Abstract: A self-adjusting gas lift system and corresponding self-adjusting gas lift valve (GLV) are described herein. The self-adjusting gas lift system includes a number of self-adjusting GLVs that fluidically couple an annulus of a well to an interior of a production tubing of the well. Each of the self-adjusting GLVs is configured to open to allow a compressed gas to flow from the annulus to the interior of the production tubing when a pressure differential between an injection pressure of the compressed gas within the annulus and a production pressure of fluids within the production tubing is within an engineered range. Each of the self-adjusting GLVs is also configured to close when the pressure differential is outside the engineered range.

Abstract: A chemically-activated inflow control device. The inflow control device comprises a tubular body configured to be connected in series to joints of sand screen in a wellbore. The tubular body forms a bore that receives a slotted base pipe. At the same time, the tubular body is fluidly connected with the sand screen joints, forming an annular flow path between the slotted base pipe and surrounding sand screen. Production fluids moving into the sand screen pass across a component that degrades in the presence of water. If the well begins producing water, the degradable component will dissolve, activating a sealing mechanism within the inflow control device and closing a restricted flow path. In this way, production fluids are not able to travel from the annular flow path into the bore of the slotted base pipe. A method for completing a wellbore having a chemically-activated inflow control device is also provided.

Abstract: Hydrocarbon wells including gas lift valves and methods of providing gas lift in a hydrocarbon well. The hydrocarbon wells include a wellbore extending within a subsurface region and a downhole tubular extending within the wellbore. The downhole tubular defines a tubular conduit, and the wellbore and the downhole tubular define an annular space therebetween. The hydrocarbon wells also include a lift gas supply system configured to provide a lift gas stream to the annular space and a closure material supply system configured to provide a closure material stream to the annular space. The hydrocarbon wells further includes a gas lift valve operatively attached to the downhole tubular. The gas lift valve includes a lift gas injection conduit and an actuation mechanism. The actuation mechanism selectively transitions to a closed state responsive to contact with the closure material. The methods include methods of operating the hydrocarbon wells.

Abstract: Test systems and methods for evaluating erosion of a test sample. The test systems include a particulate distribution structure configured to receive a supplied particulate stream and to discharge a distributed particulate stream. The test systems also include a particulate acceleration structure configured to receive the distributed particulate stream and to generate an accelerated particulate stream. The test systems further include a test sample fixture configured to hold the test sample at a test sample location positioned such that the accelerated particulate stream is incident upon the test sample location. The methods include methods of operating the test systems.

Abstract: Systems and a method for efficient downhole separation of gas and liquids. An exemplary system provides a downhole gas separator for an artificial lift system. The downhole gas separator includes a separation section. The separation section includes a number of openings over an extended length, and wherein a size of each of the openings, a number openings, or both, is increased as a distance from a production tubing is increased.

Abstract: A method of reducing erosional peak velocity includes arranging a sand control screen assembly in an open hole section of a wellbore, the sand control screen assembly including a base pipe defining a plurality of flow ports, a sand screen arranged about the base pipe, and a wellbore isolation device deployed within an annulus defined between the sand control screen assembly and an inner wall of the wellbore. A fluid from a surrounding subterranean formation is circulated within the annulus, and the fluid within the annulus is diverted through the sand screen and into the base pipe upon approaching the wellbore isolation device. A peak velocity of the fluid flowing through the sand screen is reduced with a peak flux reducing assembly arranged axially adjacent the wellbore isolation device.

Abstract: A self-adjusting gas lift system and corresponding self-adjusting gas lift valve (GLV) are described herein. The self-adjusting gas lift system includes a number of self-adjusting GLVs that fluidically couple an annulus of a well to an interior of a production tubing of the well. Each of the self-adjusting GLVs is configured to open to allow a compressed gas to flow from the annulus to the interior of the production tubing when a pressure differential between an injection pressure of the compressed gas within the annulus and a production pressure of fluids within the production tubing is within an engineered range. Each of the self-adjusting GLVs is also configured to close when the pressure differential is outside the to engineered range.

