments. In particular, the methods described herein enable automated determination of properties of laminated reservoir formations by, for example, enabling the automated determination of arrival times and slownesses of multiple compressional and shear arrival events received by a sonic logging tool.
A method can include generating equipment specifications for a facility project at a field site by simulating physical phenomena using one or more computational simulators; using the equipment specifications and a computational facility planner system, generating a work breakdown structure for the facility project, where the work breakdown structure represents activities to be performed to deliver a defined scope of the facility project within a defined time; rendering a graphical user interface to a display that includes graphical controls for dependencies of the activities and equipment characterized by the equipment specifications; responsive to input received via one or more of the graphical controls, automatically updating at least durations of the activities; and, based at least in part on the updating, generating an optimal scenario for the facility project.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
G06Q 10/0631 - Resource planning, allocation, distributing or scheduling for enterprises or organisations
G06Q 10/067 - Enterprise or organisation modelling
A backup ring for a frac plug. The backup ring may include a plurality of segments defined by a plurality of slots, where each segment is defined by a sequential pair of the plurality of slots. The backup ring may also include a plurality of buttons, wherein at least one button is disposed on each segment. The backup ring creates a backup anchor for the sealing element and reduces or prevents extrusion of the sealing element.
A system for detecting hydrocarbons in a subterranean formation includes an outlet sensor configured to measure an outlet drilling fluid parameter of a drilling fluid. The system also includes an inlet sensor configured to measure an inlet drilling fluid parameter of the drilling fluid. The system also includes a gas extractor positioned downstream from the outlet of the wellbore and upstream from the inlet sensor. The gas extractor is configured to extract a gas from the drilling fluid. The system also includes a computing system configured to determine a first time when the outlet drilling fluid parameter increases by more than a first threshold, determine a second time when the inlet drilling fluid parameter becomes substantially constant or increases by more than a second threshold, and determine a surface transit time of the drilling fluid based at least partially upon the first time and the second time.
A method can include receiving real-time data during a controlled drilling operation performed by a controller, an instrumented rig and a drillstring that includes one or more downhole sensors, where the data include surface data from the instrumented rig and downhole data from the one or more downhole sensors; detecting a drilling behavior during the drilling operation; and generating a control recommendation to mitigate the drilling behavior.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
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 systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 7/02 - Drilling rigs characterised by means for land transport, e.g. skid mounting or wheel mounting
78.
GENERATION AND USE OF SEARCHABLE GRAPH DATA STRUCTURE BASED ON ONTOLOGICAL KNOWLEDGE
A method including parsing a natural language query to generate terms. The method also includes linking the terms to entities of a graph data structure including a first layer of nodes connected by edges. The entities are selected from among the nodes and the edges. The graph data structure further includes a meta layer which has tags associated with the edges and the nodes. The tags define an ontology for the entities. A term in the terms is linked to an entity in the entities when the term matches the entity. The method also includes generating a set of paths between selected tags in the meta layer. Each of the selected tags is associated with a corresponding edge in the graph data structure that matches a corresponding term extracted from the natural language query. The method also includes converting the set of paths into a structured query language statement.
A method, sensor, and non-transitory computer-readable storage medium are provided for estimating actual amplitudes of a waveform. A machine learning model may be trained for an embedded system of a first three-axes sensor having a limited range to estimate the actual amplitudes of a waveform that saturates the first three-axes sensor in a direction of one of the three axes. The embedded system acquires a second waveform during use of a tool including the first three-axes sensor. The second waveform that occurs after a second waveform producing event is isolated. The embedded system extracts a multi-dimensional feature from the isolated second waveform and estimates, using the machine learning model, the actual amplitudes of the second waveform based on the extracted multi-dimensional feature.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
Systems and methods presented herein a natural language query conversion framework configured to convert natural language queries into database-specific queries to enable users not particularly conversant in database query languages and schema. For example, a method includes receiving, via the natural language query conversion framework, a natural language query; converting, via the natural language query conversion framework, the natural language query into a database query using a language model (LM); and executing, via the natural language query conversion framework, the database query against an oil and gas (O&G) database.
Systems and methods presented herein facilitate ensuring the integrity of oil and gas well intervention operations using blockchain technologies. In particular, the systems and methods described herein utilize blockchain technologies to ensure that all data relating to oil and gas well intervention operations are captured and stored in substantially real time during the operations in a secure and immutable manner.
E21B 47/125 - 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 earth as an electrical conductor
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
H04L 9/00 - Arrangements for secret or secure communications; Network security protocols
82.
MEASURING INFLATABLE PACKER EXPANSION AND WELLBORE DEFORMATION
An inflatable packer assembly that includes opposing end fittings by which the inflatable packer assembly is installable within a downhole tool string. An inflatable body coupled between the end fittings has an external groove. An elongation sensor is fixed in the external groove. The elongation sensor includes a capacitive element that whose capacitance varies based on elongation of the elongation sensor in response to inflation of the inflatable body.
