Abstract: A system for navigating a downhole environment includes a tube body with a flexible material that is formed as a thin-walled tube and a pump that pumps pressured fluid through the tube body. The tube body has at least a section that extends along a horizontal section of a downhole environment by the flexible material pushing out under the pressured fluid. A method for navigating a downhole environment includes providing a tube body with a flexible material which is formed as a thin-walled tube, pumping a first pressure through the tube body to extend the tube body by the flexible material pushing out at tip, and controlling the flexible material to extend the tube body along a horizontal section of a downhole environment.

Abstract: A system includes an electric submersible pump assembly and a control valve assembly. The electric submersible pump assembly transports a fluid in a casing string of a well to a surface location and includes a pump that receives the fluid through a pump intake and vents the fluid through a pump discharge when activated. The electric submersible pump assembly further includes a shaft that is fixed to the pump and extends downhole from the pump. The control valve assembly includes a propeller shaft axially movable along a central axis of the system, a propeller attached to the propeller shaft that pushes the propeller shaft downhole when the pump of the electric submersible pump assembly is active, a shaft coupler that connects the propeller shaft and the shaft of the electric submersible pump assembly, and a stinger that has a conduit for the fluid to flow from the casing string to the pump intake.

Abstract: A system includes an electric submersible pump assembly and a control valve assembly. The electric submersible pump assembly transports a fluid in a casing string of a well to a surface location and includes a pump that receives the fluid through a pump intake and vents the fluid through a pump discharge when activated. The electric submersible pump assembly further includes a shaft that is fixed to the pump and extends downhole from the pump. The control valve assembly includes a propeller shaft axially movable along a central axis of the system, a propeller attached to the propeller shaft that pushes the propeller shaft downhole when the pump of the electric submersible pump assembly is active, a shaft coupler that connects the propeller shaft and the shaft of the electric submersible pump assembly, and a stinger that has a conduit for the fluid to flow from the casing string to the pump intake.

Abstract: A system includes an electric submersible pump and a flow regulating valve. The electrical submersible pump includes a pump that, when activated, receives a fluid disposed within a production tubing of a well through a pump intake and vents the fluid through a pump discharge to a surface location. The flow regulating valve includes a flow tube that blocks the fluid from entering the pump intake when the pump is inactive, a piston, connected to the flow tube, that moves the flow tube within the flow regulating valve, and a stinger that includes a conduit for the fluid to flow from the production tubing to the pump. The flow regulating valve further includes a spring that positions the piston within the flow regulating valve when the pump is inactive and a plurality of seals that pressure-seal a pressure chamber which houses a pressure force that is to be applied upon the piston.

Abstract: A system includes an electric submersible pump (ESP) assembly configured to transport a fluid in a casing string of a well to a surface location. The ESP includes a pump configured to receive, upon activation, the fluid through a pump intake and vent the fluid through a pump discharge; an output shaft extending downhole from and fixed to the pump; and a control valve assembly. The control valve assembly includes a movable core of an electromagnet movable along a central axis of the system; a generator attached to the electromagnet, configured to generate electrical power to pull the movable core in an uphole direction upon activation of the pump of the electric submersible pump assembly; a shaft coupler coupling a generator input shaft and the output shaft; and a stinger having a conduit for the fluid to flow from the casing string to the pump intake.

Abstract: A system includes a subsurface safety valve and a lock tool. The subsurface safety valve is installed within the production tubing and has a main bore delineated by an inner circumferential surface of the subsurface safety valve and a lock profile machined into the inner circumferential surface of the subsurface safety valve. The lock tool is movably disposed around a conduit and has a locking dog configured to engage with the lock profile of the subsurface safety valve and a conduit seal made of a swellable elastomer. The conduit seal is activated by an activation fluid and has an expanded position and an unexpanded position.

Abstract: Systems and methods for providing artificial lift to wellbore fluids includes a pump, a motor, and a protector assembly forming an electric submersible pump system located within a wellbore. A downhole packer is located downhole of the pump. A solids bypass device is located downhole of the pump. The solids bypass device has a flow tube with an inner bore, a bypass stinger that is a tubular member that circumscribes the flow tube, and drain ports extending through a sidewall of the bypass stinger. A sealing cap circumscribes the flow tube. The sealing cap is moveable between an open position, where the sealing cap is positioned to provide an external fluid flow path through the solids bypass device, and a closed position, where the sealing cap prevents fluid from traveling through the external fluid flow path. A biasing member biases the sealing cap towards the open position.

Abstract: Systems and methods for providing artificial lift to wellbore fluids includes a pump, a motor, and a protector assembly forming an electric submersible pump system located in a wellbore. A solids isolator is located between the pump and the protector assembly. The solids isolator includes a tubular discharge body with an inner discharge bore. A body port extends through a sidewall of the discharge body. A sliding seal member is located within the discharge bore and moveable between a port open position where the body port is open to allow fluids to travel through the body port, and a port closed position, where fluids are prevented from traveling through the body port. The sliding seal member is ring shaped in cross section. The sliding seal member is biased to the port closed position when the pump is off and moveable to the port open position when the pump is on.

Abstract: A method of determining a fluid parameter includes receiving, by a processor and from a plurality of sensors coupled to a flexible tube, fluid information. The flexible tube includes a throat arranged in a first position with respect to a fixed end. The fluid information includes a strain or pressure at a first portion of the flexible tube and a strain or pressure at a second portion of the flexible tube. The method also includes determining a first fluid parameter of the fluid and transmitting, from the processor to a controller operationally coupled to the throat, second position information including a second position of the throat different than the first position. The method also includes receiving, with the throat in the second position, second fluid information and determining, based on the second fluid information, a second fluid parameter of the fluid.

