Abstract: A downhole shunt tube isolation system having a fluid channel and a piston hydraulic chamber disposed within a valve actuator housing, wherein the fluid channel is sealed via a plug to hydraulically lock a valve in an open position, wherein a gravel slurry is configured to flow from a first tube segment through the valve to a second tube segment when the valve is in the open position. A portion of the plug is displaced to open a fluid path through the plug to the piston hydraulic chamber, wherein opening the fluid path to the piston hydraulic chamber hydraulically unlocks the valve, closing the valve via a biasing force to block the flow of the gravel slurry from a first tube segment through the valve to a second tube segment.

Abstract: A magnetic coupling mechanism in a downhole flow control tool comprising a first chamber within a flow path of wellbore fluids with a first component comprising a Halbach array of magnets. A second chamber isolated from the wellbore environment comprises a second component with a Halbach array of magnets. The first chamber and the second chamber are coupled with a nonmagnetic separation. The second component is translated with the first component by a strong magnetic flux produced by the array of magnets.

Abstract: Provided is a downhole tool and a well system. The downhole tool, in one aspect, includes a tubular providing one or more production fluid flow paths for a production fluid. The downhole tool, according to this aspect, further includes one or more float chambers located within the tubular, and two or more floats located within the one or more float chambers. In one aspect, a first of the two or more floats has a first density (?1) between a density of gas (?g) and a density of oil (?o), and a second of the two or more floats has a second density (?2) between the density of oil (?o) and a density of water (?w). The downhole tool, according to this aspect, further includes two or more non-contact proximity sensors configured to sense a radial location of the two or more floats to determine a gas:oil ratio and oil:water ratio.

Abstract: Various examples of self-contained electrical power generation assemblies are described, the assemblies configured to generate electrical power using a flow of fluid flowing through a conduit configured as part of a wellbore tool or wellbore production tubing, the electrical power generation assemblies configured to be located downhole at various positions along a drill string, a section of production tubing, or some other type of conduit configured to provide a fluid passageway for a flow of one or more types of fluid within a wellbore.

Abstract: A system can be used to recover hydrogen from a geological formation. The system can include a first flow control device and a second flow control device. The first flow control device can be positioned in a wellbore, which can be positioned in a geological formation, to control flow of a first material based on one or more first fluid properties of the first material. The second flow control device can be positioned in the wellbore offset from the first flow control device to control flow of a second material based on one or more second fluid properties of the second material. The second material can be different than the first material and can include hydrogen. The flow of the first material and the flow of the second material can be controlled in response to wellbore fluid being injected into the geological formation to enhance a hydrogen-producing reaction.

Abstract: A fluid flow control device, a well system, and a method are provided. The fluid flow control device, in one aspect, may include an inlet port, allowing a downhole fluid of a borehole to flow into the fluid flow control device, and an outlet port, allowing the downhole fluid to flow out of the fluid flow control device. The fluid flow control device, in accordance with this aspect, may further include a fluid chamber positioned between the inlet port and the outlet port, wherein an electrokinetic film is located within the fluid chamber and is capable of generating a voltage as the downhole fluid flows over the electrokinetic film.

Abstract: An apparatus to be positioned in a wellbore formed in a subsurface formation. The apparatus comprises one or more generators disposed in a flow path within a flow control tool and configured to output electrical power to components of the flow control tool in response to flow of a fluid in the flow path, wherein the fluid enters the flow path from the wellbore. The apparatus comprises a flow rate limiting device disposed in the flow path and configured to control a flow rate of the fluid as the fluid flows to the one or more generators.

Abstract: Shunt closures with a compensating piston and methods of using the same. An example shunt closure includes a compensator piston disposed between an oil chamber and a piston chamber and configured to translate towards the piston chamber to allow for an increase in the volume of the oil chamber. The shunt closure also includes a piston coupling connected to the compensator piston; wherein a portion of the piston coupling is configured to translate into the piston chamber upon translation of the compensator piston. The shunt closure further includes the piston chamber configured to house a portion of the piston coupling and the oil chamber configured to house an oil. Thermal expansion of the oil applies pressure to the compensator piston. The shunt closure also includes a shunt isolation sleeve coupled to and adjacent to the piston chamber.

Abstract: Provided is a support structure and a method for manufacture thereof. The support structure, in one aspect, includes first and second expanded metal structural pillars positioned within the ground by a distance (d1), the first and second expanded metal structural pillars comprising a metal that has expanded in response to hydrolysis. In at least one other aspect, the support structure includes one or more beams spanning the first and second expanded metal structural pillars.

Abstract: Provided is a sealing/anchoring tool, a well system and a method for sealing/anchoring within a wellbore. The sealing/anchoring tool, in one aspect, includes a mandrel and a hydraulically deformable member positioned about the mandrel. The sealing/anchoring tool, in accordance with this aspect, further includes a sealing/anchoring element positioned about the hydraulically deformable member, the sealing/anchoring element including a circlet having an inside surface having an inside diameter (di), an outside surface having an outside diameter (do), a width (w), and a wall thickness (t), the circlet comprising an expandable metal configured to expand in response to hydrolysis to chemically deform the circlet from a radially reduced chemical state to a radially enlarged chemical state.

