Abstract: An example method includes introducing a solution into at least part of a reservoir. The solution includes a contrast agent and a fluid. The contrast agent includes a polymer having a dielectric constant that may be greater than a predefined value. The example method also includes using at least one EM transmitter antenna to direct a first electromagnetic (EM) signal into the reservoir. The first EM signal passes through the at least part of the reservoir into which the solution was introduced. The first EM signal is received using at least one EM receiver antenna following passage through the at least part of the reservoir. Data is determined that represents a difference between a first travel time of the first EM signal transmitted through the contrast agent in the reservoir and a second travel time of a second EM signal transmitted through water-saturated reservoir rock. Information about a physical feature of the at least part of the reservoir is generated based on the data.

Abstract: A well completion system and related methods are disclosed. The methods utilize mapped geological formation characterization data based on mechanical specific energy (MSE) values to determine a well completion scenario and executes the well completion scenario.

Abstract: Systems and methods for performing field-wide downhole operations, the field having a plurality of wells. Methods include obtaining, at a computing system, a reference data set associated with the field, the reference data set including at least one property of a downhole formation, obtaining, at the computing system, a first well data set associated with a first well of the field, the first well data set including the at least one property of a downhole formation associated with the first well, calculating a similarity index ratio based on the reference data set and the first well data set, wherein the similarity index ratio indicates a similarity in values of the reference data set and the first well data set, and performing a responsive action based on the calculated similarity index ratio.

Abstract: A system for enhancing a flow of a fluid induced by a rod pumping unit is provided. The system includes one or more sensors and a pumping control unit configured to control stroke movement of the rod pumping unit. The pumping control unit is configured to: (a) initiate at least one stroke of the rod pumping unit; (b) receive sensor data from the one or more sensors; (c) upon determination of a violation of a first set of constraints, make a first adjustment to the current stroke timing, and return to step (a); (d) upon determination of a violation of a second set of constraints, make a second adjustment to the current stroke timing, and return to step (a); and (e) upon determination of no violation of at least one set of constraints make a third adjustment to the current stroke timing, and return to step (a).

Abstract: A system for recovery of gas trapped by fluid and particulate matter in a well includes a device with a lower valve for controlling flow of fluid into the cavity and an upper valve for controlling flow of the fluid and suspended solids out of the cavity. The device also includes: a gas line for providing a stream of pressurized gas to push on fluid in the cavity in a compression stroke which closes the lower valve and opens the upper valve and to exhaust contained gas from the cavity during an exhaust stroke when infiltration of fluid into the cavity raises the fluid level; an effluent line for allowing exit of the fluid and suspended solids during the compression stroke; and a probe line providing powering pair of probes for initiating and halting entry of the stream of pressurized gas into the cavity.

Abstract: A system may include a monitoring device that may receive data associated with one or more properties of a well. The well may produce a flow of hydrocarbons. The monitoring device may receive data associated with the well and determine whether the flow of hydrocarbons includes a percentage of water greater than a threshold based on whether the data is outside a profile associated with the flow of hydrocarbons at the well over time. The monitoring device may then send an alarm notification to another device indicating an increased water cut in the flow of hydrocarbon.

Abstract: A downhole tool for connecting an interior of a casing to a formation, the downhole tool including an inner housing extending along a longitudinal axis X; an outer housing that encloses the inner housing and forms first to fourth chambers; a first piston that separates the first and second chambers; a second piston that separates the third and fourth chambers; a port that is configured to fluidly communicate an outside and inside of the downhole tool; and a stopping mechanism that prevents the second piston from opening the port. The second piston is positioned to separate the port into an outer portion and an inner portion to interrupt a fluid communication between the outside and inside of the downhole tool.

Abstract: A gas injection optimization system is provided. The optimization system is designed to control a volume of gas injected into a wellbore in connection with an intermittent gas-lift system. The system includes a gas storage vessel residing at the surface, and a series of pressure transducers. The system additionally includes a controller configured to receive pressure value signals from the transducers, and in response, send control signals that cyclically open and close a well flow control valve at the surface. When the well flow control valve is closed, compressible fluid is injected into the gas storage vessel to load the vessel. When the well flow control valve is opened, a volume of injection gas (VR) is released from the vessel and is injected into a wellbore annular region to push a volume of fluids (VS) residing in the tubing string to the surface. A method for optimizing gas injection into a wellbore in support of an intermittent gas-lift operation is also provided herein.

