Abstract: 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.

Abstract: An example laser tool includes a laser head to output a laser beam and a robotic arm that is articulated and that is connected to the laser head. The robotic arm includes segments that are connected by flexible joints to enable movement of the laser head in six degrees of freedom. A control system is configured to control the robotic arm to direct output of the laser beam.

Abstract: A controller and related system and method for controlling a choke for choking fluid flow are configured to take into account non-linear behaviors of the choke, to allow more accurate and effective control of the choke. To obtain a desired pressure drop across a choke valve, the controller is configured to monitor the position of a choke actuator coupled to the choke valve and the pressure at the inlet of the choke valve. The controller calculates an adaptive proportional gain coefficient, and optionally adaptive integral and derivative coefficients, based on the choke actuator position, to help mitigate the effects of non-linear behaviors of the choke and, where necessary, based on the inlet pressure, the controller calculates an augmentation correction to address any instability in the choke. The controller then commands the choke actuator accordingly to adjust the flow area through the choke valve.

Abstract: A method includes training a proxy model to predict output from a reservoir model of a subterranean volume, receiving data representing an oilfield operation performed at least partially in the subterranean volume, predicting one or more performance indicators for the oilfield operation using the proxy model, and updating the reservoir model based at least in part on the one or more performance indicators predicted in the proxy model.

Abstract: Apparatus and methods for measuring the oil to water ratio of a wellbore fluid. An example method includes flowing the wellbore fluid into a flow path of a fluid identification device disposed on the outside of a wellbore tubing and within a wellbore annulus. The fluid identification device comprises a shroud, the flow path disposed within the shroud that opens to the wellbore annulus and fluidically links the wellbore annulus to the wellbore tubing thereby allowing fluid flow through the flow path from the wellbore annulus to the wellbore tubing, and an alternating current electrical sensor disposed within the flow path. The method further includes measuring a property of the wellbore fluid with the alternating current electrical sensor when the wellbore fluid has flowed into the flow path and determining the oil to water ratio of the wellbore fluid that flowed through the flow path.

Abstract: Systems and methods for adjusting the power provided by an electric drive system to an ESP motor through an electrical network based on a model of the system and real-time inputs indicating operating conditions of the system. Some embodiments use a field oriented control system to adjust a direct-axis current setting to generate output power signals which drives the motor at a desired operating point for optimized performance. The electrical network may include a filter, a transformer, and a transmission line. A drive controller may receive real-time operating conditions and motor parameters as input, and may select further system parameters based on the received parameters. The controller builds a model of the electrical network and generates adjustments to the power generated by the drive using the system model and received real-time input. The adjustments may be recalculated at scheduled intervals.

Abstract: A system for sampling groundwater from a well that includes a pump configured to be at least partially submerged in the groundwater within the well and pump the groundwater out of the well, a sensor configured to output a signal indicative of the depth of the groundwater in the well, and a controller in communication with the sensor. The controller is configured to receive the signal indicative of the depth of the groundwater from the sensor and compensate for groundwater ingress into the well by adjusting a rate of flow of groundwater pumped by the pump based on the signal to stabilize the depth of groundwater in the well while the pump is pumping groundwater from the well.

Abstract: Optic fibers are embedded within the body of a casing section making up a wellbore casing string. The optic fibers are used to detect damage or deformation of the casing string over the lifespan of a wellbore.

Abstract: The present disclosure relates to a multi-plunger lift control device for increasing device durability and production efficiency by synchronizing and controlling operating states of a plurality of plunger lifts sharing some production lines. The multi-plunger lift control device according to the present disclosure includes a plunger lift synchronization setting unit configured to set an operation priority of the plurality of plunger lifts so that production stages of the plurality of plunger lifts do not collide, a stage monitoring unit for each plunger lift configured to monitor current production stages of the plurality of plunger lifts, and a plunger lift logic control unit configured to synchronize and control production operations of the plurality of plunger lifts based on the operation priority set by the plunger lift synchronization setting unit and stage monitoring information received from the stage monitoring unit for each plunger lift.