Abstract: A system can be used to produce brine from a wellbore. The system can include a first flow control device and a second flow control device. The first flow control device can be positioned downhole in a wellbore to control flow of first material based on one or more first fluid properties of the first material. The second flow control device can be positioned downhole in the wellbore offset from the first flow control device to control flow of a second material based on one or more second fluid properties of the second material. The second material can be different than the first material and can include a brine having an alkali metal.

Abstract: A system can be used to recover hydrogen from a geological formation. The system can include a first flow control device and a second flow control device. The first flow control device can be positioned in a wellbore, which can be positioned in a geological formation, to control flow of a first material based on one or more first fluid properties of the first material. The second flow control device can be positioned in the wellbore offset from the first flow control device to control flow of a second material based on one or more second fluid properties of the second material. The second material can be different than the first material and can include hydrogen. The flow of the first material and the flow of the second material can be controlled in response to wellbore fluid being injected into the geological formation to enhance a hydrogen-producing reaction.

Abstract: A lower completion assembly includes a tubular comprising an interior passageway defined by an internal surface of the pipe and a port extending between external and internal surfaces of the tubular. The port is defined by a first surface that extends between the internal and external surfaces. The assembly also includes an inflow control device that is coupled to the external surface of the pipe and that comprises a fluid exit that is adjacent the port. The assembly has a first configuration and a second configuration. When in the first configuration a dissolvable plug extends across the fluid exit to fluidically isolate the fluid exit from the interior passageway and a gap is defined adjacent the first surface. When in the second configuration, the dissolvable plug does not extend across the fluid exit and the fluid exit is in fluid communication with the interior passageway.

Abstract: In some implementations, a clamshell packer for use in a wellbore proximate to a subsurface formation comprises an expandable non-elastomeric material and is configured to annularly envelop a non-compliant portion of a tubular in the wellbore, the non-compliant portion between one or more expandable screens.

Abstract: Regulating downhole fluid flow through a plurality of valves to treat wellbore sections while also allowing for production to continue. If it is determined that fluid flow through a valve of a plurality of valves is below a threshold, maintaining fluid flow through the below threshold valve may be maintained while restricting fluid flow through other valves of the plurality. This restriction fluidly isolates a section of a well from other sections of the well. Once isolated, a treatment substance may be injected through the below threshold valve into the isolated section of well. Afterwards, the closed valves may be reopened while restricting fluid flow through the treated section valve for a threshold period of time. the treated section valve may then be reopened after the threshold period of time.

Abstract: Some implementations include a flow control device positioned in a tubing string within a wellbore formed in a subsurface formation, the flow control device configured to produce a liquid or a gas. The flow control device may comprise a movable restrictor configured to move, in response to the liquid at a first velocity from the subsurface formation, from a closed position to an open position and a pilot-operated valve configured to attenuate a flow of the liquid through the flow control device when the movable restrictor is in the open position.

Abstract: A screen assembly for wellbore production wherein a base pipe is wrapped with a screen constructed one or more cables formed from a plurality of non-metallic fibers bonded to one another with a metal binder. The non-metallic fibers may be basalt fibers or another ceramic material. The metal binder forms a metal matrix that has a first diameter about a primary cable axis, with the metal matrix securing the non-metallic fibers so that they have a second diameter about the primary cable axis, where the second diameter is larger than the first diameter, minimizing exposure of the metal matrix to wellbore fluids.

Abstract: Provided is a fluid flow control system, a well system, and a method. The fluid flow control system, in one aspect, includes a flow restrictor operable to receive production fluid having a pressure (P3) and discharge control fluid having a control pressure (P2), and a fluidic diode placed between the flow restrictor and the tubing, the fluidic diode configured to increase the control pressure (P2) to a higher control pressure (P2++) when the fluidic diode encounters lower viscosity fluids and is configured to increase the control pressure (P2) to a lower control pressure (P2+) when the fluidic diode encounters higher viscosity fluids. The fluid flow control system, in one aspect, further includes an inflow control device having a production fluid inlet, a control inlet operable to receive control fluid having the higher control pressure (P2++) or the lower control pressure (P2+), and a production fluid outlet.

Abstract: Provided is a fluid flow control system, a well system, and a method. The fluid flow control system, in one aspect, includes a fluidic diode operable to receive production fluid having a pressure (P3) and discharge control fluid having a control pressure (P2), and a flow restrictor placed between the fluidic diode and the tubing, the flow restrictor configured to change the control pressure (P2) to a higher control pressure (P2++) when the flow restrictor encounters higher viscosity fluids and is configured to change the control pressure (P2) to a lower control pressure (P2+) when the flow restrictor encounters lower viscosity fluids. The fluid flow control system, in one aspect, further includes an inflow control device having a production fluid inlet, a control inlet operable to receive control fluid having the higher control pressure (P2++) or the lower control pressure (P2+), and a production fluid outlet.

Abstract: A spool valve assembly and methods for use downhole to control fluid flow into a borehole from a downhole formation. The assembly includes a valve body having an interior. The assembly also includes a spool moveable within the valve body interior from a first position wherein the spool prevents flow through the valve body, to a second position wherein the spool allows flow through the valve body at a first flow rate, and to a third position wherein the spool allows flow through the valve body at a second flow rate different than the first flow rate. The spool is moveable from the first position to the second position using hydrostatic fluid pressure acting on the spool from outside the valve body. The spool is moveable from the second position to the third position using gas pressure from a chemical reaction producing a force sufficient to overcome the hydrostatic pressure.