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.

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: 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 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: 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 method includes wrapping a packer bag around a deployment tool, providing at least one canister in fluid communication with the packer bag, sending the packer bag around the downhole tool to a downhole location in a well, and injecting a polymer filler material from the at least one canister into the packer bag until the packer bag expands to seal the downhole location.

Abstract: An electrical submersible pumping system includes thrust bearings and radial bearings fabricated from a micro-grained polycrystalline diamond compact (“USPCD”) material that is ultra-strong; and where the USPCD is produced using a catalyst free process. In examples, all components of the bearings are formed from the ultra-strong USPCD material. Pads are in the bearings that have a contact surface, and the pads selectively tilt about a tilt member in response to variations in an opposing contact surface. The tilt members are attached to or otherwise associated with the pads, and are in contact with a resilient member that improves tilting response of the pads. The resilient members are encased in jackets that cover surfaces of the resilient members not in contact with the tilt members. The jackets are set in channels formed in structure of the bearings.

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: A thrust balancing apparatus for a pump includes a housing, a balancing chamber, a connecting tube, a balancing disk, a bushing, a washer, and a pair of upthrust washers. The balancing chamber defines an upper cavity and a lower cavity. The connecting tube is configured to establish fluid communication between the balancing chamber and an exterior of the housing. A first portion of the balancing disk is disposed within the upper cavity. A second portion of the balancing disk passes through the lower cavity. A third portion of the balancing disk is external to the balancing chamber. The washer is disposed between the balancing disk and the bushing. The pair of upthrust washers are disposed between the balancing disk and the balancing chamber.

Abstract: A pump system includes a pump barrel disposed within a housing. A standing valve is disposed at a first end of a pump chamber defined within the pump barrel. A traveling valve is disposed at a second end of the pump chamber. The traveling valve is movable relative to along an axial axis and relative to the housing. A motor stator is disposed inside the housing. produces a rotating electromagnetic field upon receiving electrical power. A motor rotor is rotatably supported within the motor stator and rotates about the axial axis in response to the rotating electromagnetic field. A traveling plug is coupled to the valve body of the traveling body and arranged to move linearly along the axial axis in response to rotation of the motor rotor. The pump system can be disposed in a wellbore to lift fluids up a tubing in the wellbore.

Abstract: A system for hybrid gas lifting may include a gas-lift completion arranged to inject high-pressure gas into production tubing of a well. The system may include a downhole annular jet pump. The downhole annular jet pump may include an annular nozzle arranged to receive the injected high-pressure gas. The injected high-pressure gas exits the annular nozzle as an annular high-velocity gas jet. The downhole annular jet pump may include a throat section arranged to receive the annular high-velocity gas jet, and to mix the annular high-velocity gas jet with a low-pressure production fluid. The downhole annular jet pump may include a diffuser section arranged to facilitate conversion of kinetic energy into pressure energy in a mixture of the annular high-velocity gas jet and the low-pressure production fluid, and to produce the mixture to a surface via the production tubing.

Abstract: One example of a gerotor pump includes an inner rotor comprising multiple teeth, the inner rotor configured to rotate about a first longitudinal gerotor pump axis. The gerotor pump also includes a hollow outer rotor including an outer surface and an inner surface having substantially identical contours, the inner surface configured to engage with the multiple teeth and to rotate about a second longitudinal gerotor pump axis. The pump includes a pump housing within which the inner rotor and the outer rotor are disposed, wherein the outer surface of the outer rotor defines gaps between the pump housing and the outer rotor.

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 system for measuring conditions in a wellbore includes tubing extending into the wellbore. A high power laser having a power greater than 1 kW is operable to deliver a light to a first fiber optic cable. The first fiber optic cable extends axially along a fist surface portion of the tubing and has at least one signal generation gauge located at a predetermined location for producing a generated acoustic signal that propagates outward from the generation gauge and through the tubing. A second fiber optic cable extends axially along a second surface portion of the tubing and is operable to receive a resulting signal of the generated acoustic signal so that wellbore parameters proximate to the predetermined location can be determined. The second fiber optic cable is spaced apart from the first fiber optic cable and is operable to transmit data of the resulting signal to a receiver.

Abstract: A first sand accumulator may include a housing and an insert within the housing. The insert includes axially aligned outer and inner sleeves. In a first position, the outer and inner sleeves both have large flow ports that align to form a continuous flow path for fluid to flow through the sand accumulator such that a vortex flow forms in the sand accumulator. A second sand accumulator may include a housing disposed in line with a wellbore tubular and an insert disposed inside the housing such that insert forms a continuous end-to-end seal with a section of the wellbore tubular. An inlet section of the insert has an inlet port configured to permit fluid flow such that a vortex flow forms in the inlet section. A method of using a sand accumulator includes introducing process fluid entrained with sand to the sand accumulator.

Abstract: A motorized pump system includes a switched reluctance motor with a motor rotor and a motor stator, and a pump surrounding the switched reluctance motor. The motor rotor is positioned radially inward or outward of the motor stator, and the pump includes a pump rotor integrated with the motor rotor. The pump rotor includes at least one impeller connected to the motor rotor.

Abstract: A fluid rotor and a fluid stator. The fluid stator surrounds the fluid rotor. The fluid stator has an intake end and a discharge end. The fluid stator is shaped to be inserted into a wellbore. A shaft passes through a rotational axis of the fluid rotor. The shaft is attached to the fluid rotor to rotate in union with the fluid rotor. The shaft defines a central fluid passage that extends from the intake end of the fluid rotor to the discharge end of the fluid rotor. A balance piston surrounds the shaft. The balance piston extends from an outer surface of the shaft to an inner surface of the fluid stator. The balance piston is positioned at the intake end.

Abstract: A first fluid rotor that has a first fluid intake end and a first fluid discharge end. The first fluid rotor includes a shaft and an impeller. 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. The second fluid rotor includes a second shaft and a second impeller. A first fluid stator surrounds the first fluid rotor. The first fluid stator is aligned along the rotational axis. The first fluid rotor and the first fluid stator form a first fluid stage. A second fluid stator surrounds the second fluid rotor. 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 system for providing artificial lift to wellbore fluids has a pump located within a wellbore and a motor located within the wellbore uphole of the pump. A seal assembly has a first side connected to the motor and a second side connected to the pump. The pump, motor, and seal assembly together form a submersible pump string. An uphole packer circumscribes the production tubular uphole of the motor. A downhole packer is located downhole of the pump. An uphole y-tool has an uphole y-tool first end in fluid communication with the production tubular and an uphole y-tool second end with a first uphole y-tool branch that is mechanically connected to the submersible pump string and a second uphole y-tool branch in fluid communication with a bypass tubular. The bypass tubular is positioned adjacent to the submersible pump string and extends between the uphole y-tool and the downhole packer.