Abstract: A fluid injection system is configured to inject a fluid into a well. A sensor is separate from the fluid injection system. A first controller is configured to adjust at least one parameter of the fluid injection system in response to feedback from the sensor. The fluid injection system includes a housing having an electrical connector, a fluid inlet, a fluid outlet, and a fluid path between the fluid inlet and the fluid outlet, a valve disposed along the fluid path, and a flow meter disposed along the fluid path.

Abstract: A drilling apparatus including plurality of subsystems, each subsystem includes a subsystem controller, one or more sensors, and one or more actuators. Each subsystem controller is configured to determine a local subsystem state from measurements received from the one or more sensors and further configured to receive global state estimates and updated control strategies. Each subsystem controller is configured to send command signals to one or more actuators based at least in part on the local subsystem state, global state estimates, and updated control strategy. A method and system for coordinating the control of a plurality of drilling subsystems during drilling operations is provided. A method of drilling subsystem controller decision-making based on a co-player inference playing strategy is further provided.

Abstract: A micro grid for an oil field is powered by a utility power grid. A micro grid controller is adapted to prevent excessive or unstable power draw on the utility power grid while allowing uninterrupted power supply for drilling rigs in the oil field. The micro grid controller is adapted to control operation of one or more pieces of electrical equipment on the drilling rigs. The micro grid controller may prioritize operation of the electrical equipment based on relative priority of the operations or based on an operating condition of the drilling rig.

Abstract: A method for injection of a lift gas into a wellbore production string comprises determining production pressure within the production string, and autonomously controlling a variable orifice gas lift valve in accordance with the determined production pressure, wherein the variable orifice gas lift valve controls the injection flow rate of the lift gas into the production string. A valve comprises a housing defining an inlet, an outlet and a flow path therebetween, and a valve member linearly moveable within the housing between first and second positions to vary flow along the flow path, wherein the valve member is prevented from rotation relative to the housing during linear movement between the first and second positions. The valve further includes a rotary drive and a transmission arrangement interposed between the rotary drive and the valve member for converting rotation of the rotary drive to linear movement of the valve member.

Abstract: A method and an arrangement for operating a process for extracting a fluid in a borehole are optimized. In the case of deep wells, the location of an interface depth in the borehole is detected. A pressure measurement of the pressure at the head of the borehole is made. The pressure in the liquid in the borehole below the interface depth is determined from the measured pressure at the head of the borehole and the detected location of the interface depth. The determination of this pressure is used for regulating the performance of an extracting device for the liquid that is to be extracted.

Abstract: A drill string has a first part and a second part closer to a top of the well. The first part has a drilling head and an annular barrier with a tubular metal part, an expandable metal sleeve and an annular space between the inner face of the expandable metal sleeve and the tubular metal part. Drilling is commenced and then stopped when a loss of formation pressure is detected. A ball is dropped into the drill string and the drill string is pressurized. The expandable metal sleeve is expanded with pressure until the expandable metal sleeve abuts the inner face of the borehole. The second part of the drill string is separated from the first part and pulled out of the borehole. Cement is injected into the borehole above the first part to provide a cement plug above the first part.

Abstract: Some examples can be implemented to determine electric submersible pump efficiency to estimate downhole parameters. At a computer system, a load signal on an in-well type electric submersible pump to transfer fluid through a wellbore is received. At the computer system, a load represented by the received load signal and an expected load on the pump is compared. A difference between the load represented by the received load signal and the expected load based on comparing the load represented by the received load signal and the expected load on the pump is identified.

Abstract: A motor driving control device, together with a controller, included in a motor driving system, has a control circuit controlling drive of a motor according to instruction information transmitted from the controller. The control circuit has a first acquisition unit acquiring setting reference information related to assignment of identification information for the motor driving control device itself, the setting reference information being input from outside, a setting unit setting the motor driving control device's identification information based on a magnitude of a setting voltage input from the outside and the setting reference information, and a second acquisition unit acquiring the instruction information based on the identification information set by the setting unit.

Abstract: A method and apparatus for determining a parameter of a production fluid in a wellbore by providing an initially blocked isolated communication path between a sensor and an aperture formed in a sleeve. The isolated communication path is subsequently unblocked to allow measurements of the parameter of the production fluid.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: A common mode line-to-ground filter is disclosed which includes but is not limited to a resistor, capacitor and a ground. The common mode line to ground filter is connected on a high side of a step-up transformer. A low side of the step-up transformer is connected to a variable frequency drive that provides a semi-sinusoidal voltage waveform. The common mode line to ground filter generates a filtered sinusoidal waveform from the output of the step-up transformer. The filtered sinusoidal voltage waveform is supplied via an electrical cable to an electrically submersible pump deployed downhole.

