Abstract: The disclosed embodiments include systems and methods to generate electrical power in a downhole environment. In one embodiment, the system includes a thermoelectric generator operable to convert a temperature gradient across a section of the thermoelectric generator into electrical energy and deployed in a wellbore. The system also includes a pressure control device positioned proximate the thermoelectric generator and having a fluid flow path for a fluid flowing through the pressure control device and across the thermoelectric generator such that an absolute pressure of the fluid decreases when the fluid flow out of the pressure control device and across the thermoelectric generator. A temperature of the fluid changes as the fluid flows out of the thermoelectric generator and across the thermoelectric generator due to a change in the absolute pressure of the fluid. The temperature gradient across the thermoelectric generator is due to change in the temperature of the fluid.

Abstract: An example method includes providing fluid communication between an internal bore of a drill string and an annulus between the drill string and a borehole through a fluid channel in a side of a collar coupled to the drill string. Fluid may be circulated through the internal bore of the drill string. A fluid telemetry signal may be generated by selectively generating a vortex within the fluid channel. Providing fluid communication between the internal bore and the annulus through the fluid channel may include providing fluid communication between the internal bore and a vortex basin at least partially defining the fluid channel, through at least one of a first fluid flow path and a second fluid flow path between the vortex basin and the internal bore; and providing fluid communication between the vortex basin and the annulus through a fluid outlet of the vortex basin.

Abstract: Certain embodiments are directed to magnetic rheological packer systems that seal an annulus in a downhole wellbore. In one embodiment, the seal is formed from a two-part epoxy and magnetorheological composition. The epoxy and magnetorheological compositions are allowed to be shaped by a magnetic field provided by one or more magnets exerting a magnetic field to place the packer seal.

Abstract: A completion string can have an outer surface and an inner surface, a first fluid passageway being defined between the outer surface and the inner surface. The inner surface can define an inner region of the completion string and can have a recess that is sized to receive a sleeve that is moveable between an open position and a closed position. The inner region can be sized to receive a work string at a position at which a surface of the work string cooperates with the sleeve and the inner surface of the completion string to define a first chamber on a side of the sleeve, the first chamber being hydraulically sealed by a plurality of sealing elements. The work string can define a second fluid passageway to provide fluid communication with the first chamber.

Abstract: A wellbore apparatus positionable within a wellbore with a tubular string includes a fracturing assembly and a latch. The fracturing assembly includes a housing comprising a flowbore formed therein and a port, a flow control device configured to move with respect to the housing to selectively allow fluid communication from the flowbore to an exterior of the housing through the port, and a wellbore securing device configured to secure the fracturing assembly within the wellbore. The latch is configured to removably couple the fracturing assembly to the tubular string.

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

Abstract: An erosion protection system for closing sleeve assemblies is disclosed. A closing sleeve assembly including a housing; a port formed in the housing; a sealing surface formed in the housing adjacent to the port; a closing sleeve configured to move between an open position, in which a fluid flow through the port is permitted, and a closed position, in which the fluid flow through the port is prevented, the closing sleeve including a seal configured to engage with the sealing surface to form a fluid and pressure tight seal when the closing sleeve is in the closed position; and a protective sleeve configured to extend toward the port to substantially cover the sealing surface when the closing sleeve is moved to the open position and retract away from the port when the closing sleeve is moved to the closed position.

Abstract: The disclosed embodiments include downhole capacitive coupling systems, and methods and apparatuses to provide an electrical connection between two downhole strings. In one embodiment, the system includes a first electrode deployed along an internal surface of a first string deployed in a wellbore, the internal surface being defined by an annulus. The system also includes a second electrode deployed along an external surface of a second string, the second string being deployed within the annulus, and the external surface of the second string and the internal surface of the first string being separated from each other by the annulus. The first electrode and the second electrode are operable to form a first capacitive coupling between said first electrode and said second electrode to transfer electrical current from the second electrode to the first electrode.

Abstract: The disclosed embodiments include systems and methods to generate electrical power in a downhole environment. In one embodiment, the system includes a thermoelectric generator operable to convert a temperature gradient across a section of the thermoelectric generator into electrical energy and deployed in a wellbore. The system also includes a pressure control device positioned proximate the thermoelectric generator and having a fluid flow path for a fluid flowing through the pressure control device and across the thermoelectric generator such that an absolute pressure of the fluid decreases when the fluid flow out of the pressure control device and across the thermoelectric generator. A temperature of the fluid changes as the fluid flows out of the thermoelectric generator and across the thermoelectric generator due to a change in the absolute pressure of the fluid. The temperature gradient across the thermoelectric generator is due to change in the temperature of the fluid.

Abstract: An example method includes providing fluid communication between an internal bore of a drill string and an annulus between the drill string and a borehole through a fluid channel in a side of a collar coupled to the drill string. Fluid may be circulated through the internal bore of the drill string. A fluid telemetry signal may be generated by selectively generating a vortex within the fluid channel. Providing fluid communication between the internal bore and the annulus through the fluid channel may include providing fluid communication between the internal bore and a vortex basin at least partially defining the fluid channel, through at least one of a first fluid flow path and a second fluid flow path between the vortex basin and the internal bore; and providing fluid communication between the vortex basin and the annulus through a fluid outlet of the vortex basin.