Abstract: A downhole tool to log a horizontal or deviated wellbore includes a production unit and a logging unit. The production unit can fluidly couple to a production tubing positioned in a wellbore that includes a vertical portion and a horizontal portion. The production unit can be positioned in the vertical portion. The logging unit is coupled to a downhole end of the production unit. The logging unit includes a tractor and logging sensors. The tractor can detach from the logging unit and carry the sensors through the wellbore downhole of the production unit and into the horizontal portion. The sensors can perform logging operations within the wellbore, and the tractor can carry the sensors back to the logging unit. The tractor can be reattached to the logging unit.

Abstract: A system includes a solids trap disposed in a well. The system includes an inner annulus, an outer annulus, and a chamber between the inner annulus and the outer annulus. A solids accumulation zone is formed in the chamber. A pump is fluidly connected to the solids trap. A fluid stream carrying solids flows from the pump. The fluid stream carrying solids is configured to follow a path delimited by the outer annulus and the chamber until the fluid stream deposits the solids in the solids accumulation zone and departs the solids trap via the inner annulus into a tubing.

Abstract: A motorized pump including a motor and a pump around the motor. The pump rotor is integrated with the motor rotor, wherein the pump rotor has vanes. The motorized pump may be employed as an electrical submersible pump (ESP) in a wellbore.

Abstract: A pump assembly includes multiple impeller stages, each impeller stage including at least one impeller vane. At least one impeller stage includes at least one impeller vane with at least one perforation disposed therethrough.

Abstract: An electrical submersible pump (ESP) including a motorized pump having a motor and a pump and that may be employed in a wellbore. The pump rotor has vanes and the pump stator has vanes. The pump rotor is integrated with the motor rotor, wherein the pump rotor and the motor rotor rotate together.

Abstract: A diagnostics and control system (DCS) for an artificial lift system (ALS) in a well, comprising: a sensor network comprising a plurality of sensors for monitoring and obtaining measurements at a power source of the ALS and at a downhole pump of the ALS; a conditioning subsystem configured to measure ALS system performance data; a processing subsystem configured to receive communications from the conditioning subsystem and comprising a processor configured to process sensor data obtained by the sensor network; and a permanent local wellsite monitor that is controlled by the processing subsystem and is powered using a production controller of the ALS, wherein the permanent local wellsite monitor comprises a central surveillance center for transmitting commands and coordinating testing of the ALS among the sensor network, the conditioning subsystem, and the processing subsystem; wherein a condition of the ALS is evaluated by the permanent local wellsite monitor using the processed sensor data, testing results a

Abstract: A method for mitigating water invasion to a submersible motor includes: forming an accumulation zone within an inner space of the submersible motor, wherein the accumulation zone is disposed at a bottom of the inner space below a motor shaft; measuring a conductivity of a fluid inside the accumulation zone using a sensor, wherein the fluid comprises water and dielectric oil; comparing the conductivity of the fluid with a threshold value; upon detecting that the conductivity of the fluid is greater than the threshold value, activating a solenoid pump to discharge the fluid from the accumulation zone to an outside of the submersible motor.

Abstract: A system includes a solids catcher that is centered with respect to a central axis of a tubing. The system includes an inner annulus, an outer annulus, and a chamber between the inner annulus and the outer annulus. A solids accumulation zone is formed in the chamber. A pump disposed offset from the central axis of the tubing. The pump is fluidly connected to the solids catcher through the outer annulus. A fluid stream carrying solids flowing from the pump. The fluid stream carrying solids is configured to follow a path delimited by the outer annulus and the chamber until the fluid stream deposits the solids in the solids accumulation zone and departs the solids catcher via the inner annulus into a tubing.

Abstract: Systems to drive a downhole pump include an enclosure body with a magnetically transparent wall. A magnetic driver or a stationary member with coil windings in slots is disposed outside the enclosure body. A magnetic follower or a movable member with one or more permanent magnets is disposed inside the enclosure body such that the magnetic follower or movable member is exposed to a different environment compared to the magnetic driver or stationary member. The magnetic driver and magnetic follower, or the stationary member and movable member, are separated by a gap containing at least a portion of the magnetically transparent wall. A prime mover is operatively coupled to the magnetic driver. A rod couples the magnetic follower or the movable member to the downhole pump. Movement of the rod with the magnetic follower or the movable member operates the pump.

Abstract: A first fluid rotor that has a first fluid intake end and a first fluid discharge end. A second fluid rotor that has a second fluid intake end and a second fluid discharge end. The second fluid rotor is rotatably coupled to the first fluid rotor to rotate in unison with the first fluid rotor along a shared rotational axis. The first fluid intake end and the second fluid intake end are facing opposite directions. A first fluid stator surrounds the first fluid rotor. The first fluid rotor and the first fluid stator form a first fluid stage. The second fluid stator is aligned along the rotational axis. The second fluid stator and the second fluid rotor form a second fluid stage. A flow crossover sub is positioned between the first fluid stage and the second fluid stage.

Abstract: A packer, disposed in a deviated portion of a well, seals with an inner wall of the well. A first tubular, extending through the packer, receives a wellbore fluid via first inlet. A first outlet of the first tubular discharges the wellbore fluid into an annulus within the well, uphole of the packer. A second tubular, coupled to the first tubular, receives at least a liquid portion of the wellbore fluid via a second inlet. The second tubular directs the liquid portion of the wellbore fluid to a downhole artificial lift system. A sump, defined by a region of an annulus between the inner wall of the well and the first tubular, receives at least a portion of solid material carried by the wellbore fluid.