Abstract: The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for method for determining flow control device (FCD) properties for both an injection well and a production well in coupled injector-producer liquid flooding systems that yields uniform flooding along the production well.

Abstract: An apparatus includes a linear motor and a fluid pump functionally connected to the linear motor. A fluid inlet of the fluid pump is in fluid communication with a fluid source. A fluid outlet of the fluid pump in fluid communication with a well. A pressure sensor is in fluid communication with the well. A controller is functionally coupled to the linear motor and the pressure sensor, wherein the controller is configured to operate the fluid pump to maintain a selected pressure in the well.

Abstract: The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for determining flow control device (FCD) properties for an injection well that yields uniform flooding along the production well.

Abstract: The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for method for determining flow control device (FCD) properties for a production well in coupled injector-producer liquid flooding systems that yields a uniform flooding front along the production well.

Abstract: Methods and systems for increasing the recovery efficiency of a petroleum reservoir. For example, a method for performing a petroleum recovery assessment to increase the recovery efficiency of a petroleum reservoir includes evaluating results associated with a reservoir management analysis for the petroleum reservoir and generating a reservoir management analysis score. The method further includes evaluating results associated with a global benchmark analysis and generating an estimated maximum recovery efficiency for the petroleum reservoir. The method further includes determining key recovery obstacles impeding the petroleum reservoir from achieving the estimated maximum recovery efficiency, and identifying field development opportunities addressing a key recovery obstacle that when implemented, increases a recovery efficiency for the petroleum reservoir closer to the estimated maximum recovery efficiency.

Abstract: An apparatus has been described, including a tubular housing including opposing first and second end portions and defining an interior surface, an exterior surface, and an internal flow passage; an open inflow area extending radially through the tubular housing and adapted to distribute the radial flow of a fluid from the internal flow passage to the wellbore; a closure member extending within the tubular housing and adapted to cover the open inflow area; and a filter defining a plurality of gaps, the filter concentrically disposed about the exterior surface of the tubular housing and extending axially along at least the open inflow area. In an exemplary embodiment, the open inflow area includes a plurality of openings formed radially through the tubular housing and defining a tubular injection interval extending axially along the tubular housing. A system and assembly have also been described, each incorporating elements of the above described apparatus.

Abstract: An apparatus for metering fluid in a subterranean well includes an electric submersible pump having a motor, a seal section and a pump assembly and a metering assembly. The metering assembly includes an upper pipe section with an outer diameter, the upper pipe section having an upper pressure sensing means, and a lower pipe section with an outer diameter smaller than the outer diameter of the upper pipe section, the lower pipe section having a lower pressure sensing means. A power cable is in electronic communication with the electric submersible pump and with the metering assembly.

Abstract: Aspects of the present disclosure generally relate to attenuating the effects of slugging based on one or more measurements of parameters from one or more locations in one or more wells. In some cases, a controller may be configured to attenuate the effects of slugging based on the one or more parameters, for example, by controlling a choke or an artificial lift. In certain aspects, the one or more locations may include downhole or at the surface of the one or more wells.

Abstract: A method, apparatus, and computer readable storage medium perform oilfield-wide optimization in a field with a plurality of wells, with each well including a well flow rate management mechanism controlled by an associated well controller. In a central controller, a network simulation model functioning as a proxy of the field is accessed to determine an optimal allocation solution for the field, and a well-specific control signal is generated for each of the plurality of wells based upon the determined optimal allocation solution. The well-specific control signal for each of the plurality of wells is communicated to cause the associated well controller to control a flow rate management parameter associated with the well flow rate management mechanism for the well.

Abstract: A distance of a water flow path and a velocity of the water flow are calculated using data obtained from both a pulsed neutron sensor and distributed acoustic sensors. The two distance and velocity values are compared to obtain a first calculated distance and velocity. The distance of the water flow path and the velocity of the water flow are calculated using the Doppler data obtained from distributed Doppler sensors. The distance and velocity values are compared with the first calculated distance and first calculated velocity to obtain a second calculated distance and velocity values. The distance of the water flow path and the velocity of the water flow are calculated using temperature data obtained from distributed temperature sensors. The distance and velocity values are compared with the second calculated distance and velocity to determine a distance of a cement interface, and a velocity of a water flow therein.

Abstract: The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for determining flow control device properties for an injection well that would yield to a prescribed uniform or non-uniform accumulated injection profile along a production well.