Abstract: A downhole tool includes an elongated base pipe and a expandable element disposed on the base pipe and radially expandable from a first configuration to a second configuration. The expandable element includes a first lattice structure that includes a first plurality of connecting members; a second plurality of connecting members movable relative to the first plurality of connecting members to allow the expandable element to radially expand from the first configuration to the second configuration; and a plurality of cells, each of the cells being defined between at least two connecting members. Each of the connecting members from the at least two connecting members is from the first plurality of connecting members or from the second plurality of connecting members. In one or more exemplary embodiments, the first lattice structure is at least partially manufactured using an additive manufacturing process.

Abstract: An example method includes providing fluid communication between an internal bore of a drill string and an annulus between the drill string and a borehole through a fluid channel in a side of a collar coupled to the drill string. Fluid may be circulated through the internal bore of the drill string. A fluid telemetry signal may be generated by selectively generating a vortex within the fluid channel. Providing fluid communication between the internal bore and the annulus through the fluid channel may include providing fluid communication between the internal bore and a vortex basin at least partially defining the fluid channel, through at least one of a first fluid flow path and a second fluid flow path between the vortex basin and the internal bore; and providing fluid communication between the vortex basin and the annulus through a fluid outlet of the vortex basin.

Abstract: A method and apparatus that includes an elongated base pipe having an external surface at least partially defining an external region and an internal surface at least partially defining an internal region; and a pressure maintenance device disposed in the base pipe and includes a first flow path that extends between an opening in the external surface and an opening in the internal surface; a first valve that controls the flow of a first fluid through the first flow path; a first pressure differential sensor that controls the actuation of the first valve and is in fluid communication with the external region; and a pressurized fluid source in fluid communication with the first pressure differential sensor; wherein a first pressure differential threshold associated with the first pressure differential sensor is the difference between a pressure within the external region and the pressurized fluid source.

Abstract: Certain aspects are directed to devices for use in a wellbore in a subterranean formation. There is provided an intervention tool that may be used to set a self-assembling remedial screen, patch, plug, create a remedial isolation zone, conduct remedial securement, or otherwise provide a remedial fix to one or more components of the completion in a downhole configuration. The intervention tool may have a tool shaft, at least two magnets positioned with respect to the tool shaft, a carrier fluid containing magnetically responsive particles, one or more injection ports on the tool shaft, and a fluid deployment system to cause deployment of the carrier fluid out of the tool shaft through the one or more injection ports.

Abstract: An assembly for creating a packer can include a downhole tool positionable within a wellbore. The downhole tool can include an outflow control device that includes a substantially circumferential slot, a port in the slot for receiving a sealant from a reservoir, and a flow restriction device that can be positioned between the substantially circumferential slot and an annulus of the wellbore. The flow restriction device can create a pressure difference between the substantially circumferential slot and the annulus of the wellbore.

Abstract: Included are well systems and methods for use in subterranean formations. An example well system comprises a water front sensor operable to sense a water front, wherein the water front sensor comprises a water front sensor signal transmitter and a water front sensor signal receiver. The example well system further comprises an electronic inflow control device, wherein the electronic inflow control device comprises a flow regulator in fluidic communication with an inlet of the electronic inflow control device and adjustable to provide a flow resistance to a fluid flowing through the electronic inflow control device, and a controller configured to actuate the flow regulator to change the flow resistance through the electronic inflow control device.

Abstract: A hydraulic pump system includes a power source that generates power at a level and is capable of modifying the level. A hydraulic pump is coupled to the power source to receive power and includes an output through which fluid can be displaced at a rate that can be controlled by a solid-state actuator coupled to the hydraulic pump. A fluid line is in fluid communication with the output of the hydraulic pump and fluid can be displaced through the fluid line in a direction, which can be reversed.

Abstract: Certain aspects are directed to self-assembling packers that seal an annulus in a downhole wellbore. In one aspect, the packer is formed from a magnetorheological fluid, which may be a carrier fluid formed from a polymer precursor and magnetically responsive particles. The fluid is allowed to be shaped by a magnetic field provided by one or more magnets exerting a radially extending magnetic field from a tubing section used to place the packer.

Abstract: An example well system includes a base pipe having an interior and defining one or more flow ports, the base pipe being positionable within a wellbore adjacent a subterranean formation. A flow path for a fluid extends between the interior of the base pipe, through the one or more flow ports, and to an exterior of the base pipe. A transverse turbine is positioned in the flow path, the transverse turbine including a rotor and a plurality of blades positioned to receive a flow of the fluid perpendicular to a rotational axis of the rotor. A generator includes one or more magnets rotatable with rotation of the transverse turbine and one or more coil windings mounted on a stator. The flow of the fluid rotates the transverse turbine and rotation of the transverse turbine generates electrical power in the generator.