Abstract: A downhole communication includes an antenna winding fixed to an inner surface of a collar. A fluid flow flows through a center of the antenna winding. The antenna winding is wound around a chassis in an antenna channel in the chassis. The chassis is attached to the inner surface of the collar with a seal such that fluid does not travel between the fluid flow and an annulus between the antenna winding and the inner surface of the collar. A difference in diameter between an upper seal and a lower seal results in a net force to push the chassis against a shoulder on the collar.

Abstract: A device for actuating a downhole tool includes a housing having a surface structure on an external surface thereof. The surface structure has an inactive state and an activated state. In the inactive state, the device can travel through seat structures mounted in a well tubing and will experience a physical impact having an impact level exceeding a threshold level when passing through each one of the seat structures. In the activated state, the device can seat in a selected seat in the well tubing. A sensor is enclosed in the housing and configured to generate a signal in response to the physical impact. A controller in the housing communicates with the impact sensor and monitors the physical impacts; and activates the surface structure based on the monitored physical impacts.

Abstract: Systems, methods, and computer-readable media of which the method includes obtaining a knowledge graph comprising elements and relationships that connect together the elements, receiving a raw oilfield data, generating structured oilfield data based on the raw oilfield data, wherein the structured oilfield data represents information about the raw oilfield data, and generating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph. The unstructured data includes data about the raw oilfield data, and one or more of the elements, one or more of the relationships, or both.

Abstract: A computer implemented method of predicting a future maintenance event of a pumping equipment on a wellbore pumping unit comprising loading a pump usage log and a pump maintenance log into a predictive maintenance model. The predictive maintenance model is trained by a machine learning process with a historical database of completed pumping jobs. The predictive maintenance model determines a probability of a future maintenance event in response to the current pump usage. The unit controller displays an alert of the remaining pump life in comparison to a threshold value for a recommended pump maintenance period or a required pump maintenance period.

Abstract: A method for operating a pipeline system includes obtaining sensor data of a gas in the pipeline system from sensors of a sensing unit. The method also includes performing a real-time and closed loop control scheme using the sensor data and a material model of the gas to determine one or more control decisions. The method also includes operating one or more controllable pipeline elements to adjust a temperature, a pressure, a flow rate, or a composition of the gas according to the one or more control decisions.

Abstract: A system can include isolation devices, a flow control device, and an energy transfer device. The isolation devices can be positioned between a wall of a wellbore and a tubular positioned in the wellbore for carrying fluid for geothermal energy transfer. The flow control device can be positioned in the wellbore and between the isolation devices for controlling flow of the fluid between zones of the wellbore for transferring geothermal energy to a surface of the wellbore. The energy transfer device can be positioned at the surface of the wellbore for transferring the geothermal energy from the fluid into usable energy.

Abstract: An electronic apparatus and a method for controlling thereof are provided. The electronic apparatus includes a memory storing an artificial neural network and metadata including information of at least one layer in the artificial neural network, and a processor configured to: acquire a security vector based on the metadata and a security key of the electronic apparatus; map the security vector and the metadata with the security key and identification information of the artificial neural network; perform encryption on the at least one layer based on the metadata and the security vector; based on input data input to the artificial neural network, load the metadata and the security vector by using the security key and the identification information of the artificial neural network; and perform an operation between the input data and the encrypted at least one layer based on the loaded security vector and the metadata.

Abstract: Tracer tracking for control of flow control devices on injection wells includes at least one computer processor executing a reservoir model using numerical tracers to obtain output values for at least one producer well. The numerical tracers are assigned to at least one corresponding injection flow control device in multiple injection flow control devices of an injection well. From the output values at the producer well, a set of volume fraction is calculated for the injection flow control devices. The at least one computer processor solves, using the set of volume fractions, an optimization problem to obtain a flow control device parameter, and stores the flow control device parameter in storage.

Abstract: 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.

Abstract: A side pocket mandrel is configured for use within a gas lift system deployed in a well that has an annular space surrounding the gas lift system. The side pocket mandrel includes a central body that includes a central bore, a gas lift valve pocket, and a gas lift valve installed within the gas lift valve pocket. The side pocket mandrel may also include a motorized choke valve assembly to selectively cover some or all of an internal tubing port extending between the central bore and the gas lift valve pocket. The side pocket mandrel may also include an automatic closing valve assembly configured to automatically close the gas lift valve port when the gas lift valve is removed from the side pocket mandrel.