Abstract: Hydrocarbon wells including gas lift valves and methods of providing gas lift in a hydrocarbon well. The hydrocarbon wells include a wellbore extending within a subsurface region and a downhole tubular extending within the wellbore. The downhole tubular defines a tubular conduit, and the wellbore and the downhole tubular define an annular space therebetween. The hydrocarbon wells also include a lift gas supply system configured to provide a lift gas stream to the annular space and a closure material supply system configured to provide a closure material stream to the annular space. The hydrocarbon wells further includes a gas lift valve operatively attached to the downhole tubular. The gas lift valve includes a lift gas injection conduit and an actuation mechanism. The actuation mechanism selectively transitions to a closed state responsive to contact with the closure material. The methods include methods of operating the hydrocarbon wells.

Abstract: Test systems and methods for evaluating erosion of a test sample. The test systems include a particulate distribution structure configured to receive a supplied particulate stream and to discharge a distributed particulate stream. The test systems also include a particulate acceleration structure configured to receive the distributed particulate stream and to generate an accelerated particulate stream. The test systems further include a test sample fixture configured to hold the test sample at a test sample location positioned such that the accelerated particulate stream is incident upon the test sample location. The methods include methods of operating the test systems.

Abstract: A chemically-activated inflow control device. The inflow control device comprises a tubular body configured to be connected in series to joints of sand screen in a wellbore. The tubular body forms a bore that receives a slotted base pipe. At the same time, the tubular body is fluidly connected with the sand screen joints, forming an annular flow path between the slotted base pipe and surrounding sand screen. Production fluids moving into the sand screen pass across a component that degrades in the presence of water. If the well begins producing water, the degradable component will dissolve, activating a sealing mechanism within the inflow control device and closing a restricted flow path. In this way, production fluids are not able to travel from the annular flow path into the bore of the slotted base pipe. A method for completing a wellbore having a chemically-activated inflow control device is also provided.

Abstract: A valve for a positive displacement pump, designed for use in an artificial lift system. The valve may be either a traveling valve or a standing valve. The valve comprises a cylindrical cage, and includes a ball residing within the cage. In an open position, the ball floats up off of a seat, while in a closed position the ball sealingly lands onto the seat. The cage includes a cone to guide fluid flow after it passes the ball and reduce turbulence and pressure loss through the valve. An intake below the seat gradually reduces in diameter, providing a minimum inner diameter that is less than a diameter of the seat.

Abstract: Systems and a method for efficient downhole separation of gas and liquids. An exemplary system provides a downhole gas separator for an artificial lift system. The downhole gas separator includes a separation section. The separation section includes a number of openings over an extended length, and wherein a size of each of the openings, a number openings, or both, is increased as a distance from a production tubing is increased.

Abstract: A subsurface autonomous inflow control device for a wellbore, the inflow control device comprising a tubular base pipe having one or more through-openings for receiving production fluids within a wellbore. The inflow control device further includes a housing residing along an outer diameter of the tubular base pipe and covering the one or more through-openings. The housing comprises a fluid inlet configured to receive production fluids from a subsurface formation, and a hydrophobic material positioned within the housing between the fluid inlet and the through-openings. The hydrophobic material provides a network of pores that permits a flow of hydrocarbon fluids there through en route to the through-openings, but the hydrophobic material blocks the passage of aqueous fluids there through. A method for completing a wellbore having the porous, hydrophobic inflow control device is also provided.

Abstract: A method of reducing erosional peak velocity includes arranging a sand control screen assembly in an open hole section of a wellbore, the sand control screen assembly including a base pipe defining a plurality of flow ports, a sand screen arranged about the base pipe, and a wellbore isolation device deployed within an annulus defined between the sand control screen assembly and an inner wall of the wellbore. A fluid from a surrounding subterranean formation is circulated within the annulus, and the fluid within the annulus is diverted through the sand screen and into the base pipe upon approaching the wellbore isolation device. A peak velocity of the fluid flowing through the sand screen is reduced with a peak flux reducing assembly arranged axially adjacent the wellbore isolation device.