Abstract: The present invention includes a method, apparatus, and computer readable medium for controlling a valve. Example embodiments of the present invention described herein utilize a soft cutoff threshold and soft cutoff procedure at which point the controller monotonically ramps a servo set-point to slowly overdrive the servo beyond a calibrated set-point range, wherein the servo transitions into a hard cutoff when the servo set-point reaches a predefined overdrive threshold.

Abstract: A computer-implemented method is provided for determining properties of a formation traversed by a well or wellbore. A formation model describing formation properties at an interval-of-interest within the well or wellbore is derived from measured sonic data, resistivity data, and density data for the interval-of-interest. The formation model is used as input to a plurality of petrophysical transforms and corresponding tool response simulators that derive simulated sonic data, resistivity data, and density data for the interval-of-interest. The measured sonic data, resistivity data, and density data for the interval-of-interest and the simulated sonic data, resistivity data, and density data for the interval-of-interest are used by an inversion process to refine the formation model and determine properties of the formation at the interval-of-interest. In embodiments, properties of the formation may be radial profiles for porosity, water saturation, gas or oil saturation, or pore aspect ratio.

Abstract: Methods for making a threaded connection between an upper tubular and a lower tubular using an oilfield tubular spinner and a torque wrench, including holding the lower tubular with the torque wrench, frictionally engaging the upper tubular with the tubular spinner, operating a motor of the tubular spinner to spin-in and shoulder-up a tubular connection between the upper tubular and the lower tubular, establishing a threshold hydraulic system pressure that indicates a shouldered-up condition, monitoring, with a detection system, a hydraulic system pressure of the motor during spin-in and shoulder-up, and maintaining the threshold hydraulic system pressure to operate the motor for a selected period of time after the threshold hydraulic system pressure is reached. An oilfield tubular spinner for an oilfield tubular wrench is also provided.

Abstract: Methods and an apparatus to facilitate the creation of casing exit openings in the casing of parent wellbores. Methods and systems for azimuthally and longitudinally aligning drilling assemblies through openings in a parent wellbore casing to allow for drilling multiple lateral wellbores extending outwardly from a parent wellbore. A method of stimulating one or more subterranean zones intersected by multiple lateral wellbores extending outwardly from one or more patent wellbores includes the steps of: simultaneously injecting a stimulation fluid into the lateral wellbores; and stimulating the zones intersected by the lateral wellbores in response to the stimulation fluid injecting step.

Abstract: A process for determining a location and size of a gas source within an area with a spectrometer gas monitor includes: providing the spectrometer gas monitor; performing fence line monitoring of the area with the spectrometer gas monitor; collecting spectroscopic data over multiple open paths around the area with the spectrometer gas monitor; measuring atmospheric conditions along gas inflows and gas outflows of the area; subtracting a background for a selected gas from the spectroscopic data; applying a boundary constraint to the spectroscopic data; determining an atmospheric concentration of air entering the area; applying bootstrapping to the spectroscopic data; applying zero minimum elimination to the spectroscopic data; and producing inversion data from the spectroscopic data to determine the location and size of the gas source within the area.

Abstract: Disclosed techniques include a method of removing wellbore liquid from a wellbore that extends within a subterranean formation, comprising positioning a pump downhole in the wellbore, electrically powering the pump, expanding and contracting a membrane by pumping a fluid with the pump, wherein expanding and contracting the membrane creates a pressure for removing the wellbore liquid from the well, and removing the wellbore liquid from the well using the pressure.

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: An example well system including a drill string extending from a surface location into a wellbore and defining an annulus between the drill string and the wellbore, a fluid circuit extending through the drill string to a bottom of the wellbore and back to the surface location within the annulus, and further extending back to the drill string from the annulus, and one or more flow imaging devices in fluid communication with the fluid circuit to monitor the wellbore fluid and track a real-time particle size distribution (PSD) of one or more particulates suspended within the wellbore fluid.

Abstract: Real-time dynamic process modeling in an online model-based process control computing environment. A solver system utilizes an oracle to implement adaptive algorithms for a mixed integer nonlinear programming (MINLP) solver and a nonlinear programming (NLP) solver.

Abstract: A system and method for providing artificial lift to production fluids within a subterranean well includes loading an electrical submersible pump assembly into an interior cavity of a pump launcher. The electrical submersible pump assembly has a motor and a pump. The pump launcher is releasably secured to a wellhead so that the interior cavity is in fluid communication with an inner bore of a production tubing that extends a length into the subterranean well. A propulsion system is activated to move the electrical submersible pump assembly from the pump launcher and into the subterranean well, wherein the propulsion system includes a self-powered robotic system having a propulsion mechanism. The propulsion system can be communicated with to control the descent of the electrical submersible pump assembly through the subterranean well.