Abstract: An apparatus for use in fracturing wells includes a body defining and coupled to a wellhead of a well extending through a subsurface formation with the flow path being in communication with a wellbore of the well. The apparatus includes a flow meter in communication with the flow path and configured to measure a flow attribute of fluid from the wellbore along the flow path. The apparatus further includes a computing device communicatively coupled to the flow meter. The computing device is operable to receive a flow attribute measurement from the flow meter and to transmit an indicator in response to determining that the flow attribute measurement indicates interaction of a fracture in the subsurface formation with the well.

Abstract: A control system for controlling extraction of landfill gas, comprising: at least one sensor configured to measure one or more characteristics of landfill gas; at least one flow control mechanism disposed in well piping and configured to control flow of the landfill gas through the well piping; and at least one processor configured to: obtain a measured concentration of a first gas in landfill gas; determine whether the measured concentration of the first gas is either less than a first threshold concentration or greater than a second threshold concentration; when it is determined that the measured concentration is less than the first threshold concentration, control the at least one flow control mechanism to reduce flow rate of landfill gas; and when it is determined that the concentration is greater than the second threshold concentration, control the at least one flow control mechanism to increase the flow rate of landfill gas.

Abstract: A metering unit for the controlled supply of a substance inside an aquarium tank comprises a containment box and a dosimetric pump which is actuated by an electric motor, both being associated with the containment box. The containment box has at least a first connection element and at least a second connection element which is suitable for being connected to a corresponding first connection element of an additional similar metering unit.

Abstract: Methods and systems are provided for controlling gas lift in at least one production well, which determine a quadratic function that relates flow rate or value of oil produced from a production well to gas flow rate for gas injected into the production well based on flow rate measurements for gas injected into the production well and corresponding flow rate measurements of oil produced from the production well. The quadratic function is used to determine an optimal flow rate for gas injected into the production well. The optimal flow rate for gas injected into the production well is used to control the flow rate of gas injected into the production well, and an oil flow rate produced from the production well is measured at the optimal gas flow rate for iterative processing to refine the quadratic function and determination of optimal gas flow rate if need be.

Abstract: Systems, methods, and computer-readable media of which the method includes obtaining a knowledge graph comprising elements and relationships that connect together the elements, receiving a raw oilfield data, generating structured oilfield data based on the raw oilfield data, wherein the structured oilfield data represents information about the raw oilfield data, and generating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph. The unstructured data includes data about the raw oilfield data, and one or more of the elements, one or more of the relationships, or both.

Abstract: Downhole tools and methods for detecting a downhole obstruction within a wellbore. The downhole tools include a positioning mechanism, which is configured to facilitate positioning of the downhole tool within a target region of a wellbore of a hydrocarbon well, an acoustic pulse generator, which is configured to generate an acoustic pulse within a wellbore liquid that extends within the wellbore and fluidly contacts the downhole tool, and a sensor assembly, which is configured to detect a reflected acoustic pulse within the wellbore liquid. The methods include positioning a downhole tool within a target region of a wellbore, generating an acoustic pulse, propagating the acoustic pulse within a wellbore liquid, and reflecting the acoustic pulse from a downhole obstruction. The methods also include propagating a reflected acoustic pulse within the wellbore liquid, receiving the reflected acoustic pulse, and characterizing the downhole obstruction based upon the reflected acoustic pulse.

Abstract: A variable flow resistance system for use with a subterranean well includes a first flow path configured to receive a fluid, a sensor configured to measure a property of the fluid received into the first flow path, and an actuator configured to control an inflow rate of the fluid received into the first flow path based upon the property of the fluid measured by the sensor.

