Abstract: In some embodiments, a method for controlling fluid flow through a downhole pump system in a borehole includes moving, via a downhole pump residing below a tubular in the borehole, a first fluid through the tubular, wherein the first fluid includes a compressible fluid. The method may further include increasing an intake pressure of the downhole pump while the first fluid is moving via a control valve system comprising a throttling valve.

Abstract: A downhole gas separator fluid mover assembly comprising a fluid mover having an inlet and an outlet, a separation device, a separation chamber, and a flow path separator located downstream of the fluid mover. The fluid mover comprising a centrifugal pump stage with an impeller and a diffuser moves production fluid comprising a high viscosity fluid portion and a gas portion to the separation device. The separation device produces a fluid motion that separates the gas phase from the liquid phase in response to the flow rate of production fluid from the fluid mover. A portion of the high viscosity fluid passes through the gas phase discharge port in response to the over-supply of high viscosity fluid to the liquid discharge port in response to the flow rate of the production fluid through the fluid mover.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator comprising a plurality of gas phase discharge ports, and at least one liquid phase discharge port, wherein the gas separator is located uphole of the fluid intake; a centrifugal pump comprising a fluid inlet at a downhole end, wherein the at least one liquid phase discharge port of the gas separator is fluidically coupled to the fluid inlet of the centrifugal pump; and an inverted shroud assembly, wherein a downhole end of the inverted shroud assembly is coupled to an outside of the gas separator downhole of the gas phase discharge ports of the gas separator and uphole of the fluid intake.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section; a fluid intake; a charge pump assembly located downstream of the fluid intake and having an inlet in fluid communication with an outlet of the fluid intake, having a fluid mover coupled to a drive shaft, and having a fluid reservoir located downstream of the fluid mover; a gas separator located downstream of the charge pump assembly and having an inlet in fluid communication with an outlet of the charge pump assembly; an inverted shroud coupled at an upper end to the gas separator or to the charge pump assembly and coupled at a lower end to the ESP assembly below the fluid intake; and a production pump assembly located downstream of the gas separator and having an inlet in fluid communication with a liquid phase discharge port of the gas separator.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator comprising a plurality of gas phase discharge ports, and at least one liquid phase discharge port, wherein the gas separator is located uphole of the fluid intake; a centrifugal pump comprising a fluid inlet at a downhole end, wherein the at least one liquid phase discharge port of the gas separator is fluidically coupled to the fluid inlet of the centrifugal pump; and an inverted shroud assembly, wherein a downhole end of the inverted shroud assembly is coupled to an outside of the gas separator downhole of the gas phase discharge ports of the gas separator and uphole of the fluid intake.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to an uphole end of the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator coupled to an uphole end of the fluid intake, wherein the gas separator has a plurality of gas phase discharge ports; a pump assembly coupled to an uphole end of the gas separator; and an intake extension tubular, wherein an uphole end of the intake extension tubular is coupled to the fluid intake uphole of the inlet ports, and wherein an annulus defined between an inside of the intake extension tubular and an outside of the seal section defines a fluid flow path from a downhole end of the intake extension tubular to the inlet ports of the fluid intake.

Abstract: A pump system for pumping production fluids from a wellbore or pumping well treatment fluids into a wellbore comprising: an axial flux electric motor; a seal section coupled to the axial flux motor; a pump intake coupled to the seal section; a pump coupled to the pump intake, and a fluid discharge coupled to the pump. The torque capacity axial flux motor may be modified without removing the axial flux motor from the pump.

Abstract: A pump system for pumping production fluids from a wellbore or pumping well treatment fluids into a wellbore comprising: an axial flux electric motor; a seal section coupled to the axial flux motor; a pump intake coupled to the seal section; a pump coupled to the pump intake, and a fluid discharge coupled to the pump. The torque capacity axial flux motor may be modified without removing the axial flux motor from the pump.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section; a fluid intake; a charge pump assembly located downstream of the fluid intake and having an inlet in fluid communication with an outlet of the fluid intake, having a fluid mover coupled to a drive shaft, and having a fluid reservoir located downstream of the fluid mover; a gas separator assembly located downstream of the charge pump assembly and having an inlet in fluid communication with an outlet of the charge pump assembly; and a production pump assembly located downstream of the gas separator assembly and having an inlet in fluid communication with a liquid phase discharge port of the gas separator assembly.

Abstract: A coupling includes an inner surface configured to receive a shaft of an electric submersible pump system through the inner surface. The coupling also includes an outer surface having a torsional undercut into the coupling, where the torsional undercut is configured to induce a failure of the coupling prior to a failure of the shaft.

Abstract: In artificial lift production systems, a reduction in pressure and temperature as production fluids migrate to the surface can cause a buildup in the production tubing that reduces or stops production. To remove buildup, an ESP can be operated at low efficiency and low flow operating conditions to generate heat in the pump. The heat increases the temperature of the production fluid in the pump. When the heated production fluid is transported to the surface, the fluid increases the temperature of the production tubing resulting in a melting of the solidified wax blocking the production tubing. As the wax melts, the production fluid carries it toward the surface. Over time, the heated production fluid will melt enough solidified wax to open the production tubing to a full flow capacity, thus allowing standard production operation to continue.