Abstract: A method for operating an electrical submersible pump, ESP, lifted well, the method comprising: measuring a characteristic of the well or a characteristic of a device associated with the well; generating a first control signal for instructing a change in the operation of the ESP; generating a second control signal for instructing a change in the operation of a further device associated with the well; wherein a degree of change in each of the first and second control signals is dependent on the outcome of the measuring and on a known effect caused by sending at least one of said first control signal to the ESP or said second control signal to the further device associated with the well; and sending the first control signal to the ESP and the second control signal to the further device associated with the well.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: A method, apparatus, and program product evaluate fracture abundance in a subsurface formation by modeling a fracture network in a three-dimensional volume using geometric primitives. A fracture abundance parameter, e.g., a P32 fracture density, may be determined in part based upon the combined areas of the primitives with cells of a three-dimensional grid.

Abstract: A method for monitoring an electric submersible pump. The method includes acquiring a baseline signature for the electric submersible pump in a first environment, acquiring a downhole signature for the electric submersible pump in a downhole environment while the electric submersible pump is confirmed to be healthy, applying an operator to the baseline signature and the downhole signature that results in a downhole noise component, acquiring a vibration signature for the electric submersible pump in the downhole environment while the electric submersible pump is in an operating mode, removing the downhole noise component from the vibration signature to produce an isolated electric submersible pump signature, and determining a health status of the electric submersible pump based on the isolated electric submersible pump signature.

Abstract: A pump device for extracting one or more resources includes a pump apparatus, a processor configured for receiving information from one or more sensors and sending instructions to one or more electronic controls, where the sensors and the electronic controls are each placed proximate to a respective component of the pump apparatus, and a network interface configured for sending and receiving communication from a device through a network.

Abstract: Systems and methods for monitoring and characterizing fluids in subterranean formations are provided. In one embodiment, a method for monitoring a well bore is provided, the method including: providing a first quantity of one or more noble gases of a known volume; circulating at least a portion of the fluid and the one or more noble gases in a portion of the well bore; detecting a second quantity of the noble gases in a portion of the fluid that has been circulated in a portion of the well bore; and determining one or more parameters relating to the well bore (e.g., well bore volume, lag time, flow characteristics, and/or efficiency of a gas extraction system) based on the quantities of the noble gases provided and/or detected in the fluid and/or the relative times at which the noble gases are provided or detected.

Abstract: A system including a controller configured to receive feedback from at least one sensor configured to monitor a fluid flow of a hydrocarbon extraction system. The fluid flow includes water and an injected chemical. Additionally, the controller is configured to determine a ratio of the injected chemical to water in the fluid flow.

Abstract: A flow control method and assembly for an oil or gas well comprises generating a pressure signature in the fluid in a bore of the well comprising a minimum rate of change of pressure, and transmitting the pressure signature to a control mechanism to trigger a change in the configuration of a flow control device in the bore in response to the detection of the pressure signature in the fluid. The flow control device can comprise a barrier, such as a flapper, sleeve, valve or similar. The pressure signature is transmitted via fluid flowing in the bore, typically being injected into the well, optionally during or before frac operations, via fluid being used for the frac operations. The control mechanism typically includes an RFID reader to receive RF signals from tags deployed in the fluid flowing in the bore.

Abstract: A system, method and apparatus for autonomous data collection from variable frequency drives (VFD) is described. The system includes at least two embedded control systems, each built on a commercial platform, with customized components in transportable cases. A computer program with multiple instantiations operates on the at least two embedded control systems to provide a client-server implementation of data collection and recording units. The units communicate by Wi-Fi autonomously when the client comes within range of the server. Units do not require any direct intervention by technicians to gather and store VFD system data. The client is a mobile unit is installed in a field truck operated by a driver without the training to operate a VFD. When the mobile unit obtains a communications link to a central receiving server, the unit uploads its data for processing in a processing system.

Abstract: Evaluating annulus-tubing communication points in a production well having an annulus between a production string and a surrounding string(s) of casing. Determining a composition of production fluids produced from the well, and injecting one or more tracer materials into the annulus of the well under pressure as part of a lift gas. Each of the one or more tracer materials defines a material that is not native to the production fluids, and each has a different rate of diffusivity in the lift gas. The tracer materials are detected upon being produced at the surface. A mass spectrometer or other analyzer capable of detecting tracer materials at concentrations of less than 1,000 ppm is used. Determining injection points of the one or more tracer materials, and determining whether each of the injection points represents a gas lift valve along the production tubing.