Abstract: A method of unloading and producing liquids from a well uses a plurality of gas injection valves installed on a production tubing. The injection valves are controlled by pressure signals transmitted through a single fluid control line. A first pressure signal is applied to the control line to open the plurality of injection valves. Gas is pumped into the annulus at an injection pressure until a first pressure drop occurs in the injection pressure, the first pressure drop being indicative of gas flowing through a first, upper one of the injection valves. Pumping of gas is continued until a second pressure drop occurs in the injection pressure, the second pressure drop being indicative of gas flowing through a second, lower one of the injection valves. A second, lower pressure signal then is applied to close the first injection valve while leaving the second injection valve open.

Abstract: A virtual sensor system includes one or more electric submersible pumping systems deployed in a reservoir and a computer system that receives data from the one or more electric submersible pumping systems. Field data is provided to computerized statistical models for predicting whether individual electric submersible pumping systems and the reservoir have undergone changes in condition. The statistical models are established with reference data obtained by running electric submersible pumping systems of known working condition in test wells under a variety of controlled conditions.

Abstract: A downhole device for installation in a petroleum well, comprising a sensor, a controller and a power source. The device further comprises an acoustic speaker configured to output a sound signal from the downhole device to a fiber optic cable in the well.

Abstract: A method of predicting hydrocarbon production from one or more artificial lift wells is disclosed. Measurements and/or well test data are obtained from one or more artificial lift wells representing well performance at more than one time period. A statistical model, representing well performance, is generated. Using the statistical model and the measurements and/or well test data, real-time production of the one or more artificial lift wells is predicted and a measure of confidence is generated. Potential optimization opportunities are identified for well performance based on the predicted real-time production of the one or more artificial lift wells. The optimization opportunities are outputted. Hydrocarbon production activities are modified using the optimization opportunities.

Abstract: A method for controlling equipment includes grouping a plurality of granular assets to form one or more general assets and generating models of the general assets based on the granular assets that form the general assets. Each model corresponds to a general asset and defines a relationship between resources produced by the general asset and resources consumed by the general asset. The method includes performing a first control process using the models of the general assets to determine a first allocation of resources among the general assets. The first allocation defines amounts of the resources to be consumed, produced, or stored by each of the general assets. The method includes operating the equipment to consume, produce, or store the resources in accordance with the first allocation.

Abstract: A controller and related system and method for controlling a choke for choking fluid flow are configured to take into account non-linear behaviors of the choke, to allow more accurate and effective control of the choke. To obtain a desired pressure drop across a choke valve, the controller is configured to monitor the position of a choke actuator coupled to the choke valve and the pressure at the inlet of the choke valve. The controller calculates an adaptive proportional gain coefficient, and optionally adaptive integral and derivative coefficients, based on the choke actuator position, to help mitigate the effects of non-linear behaviors of the choke and, where necessary, based on the inlet pressure, the controller calculates an augmentation correction to address any instability in the choke. The controller then commands the choke actuator accordingly to adjust the flow area through the choke valve.

Abstract: Hydrocarbon gas capture from a well stream can involve recovering light hydrocarbon gases from liquids and solids via a multiphase separator that is upstream of a sand removal system. Pressure is controlled in the multiphase separator to facilitate hydrocarbon gas capture. The light hydrocarbon gases can be recovered for sale or can be used on-site.

Abstract: A technique provides a desired control over incremental actuation of hydraulic devices. A hydraulically actuated tool is combined with a control module. The hydraulically actuated tool has an actuator piston positioned in a piston chamber and movable between operating positions. The control module comprises a hydraulic indexing circuit arranged to enable incremental movement of the actuator piston in a first direction and full stroke movement in a second direction based on hydraulic input delivered via control lines. The hydraulic indexing circuit comprises an indexing piston system and at least one check valve working in cooperation with the indexing piston system to enable the incremental and full stroke movements.

Abstract: Systems and methods for harvesting geothermal energy use temperature-based flow control to optimize the extraction of thermal energy from a geothermal reservoir. In one example, a thermal transport fluid is flowed into a wellbore traversing a thermal reservoir of a formation. Flow of the thermal transport fluid into and out of the thermal reservoir is dynamically controlled at each of a plurality of injection and/or return locations in response to a downhole parameter such as temperature. For example, flow may be controlled so that the flow into the thermal reservoir is greater at the injection locations where the temperature is hotter and that the flow out of the thermal reservoir is greater at the return locations where the temperature is hotter. The thermal transport fluid produced from the return locations is then conveyed to surface to extra the thermal energy.