Abstract: A well screen system having enhanced resistance to erosion, including a tubular defined by a circumferential wall having an outer surface and a first plurality of apertures circumferentially disposed longitudinally along at least a portion thereof, the first plurality of apertures extending radially through the circumferential wall; a series of circumferential channels positioned about the outer surface of the circumferential wall; a plurality of longitudinal ribs positioned adjacent the series of circumferential channels and extending radially therefrom, the plurality of longitudinal ribs forming a series of longitudinal channels; and a wire helically disposed around the tubular, substantially enclosing the series of circumferential channels and the series of longitudinal channels, wherein the series of circumferential channels is structured and arranged to permit fluid communication with the series of longitudinal channels.

Abstract: A method for pyrolyzing organic matter in a subterranean formation includes powering a first generation in situ resistive heating element within an aggregate electrically conductive zone at least partially in a first region of the subterranean formation by transmitting an electrical current between a first electrode pair in electrical contact with the first generation in situ resistive heating element to pyrolyze a second region of the subterranean formation, adjacent the first region, to expand the aggregate electrically conductive zone into the second region, wherein the expanding creates a second generation in situ resistive heating element within the second region and powering the second generation in situ resistive heating element by transmitting an electrical current between a second electrode pair in electrical contact with the second generation in situ resistive heating element to generate heat with the second generation in situ resistive heating element within the second region.

Abstract: Systems and methods for bulk heating of a subsurface formation with at least a pair of electrode assemblies in the subsurface formation are disclosed. The method may include electrically powering the pair of electrode assemblies to resistively heat a subsurface region between the pair of electrode assemblies with electrical current flowing through the subsurface region between the pair of electrode assemblies; flowing a shunt mitigator into at least one of the pair of electrode assemblies; and mitigating a subsurface shunt between the pair of electrode assemblies with the shunt mitigator. Mitigating may be responsive to a shunt indicator that indicates a presence of the subsurface shunt.

Abstract: Systems and methods for improved subterranean granular resistive heaters. The methods may include forming a composite granular resistive heating material. These methods may include determining an expected operating range for an environmental parameter for the composite granular resistive heating material within a subterranean formation, selecting a first material, selecting a second material, and/or generating the composite granular resistive heating material from the first material and the second material. The methods may include forming a granular resistive heater. The methods may include determining the expected operating range and/or locating the composite granular resistive heating material within the subterranean formation.

Abstract: A method for pyrolyzing organic matter in a subterranean formation includes powering a first generation in situ resistive heating element within an aggregate electrically conductive zone at least partially in a first region of the subterranean formation by transmitting an electrical current between a first electrode pair in electrical contact with the first generation in situ resistive heating element to pyrolyze a second region of the subterranean formation, adjacent the first region, to expand the aggregate electrically conductive zone into the second region, wherein the expanding creates a second generation in situ resistive heating element within the second region and powering the second generation in situ resistive heating element by transmitting an electrical current between a second electrode pair in electrical contact with the second generation in situ resistive heating element to generate heat with the second generation in situ resistive heating element within the second region.

Abstract: Systems and methods of detecting an intersection between a wellbore and a subterranean structure that includes a marker material. The systems and methods include drilling the wellbore and determining that the wellbore has intersected a portion of the subterranean structure that includes the marker material by detecting the marker material. The systems and methods also may include distributing the marker material within the subterranean structure, aligning the marker material within the subterranean structure, determining one or more characteristics of the marker material, ceasing the drilling, repeating the method, and/or producing a hydrocarbon from the subterranean structure. The systems and methods further may include forming an electrical connection between an electric current source and a granular resistive heater that forms a portion of the subterranean structure, forming the granular resistive heater, and/or forming the subterranean structure.