A method can include, responsive to receipt of input characterizing a geologic environment, utilizing a trained machine learning model to identify a number of geologic environments that include corresponding data stored in at least one database; analyzing one or more of the number of geologic environments; and outputting a result based at least in part on the analyzing.
A technique facilitates operation of a slip assembly, e.g. a frac plug assembly, having a plurality of slips. The plurality of slips may selectively be forced in a radially outward direction via, for example, a cone so as to set the slips against a surrounding casing or other tubing. The slip assembly further comprises a mechanism which allows different amounts of radial movement of individuals slips to ensure sufficient setting of the individual slips when the surrounding tubing is oval or otherwise out of round.
An insert assembly for a rotating control device (RCD) includes a seal element configured to form an annular seal about a tubular as the tubular rotates, moves axially, or both. The insert assembly also includes a support member positioned within the seal element, wherein the support member includes a shape memory alloy.
A perforation tool for use in a well bore is described herein. The perforation tool comprises a housing; a plurality of frames that fit inside the housing, each frame having a cylindrical shape with a central axis and a plurality of liners, each liner having an axis perpendicular to the central axis, wherein the axes of the liners of each frame are disposed in a plane perpendicular to the central axis, and the frames are axially stackable; an electrical conductor disposed along a central passage of each frame; a plurality of shaped charges secured in the liners of the frames; a bulkhead member disposed in the housing and forming a seal with the housing; and an initiator module disposed in the housing with the bulkhead member between the initiator module and the plurality of frames.
Systems, computer-readable media, and methods are provided. Relevant documents related to a specific entity are identified based on document metadata. Text and associated spatial coordinates are extracted based on relevant document pages. Significant document entities and associated spatial locations are identified. Page ranking is based on the extracted text and the spatial coordinates, the significant document entities, and image vector representations of the pages. A deep learning language model that utilizes the text and the spatial coordinates, layout information of the document entities, and the image vector representations of the pages is used to extract the user-defined attributes from the relevant document pages. First attribute values associated with the user-defined attributes are aggregated from the pages of one of the relevant documents into a single record. Second attribute values associated with the user-defined attributes are aggregated across the relevant documents. Aggregated records, including a first and second attribute, are written to a database.
A method can include receiving real-time data for a field operation at a wellsite; predicting a future drilling-related loss event based on at least a portion of the real-time data using a trained recurrent neural network model; and, responsive to the predicting, issuing a signal to equipment at the wellsite.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
G06N 3/0442 - Recurrent networks, e.g. Hopfield networks characterised by memory or gating, e.g. long short-term memory [LSTM] or gated recurrent units [GRU]
89.
DEVICES, SYSTEMS, AND METHODS FOR DOWNHOLE POWER GENERATION
A downhole energy harvesting system includes a housing subjected to periodic oscillations. An energy harvesting device is on, in, or otherwise connected to the housing and positioned to generate electricity based on the periodic oscillations. The energy harvesting device is coupled to at least one of a powered component or an energy storage device in order to use or store the harvested energy.
E21B 41/00 - Equipment or details not covered by groups
H02N 2/18 - Electric machines in general using piezoelectric effect, electrostriction or magnetostriction producing electrical output from mechanical input, e.g. generators
A global fluid identity repository is used to maintain and manage fluid characterization data for various fluids utilized in the oil & gas industry, e.g., reservoir fluids within subsurface formations. Tracking and notification services may be utilized to track changes made to a global fluid identity, e.g., changes in fluid sample and/or experiment data for a fluid, and automatically generate notifications when downstream data such as fluid models and/or simulation results become stale as a result of these changes.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
Methods of fracturing a subterranean formation include introducing a fracturing fluid containing an aqueous medium, a viscosifying agent and a polyethylene oxide alkyl ether through a wellbore and into the subterranean formation, pressurizing the fracturing fluid to fracture the subterranean formation, and allowing the fracturing fluid to flow back into the wellbore from the subterranean formation. The polyethylene oxide alkyl ether useful in some embodiments is defined according to the formula:
Methods of fracturing a subterranean formation include introducing a fracturing fluid containing an aqueous medium, a viscosifying agent and a polyethylene oxide alkyl ether through a wellbore and into the subterranean formation, pressurizing the fracturing fluid to fracture the subterranean formation, and allowing the fracturing fluid to flow back into the wellbore from the subterranean formation. The polyethylene oxide alkyl ether useful in some embodiments is defined according to the formula:
Methods of fracturing a subterranean formation include introducing a fracturing fluid containing an aqueous medium, a viscosifying agent and a polyethylene oxide alkyl ether through a wellbore and into the subterranean formation, pressurizing the fracturing fluid to fracture the subterranean formation, and allowing the fracturing fluid to flow back into the wellbore from the subterranean formation. The polyethylene oxide alkyl ether useful in some embodiments is defined according to the formula:
where R1 and R2 are independently selected from linear or branched alkyl groups having from 2 to 16 carbon atoms, and ‘n’ may be a value selected from within a range of from 1 to 100.