Abstract: Methods and apparatus to control the acoustic properties of optical cables used as in-well oil and gas probes for acoustic monitoring, such as distributed acoustic sensing (DAS). One example aspect provides a solid path for the acoustic wave to propagate from an outside armor layer of the cable to the sensing optical waveguide embedded therein. Another example aspect offers ways to spatially dispose the optical sensing elements to create response delays indicative of the propagation speed and/or direction of an acoustic wave. Yet another example aspect provides ways to utilize additional spectral interrogation to increase ultimate spatial resolution. Yet another example aspect provides ways to locally vary the acoustic properties along the length of the cable.

Abstract: A method of operating a reciprocating system including a rod pump for pumping liquids from a wellbore. The method includes determining rod position of the rod pump using a wave-based technology detector, the rod pump comprising a rod string carrying a down hole pump and a drive system including a drive motor coupled to the rod string through a transmission unit; communicating rod position to a data acquisition system receiving one or more other measurements of rod pump operation to determine rod pump performance; and adjusting at least one operating parameter to enhance rod pump performance. A method of determining operating parameters and optimizing performance of an oil or gas production rod pump, and a system for determining rod position of an oil or gas production rod pump are also provided.

Abstract: A motor of an electric submersible pump (ESP) is positioned in a wellbore. Measured data is received from one or more sensors. A first deep learning model running on a motor controller of the ESP determines first operating parameters or first operating conditions for the ESP based on the measured data. The motor controller sends the first operating parameters or first operating conditions to a centralized computer system. A second deep learning model running on the centralized computer system determines second operating parameters or second operating conditions associated with the ESP based on the first operating parameters or first operating conditions. The centralized computer system sends the second operating parameters or second operating conditions to the motor controller. The motor controller adjusts operation of the motor of the ESP based on the second operating parameters or second operating conditions.

Abstract: Implementations described and claimed herein provide systems and methods for developing a reservoir. In one implementation, a reservoir model is received. The reservoir model includes a static model and a dynamic model. The static model includes one or more clusters of a three-dimensional volume of the reservoir and an uncertainty quantification generated using a neural network. The dynamic model includes pressure values and fluid saturation values propagated across the three-dimensional volume through a nodal connectivity of neighboring clusters. A set of input features is generated from the static model and the dynamic model. The set of input features is related to a drilling attractiveness of a target region of the reservoir using a set of rules executed by a fuzzy inference engine. A quantification of the drilling attractiveness is generated. A recommendation for drilling in the reservoir is output based on the quantification of the drilling attractiveness.

Abstract: Disclosed are perturbation signaling systems and methods for use in a downhole well. Such systems can include a downhole tool configured to hang from a wellbore anchoring mechanism. The tool can have or associate with an energy harvesting system, a power management system, a sensing system, and a wireless communication system. A turbine generator can encode signals into flowing fluid through electric load and related changes in hydraulic energy, transmitting information through the fluid. A receiver station positioned at another well location can decode and or relay the signals. Signals can bypass impediments such as noise zones by inducing signals in adjacent parallel well environments such as an annulus. The receiver station can accumulate energy from repeated redundant signaling over time to enhance communication and signal resolution. An additional wireless communication system can receive and/or relay data to a remote location.

Abstract: Provided is a hydrocarbon well choke system that includes a choke valve and a choke control system adapted to obtain production data from production sensors of the well (e.g., including flowrate, wellhead pressure, wellhead temperature, water cut and gas-oil-ratio (GOR) data obtained by way of respective sensors of the well), generate (based on the data) a well profile that is indicative of the flow of production from the well for different settings of the valve, receive (from a well control system) a target production rate, determine (based on the well profile) whether the rate is obtainable, in response to determining that the rate is obtainable, determine (based on the well profile) a choke setting that corresponds to the rate, and control the choke valve to operate at the setting, and, in response to determining that the rate is not obtainable, communicate (to the well control system) a corresponding alert.

