Abstract: Provided is a fluid flow control system and a well system. The fluid flow control system, in one aspect, includes a valve having a fluid inlet operable to receive fluid, a control inlet operable to receive a control fluid, and a fluid outlet operable to pass the fluid to the tubing, the valve configured to open or close the fluid outlet based upon the control fluid. The fluid flow control system according to this aspect further includes a density control valve having an inlet conduit operable to receive the fluid and an outlet conduit coupled to the control inlet of the valve, the density control valve operable to send the control fluid to the valve to open or close the fluid outlet based upon a density of the fluid.

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: Provided is a downhole tool, a method for sealing within a well system, and a well system. The downhole tool, in at least one aspect, includes a tubular, and a collection of individual separate chunks of expandable metal positioned about the tubular, the collection of individual separate chunks of expandable metal comprising a metal configured to expand in response to hydrolysis.

Abstract: Provided is a downhole tool, a method for sealing within a well system, and a well system. The downhole tool, in at least one aspect, includes a tubular, and one or more expandable metal seal elements placed about the tubular. In at least one aspect, the one or more expandable metal seal elements comprise a metal configured to expand in response to hydrolysis and have a surface-area-to-volume ratio (SA:V) of at least 2 cm?1.

Abstract: Provided is a sealing tool, a method for sealing an annulus within a wellbore, and a well system. The sealing tool, in at least one aspect, includes a sealing assembly positioned about a mandrel. In at least one aspect, the sealing assembly includes one or more elastomeric sealing elements having a width (WSE), the one or more elastomeric sealing elements operable to move between a radially relaxed state and a radially expanded state. In at least this aspect, the sealing assembly includes a pair of expandable metal features straddling the one or more elastomeric sealing elements, each of the pair of expandable metal features comprising a metal configured to expand in response to hydrolysis and having a width (WEM), and further wherein the width (WSE) is at least three times the width (WEM).

Abstract: A downhole sealing tool and method use a swellable material (e.g., a swellable rubber or a swellable metallic material) with increased surface area for faster reaction with an activation fluid. In one example, a swellable metallic sealing element and actuator are carried on a tool mandrel for lowering into a wellbore on a conveyance. The sealing element includes a plurality of expandable metal wires supported along the tool mandrel. The expandable metal wires comprise a swellable metallic material that swells in response to exposure to an activation fluid. The actuator is used to separate at least a portion of the expandable metal wires, to increase a surface area exposed to the activation fluid and thereby accelerate the reaction.

Abstract: Some implementations include a system configured for subsurface energy storage, the system comprising: at least a first wellbore drilled into one or more subsurface formations; a first downhole accumulator having a first fluid; and a first subsurface storage zone including a second fluid and the first downhole accumulator.

Abstract: A flow control system for use in controlling flow of a fluid composition in a subterranean well is disclosed. The flow control system includes a flow chamber that includes an inlet and an outlet oriented such that the fluid composition flows circuitously through the chamber, forming a vortex at least at the outlet. The flow control system further comprises at least one flow control structure shaped and positioned in the flow chamber such that a velocity of the circuitous flow is reduced and the vortex is eliminated or substantially reduced.

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: An apparatus to be positioned in a geothermal wellbore formed in a subsurface formation. The apparatus comprises one or more components to inject a supercritical fluid into the subsurface formation. The apparatus comprises a flow control assembly configured to control flow of the supercritical fluid into the geothermal wellbore based on a density of the supercritical fluid in the subsurface formation.

Abstract: A downhole power generation system may include a downhole tubular having a generator recess. The generator recess is radially offset from a central bore of the downhole tubular, and the generator recess is connected to the central bore via an opening. The system may further include a generator disposed at least partially within the generator recess. Additionally, the system may include at least one turbine blade configured to drive rotation of the rotor in response to fluid flow through the central bore with the at least one turbine blade in an extended position. The at least one turbine blade is disposed at least partially within the central bore in the extended position, and the at least one turbine blade is configured to move at least partially into the generator recess toward a retracted position in response to contact with a downhole tool moving along the central bore.

Abstract: An inflow control device for a well that may include a chamber, a cavity fluidly connected to the chamber, wherein the cavity comprises a seat, a fluid passageway fluidly connected to the cavity, and an actuator at least partially disposed within the chamber and at least partially disposed in the cavity. The inflow control device may further include a hydraulic passageway fluidly connected to the chamber, a fluid pressure storage fluidly connected to both the hydraulic passageway, and a solenoid disposed on the hydraulic passageway and configured to control a flow of a hydraulic fluid from the fluid pressure storage to the chamber. The method may include receiving a fluid from a formation with an inflow control device (ICD) disposed on a tubular string within a formation and adjusting the actuator within the chamber and the cavity using the solenoid.

Abstract: An inflow control device and method of use. The device may include a chamber, wherein the chamber comprises a seat. The device may further include a fluid passageway fluidly connected to the chamber, an actuator disposed within the chamber, and a motor at least partially disposed in the chamber and detachably connected to the actuator by a detachable connector. The method of using the inflow control device may include receiving a fluid from a formation with an inflow control device (ICD) disposed on a tubular string within a formation and stopping flow of the fluid through the ICD by seating the actuator to the seat after the actuator has detached from the motor by the detachable connector.

Abstract: A downhole power generation system may include a downhole tubular having a generator recess. The generator recess is radially offset from a central bore of the downhole tubular, and the generator recess is connected to the central bore via an opening. The system may further include a generator disposed at least partially within the generator recess. Additionally, the system may include at least one turbine blade configured to drive rotation of the rotor in response to fluid flow through the central bore with the at least one turbine blade in an extended position. The at least one turbine blade is disposed at least partially within the central bore in the extended position, and the at least one turbine blade is configured to move at least partially into the generator recess toward a retracted position in response to contact with a downhole tool moving along the central bore.

Abstract: A magnet shield for use with a magnetic scale inhibitor includes a barrier configured for positioning at a location between the magnetic scale inhibitor and a flowbore for at least a first time period. The flowbore is configured for flow of a fluid. The barrier is: degradable in the fluid, such that, after the first time period, the barrier is no longer present at the location; and/or shiftable, such that, after the first time period, the barrier can be shifted away from the location. During the first time period, the barrier reduces or eliminates attraction of ferromagnetic particles to magnets of the magnetic scale inhibitor. A magnetic scale inhibitor tool comprising the magnet shield and a methods of utilizing the magnet shield and the magnetic scale inhibitor tool comprising the magnet shield are also provided herein.

Abstract: A Carbon Capture and Storage (CCS) system and method generates electricity by applying a supercritical fluid to an expansion turbine connected to a generator. The expansion turbine sends the fluid from the expansion turbine to a compressor after expansion. The compressor compresses the fluid output by the expansion turbine into a desired supercritical state and the compressed fluid is injected into one or more first sequestration reservoirs in a reservoir formation.

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.