A remote locking system for a blowout preventer (BOP) includes a locking mechanism configured to move to adjust the remote locking system between an unlocked configuration in which the remote locking system enables movement of a ram of the BOP and a locked configuration in which the remote locking system blocks movement of the ram of the BOP. The remote locking system also includes a gear assembly coupled to the locking mechanism, a motor coupled to the gear assembly, and an electronic controller configured to provide a control signal to activate the motor to drive the locking mechanism to move via the gear assembly.
Systems and methods presented herein include a downhole well tool having an electromechanical joint configured to connect to a downhole well tool component within a wellbore of an oil and gas well system. The electromechanical joint is configured to rotate to facilitate connection of the electromechanical joint to the downhole well tool component. For example, the electromechanical joint includes a main body portion, a rotating ring configured to rotate relative to the main body portion to facilitate connection of the electromechanical joint to the downhole well tool component, and a sealed electrical connection configured to couple with a mating electrical connection of the downhole well tool component.
A system for monitoring and optimizing fuel consumption by a genset at an oil rig is described. Gensets require large amounts of fuel to initiate and to maintain in a standby, idling position. The system accesses data in a drill plan to determine the present and future power requirements and initiates gensets if needed; otherwise gensets can be shut down. Excess power can be stored in a power storage unit such as a capacitor, battery, or a liquid air energy storage unit.
H02J 3/46 - Controlling the sharing of output between the generators, converters, or transformers
G05B 19/042 - Programme control other than numerical control, i.e. in sequence controllers or logic controllers using digital processors
H02J 7/14 - Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries for charging batteries from dynamo-electric generators driven at varying speed, e.g. on vehicle
H02J 13/00 - Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
Devices, systems, and methods are provided for a through-rotary centralizer for downhole operations. The through-rotary centralizer assists with centralizing a tool operating downhole, such as a bit. The through-rotary centralizer has a mandrel, a sleeve rotatably mounted around the mandrel, a floating hub slidably mounted around the sleeve, and centralizing arms mounted to the sleeve and floating hub. The centralizing arms extend to exert force against the inner wall of a tubular, such as wellbore casing, thereby providing stability to the downhole tool. Because the sleeve is rotatably mounted to the mandrel, the mandrel rotates within the sleeve and is able to transmit power or torque to the downhole tool, such as a bit. The centralizing arms are not required to rotate with the mandrel due to the rotatably mounted sleeve. A surface system may be used to control the position of the through-rotary centralizer.
A system and method for providing improved control of fluid flow between an interior and an exterior of a tubing string with a multicycle valve system. The multicycle valve having a run-in position, a fracturing position, and a production position. The multicycle valve comprising an outer housing having fracturing ports and production ports. The multicycle valve has a fracturing sleeve which is shifted via pressure applied to a first drop dissolvable ball to open fracturing ports of the multicycle valve. Pressure applied to a second dropped ball shifts an intermediate sleeve to close the fracturing ports and shifts a production sleeve to open production ports. The multicycle valve also has a bypass port allows sufficient fluid to exit the multicycle valve such that an additional ball pump-down operations can still take place uphole of the multicycle valve.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
97.
A METHOD TO ESTABLISH A DETECTABLE LEAK SOURCE LOCATION
Embodiments presented provide for a method for detecting emissions. The method establishes a map that is used with prevailing wind conditions to establish a point source location for methane gas emissions.
Systems and methods for monitoring and control in downhole well applications are provided. The system and methodology may be combined with a variety of completions or other types of well equipment deployed downhole to enable both electrical and fiber optic communication with downhole components. For example, the system enables both electrical and fiber optic communication for operating and monitoring of downhole completion systems or other systems.
A flow assurance digital avatar is provided that combines the simulation of fluid flow through a network of oilfield facilities including reservoirs, wells and pipelines, detection and visualization of possible flow-related issues and risks in the network of oilfield facilities, user evaluation of possible optimizations (what-if scenarios) in the operation of the network of oilfield facilities for fixes and workovers with respect to flow-related issues and risks, and user evaluation and management of possible tasks or actions for the fixes and workovers for the flow-related issues and risks. Other aspects are described and claimed.
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
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
An ammonia production system includes a steam generation device configured to produce steam and an electrolyzer cell configured to produce hydrogen feedstock gas from the steam. A hydrogen combustor receives the hydrogen feedstock gas from the electrolyzer cell and combusts the hydrogen feedstock gas and produce heat and electricity. A combustion thermal conduit provides heat transfer between the hydrogen combustor and the steam generation device. An electrical generator is connected to the hydrogen combustor and configured to generate electricity.