Abstract: A packoff pressure prevention system includes an internal pressure sensor to measure fluid pressure within a drillstring. The system further includes an annular vent to, when open, enable fluid to escape from within the drillstring into an annulus. The system further includes a processor coupled to receive pressure measurements from the internal pressure sensor and coupled to signal the annular vent to open if the fluid pressure within the drillstring rises a first threshold amount over a second threshold time.

Abstract: A method, apparatus, and program product may evaluate a field by receiving a dataset including well measurements collected from a plurality of wells in a field, generating a synthetic dataset from the received dataset by computing a plurality of synthetic samples from the received dataset using a self-organized may (SOM), and propagating one or more models generated from the synthetic dataset to the plurality of wells.

Abstract: A frac tree coupled to a wellhead is connected to either flowback equipment or zipper modules using a single straight-line connection of pipes, valves, and/or frac iron that define a straight-line pathway for fluid, gas, or flowback materials. The disclosed single straight-line connections referenced herein may be used in pressure pumping operations to deliver hydraulic fracturing fluid (“frack fluid”) to a frac tree for delivery to a wellhead or for carrying flowback from the wellhead to a flowback-collecting equipment. Using the single straight-line connections referenced herein dramatically reduces the complexity of connections needed to deliver frack fluid to or carry flowback away from a well, thereby reducing the cost, improving the efficiency, and increasing the safety of pressure-pumping and flowback operations.

Abstract: A method for assessing an optimal acid injection rate in the process of hydrocarbon formation stimulation. The method comprises evaluating an anisotropic diffusion coefficient by pulsed gradient NMR, introduction of a semi-empirical correction based on comparison of the downhole conditions with the library of laboratory experiments where such corrections were measured, extrapolation of the library data to the real downhole conditions. The improved values of the diffusion coefficients are applied in determining wormhole regime conditions that are optimal in terms of acid consumption per a unit of stimulated yield of the hydrocarbon.

Abstract: An embodiment includes a method for use by at least one machine learning classifier. The method comprises the machine learning classifier obtaining one or more recent results from at least one geomechanical simulation; the machine learning classifier comparing the recent results to stored historical data; and, based on the comparing, the machine learning classifier deciding at least one reservoir model for use by at least one reservoir simulation.

Abstract: There is provided an apparatus for controlling flow in a well bore, comprising: a housing defining a fluid passage; a flow control device sealing an outlet of said fluid passage; an actuator for manipulating said flow controller control device to an open condition to permit fluid flow through said outlet; a controller for selectively activating said actuator; an acoustic receiver in communication with said controller, said acoustic receiver configured to receive acoustic signals comprising programming instructions for said controller.

Abstract: A method for monitoring operation of an electric submersible pump. The method includes receiving data signals indicating values for a plurality of parameters regarding operation of the electric submersible pumping system; establishing, for at least some of the plurality of parameters, an associated reference signal; and detecting a deviation of one of the parameters from the reference signal associated with that parameter. As a result of the deviation having a rate of change below a predetermined threshold, the method includes updating the value of the reference signal to reflect the deviation. As a result of the deviation having a rate of change above the predetermined threshold, the method includes detecting an event and generating an indication of the event. The indication of the event further depends on a type of the parameter and a direction of the deviation from the reference signal.

Abstract: A valve system for use in a wellbore, comprising a side pocket mandrel having a main bore for alignment with a wellbore tubular and a laterally offset side pocket bore separated from the main bore by an internal wall, the laterally offset side pocket bore comprising a first receptacle for a first device and a second receptacle for a second device, the internal wall having an opening through which each of the first device and the second device is independently retrievable. There is also provided a side pocket mandrel, a hydrocarbon well and a method of operating a hydrocarbon well.

Abstract: A method for optimizing oil production includes receiving historical production data for one or more wells. A first model is generated based at least partially upon the historical production data. The production in the one or more wells is predicted based at least partially upon the first model. A second model is generated based at least partially on the predicted production. A production allocation is determined in the one or more wells to maximize production based at least partially upon the second model. The production allocation is then implemented.