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 well site includes a wellbore extending from a surface to a target reservoir. A production tubing extends into the wellbore from the surface. The production tubing forms a flow conduit from the target reservoir to the surface. A pump is coupled to the production tubing to lift well fluids to the surface. A sand level device is coupled below the pump. The level device includes one or more transmitters to generate and transmit at least two signals down the wellbore and one or more receivers to receive the at least two signals reflected from a surface in the wellbore. A time duration of transmitting and receiving the at least two signals may correspond to a straight-line distance between the sand level device and the surface in the wellbore. The sand level device is configured to send an alarm when the straight-line distance does not suppress a predetermined threshold.

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: 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: 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: An apparatus for gas-liquid separation includes a first separation region that receives a mixture of liquids and gases, at least a portion of the first separation region forms a conical section; a second separation region that receives liquids and gases from the first separation region; and a cross-over section fluidly connecting the second separation region to a tubing.

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 resettable packer system for pumping operations includes an inflatable packer that expands between the resettable packer system and a tubing wall or a casing wall, thereby creating a seal in a well and a pump that inflates the inflatable packer at a desired depth within the well when activated. The resettable packer system further includes an inner sleeve that includes ports for a fluid to pass through, an outer sleeve that is connected to the pump and creates a sealed fluid chamber with the inflatable packer when ports of the outer sleeve and the ports of the inner sleeve are misaligned. In addition, the inner sleeve slides axially along an inner surface of the outer sleeve, thereby aligning or misaligning the ports of the outer sleeve with the ports of the inner sleeve. Further, the inflatable packer contracts when the pump is inactive.

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 shaft in an electrical submersible pumping system is prevented from rotation in a backspin direction, which is in a direction opposite from its typical forward rotation during normal operation. Backspin rotation is prevented with a device that includes teeth coupled to the shaft and a stationary pawl disposed in a rotational path of the teeth. Each tooth has a forward surface that contacts the pawl during forward rotation of the shaft, the forward surfaces are each configured with a profile to slide along and past the pawl without impeding shaft rotation. Rotation in the backspin direction engages the pawl with rearward surfaces of the teeth, which are configured to impede shaft rotation when engaged. Fluid being handled by the pumping system flows through a passage in the device and absorbs friction generated thermal energy from the device.

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: An apparatus for gas-liquid separation includes a first separation region that receives a mixture of liquids and gases, at least a portion of the first separation region forms a conical section; a second separation region that receives liquids and gases from the first separation region; and a cross-over section fluidly connecting the second separation region to a tubing.

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 downhole tool system includes an electrical submersible pump (ESP) assembly configured to couple to a downhole conveyance that includes a production fluid flow path for a production fluid from a subterranean formation; and a logging sub-assembly directly coupled to a downhole end of the ESP assembly and including a length of logging cable spoolable off a cable spool of the logging sub-assembly within a wellbore.

Abstract: A solids collector is disposed at an end of a tubing in a wellbore. At a top of the solids collector, a reservoir fluid stream carrying solids is separated into a solids-liquid stream that is reversed into an annulus in the solids collector and a gas stream that continues to move uphole in the wellbore. At an end of the annulus in the solids collector, the solids-liquid stream is separated into a liquid stream that moves up the tubing and solids that are accumulated in the solids collector.

Abstract: This disclosure relates to an electric submersible pump assembly to measure a density of a fluid in a wellbore. The ESP assembly includes a density meter having a diffuser with an interior volume defined by an inner surface, a rotatable rotor arranged in the interior volume, a measurement channel, and a sensor sub-assembly configured to measure pressures in the measurement channel. The rotor includes a rotor channel defined by a first face of a partition of the rotor and an interior wall of the rotor, extends from an inlet to an outlet. The inlet is arranged at a first radial distance from an axis and the outlet is arranged at a second radial distance from the axis, greater than the first radial distance. The measurement channel, defined by the inner surface of the diffuser and a second face of the partition, extends from the outlet to the inlet.

Abstract: A system includes a first tubing arranged within a second tubing. A first flow path is formed within the second tubing, and a second flow path is formed between the first tubing and the second tubing. A pump is disposed within the first tubing and has a discharge end that is fluidly connected to the first flow path. A seal fitting coupled to a distal end of the first tubing includes a third flow path and a sealing arrangement to isolate the second flow path from a portion of an external environment of the first tubing. A gas separator is positioned to receive a fluid mixture stream from the third flow path and separate the fluid mixture stream into a gas stream that is directed into the second flow path and a liquid-rich fluid stream that is directed into the pump.