Abstract: Provided, in one aspect, is a spin control valve assembly, comprising a stationary valve plate having a first stationary valve plate opening and a second stationary valve plate opening; and a rotating valve plate coupled longitudinally adjacent to the stationary valve plate, the rotating valve plate having a rotating valve plate opening, wherein the rotating valve plate is configured to rotate among at least three positions such that at each position of the at least three positions fluid flows at a different flow rate through the spin control valve assembly.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises a centrifugal pump, an electric motor mechanically coupled by a drive shaft to the centrifugal pump, wherein the electric motor comprises a stator and a rotor, a bearing, wherein the bearing is disposed inside the electric motor, and a magnetic shield disposed in the electric motor between bearing and the rotor and stator.

Abstract: A downhole integral gas separator and pump assembly, The assembly comprises a drive shaft; a separation chamber concentrically disposed around the drive shaft; a gas flow path and liquid flow path separator having a gas phase discharge port open to an exterior of the assembly, and having a liquid phase discharge port; a fluid mover mechanically coupled to the drive shaft having an inlet fluidically coupled to the liquid phase discharge port of the gas flow path and liquid flow path separator, and having an outlet; a housing that retains the drive shaft, the gas flow path and liquid flow path separator, and the fluid mover; and a pump discharge coupled to a downstream end of the housing, wherein the pump discharge is fluidically coupled to the outlet of the fluid mover and is configured to connect to a production tubing.

Abstract: Pumping of wellbore fluid to a surface may have a detrimental effect on the pump performance due to high gas concentrations in the fluid. A pump system that utilizes a helix gas separator provides greater pump efficiency by effectively removing the gas phase of the fluid. The wellbore fluid received at a pump system is directed from an intake to a gas separator that utilizes a stationary auger. The stationary auger induces rotational motion of the wellbore fluid causing the wellbore fluid to separate into a gas phase and a liquid phase. The stationary auger utilizes a tapered diameter and an opening between one or more helixes or vanes to separate a gas phase more efficiently from a liquid phase of a fluid.

Abstract: Methods to improve fluid flow of a multi-phase mixture, methods to separate fluids of a multi-phase mixture, and downhole multi-phase fluid mixture systems are disclosed. A method to improve fluid flow of a multi-phase mixture includes positioning a first acoustic device and a second acoustic device around a conveyance that provides a fluid flow path for a first fluid in a first phase and a second fluid in a second phase to simultaneously flow through the conveyance. The method also includes determining a flow rate and a fluid condition of the fluid mixture. The method further includes generating a standing acoustic wave through the conveyance based on the flow rate and the fluid condition to break down the first fluid into droplets having volume within a threshold volume.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises a centrifugal pump, an electric motor mechanically coupled by a drive shaft to the centrifugal pump, wherein the electric motor comprises a stator and a rotor, a bearing, wherein the bearing is disposed inside the electric motor, and a magnetic shield disposed in the electric motor between bearing and the rotor and stator.

Abstract: An electric submersible pump (ESP) electric motor. The ESP electric motor comprises a housing; a stator retained within the housing; a drive shaft; and an at least one rotor mechanically coupled to the drive shaft and located concentric with and inside of the stator, wherein an inside surface of the stator defines a groove extending from an upper end to a lower end of the stator, an outside surface of the at least one rotor defines a groove extending from an upper end to a lower end of the at least one rotor, an inside surface of the at least one rotor defines a groove extending from an upper end to a lower end of the at least one rotor, or an outside surface of the drive shaft defines a groove extending from below an male splines at an upper end to a lower end of the drive shaft.

Abstract: A downhole gas separator and pump assembly. The downhole gas separator and pump assembly comprises a drive shaft; a first fluid mover having an inlet and an outlet; a separation chamber located downstream of the first fluid mover and fluidically coupled to the outlet of the first fluid mover; a gas flow path and liquid flow path separator located downstream of the separation chamber, having an inlet fluidically coupled to the separation chamber, having a gas phase discharge port open to an exterior of the assembly, and having a liquid phase discharge port; and a second fluid mover mechanically coupled to the drive shaft, located downstream of the first gas flow path and liquid flow path separator, and having an inlet fluidically coupled to the fluid phase discharge port of the first gas flow path and liquid flow path separator.

Abstract: An electric submersible pump (ESP) assembly that includes an electric motor with a splined drive shaft with drive shaft teeth, an ESP mechanically coupled to the electric motor that includes a splined ESP shaft with ESP shaft teeth, and a downhole component mechanically coupled to the electric motor that includes a splined component shaft with component shaft teeth. Splined couplings each include a central axis and grooves through the coupling with groove sidewalls sized to receive the shaft teeth. The grooves are angled relative to the central axis to form a space on either side of each tooth in each groove for at least a portion of the overlapped length of the tooth within the groove. Each coupling is engageable with the teeth of two of the drive shaft, the pump shaft, or the component shaft to mechanically couple the electric motor, the ESP, and the downhole component.