Abstract: Systems and methods for providing artificial lift to wellbore fluids include a pump located within a wellbore. A motor is located uphole of the pump and a protector assembly is located between the pump and the motor. A downhole packer is located within the wellbore downhole of the pump. A sand diverter is located downhole of the pump and has a flow port assembly located uphole of the downhole packer, the sand diverter having a diverter inner bore in fluid communication with the wellbore downhole of the downhole packer. The flow port assembly has an inner sleeve that is moveable between an open position where an inner sleeve port assembly is aligned with an outer sleeve port assembly of an outer sleeve, and a closed position where the inner sleeve port assembly is unaligned with the outer sleeve port assembly.

Abstract: A fluid management system positioned in a wellbore for recovering a multiphase stream from the wellbore. The system comprising a downhole separator configured to produce a carrier fluid having a carrier fluid pressure and a separated fluid having a separated fluid pressure, an artificial lift device configured to increase the carrier fluid pressure to produce the turbine feed stream having a turbine feed pressure, a turbine configured to convert fluid energy in the turbine feed stream to harvested energy, the conversion fluid energy from the turbine feed stream to harvested energy produces a turbine discharge stream having a turbine discharge pressure less than the turbine feed pressure, and a pressure boosting device configured to convert the harvested energy to pressurized fluid energy, the conversion of harvested energy to pressurized fluid energy produces a pressurized fluid stream having a pressurized fluid pressure greater than the separated fluid pressure.

Abstract: An electrical submersible pump (ESP) and method for pumping fluid from a wellbore. The ESP has a motorized pump with an external rotor motor topology. The motorized pump fits into casing in the wellbore. The motorized pump includes a motor having a motor stator and a motor rotor. The motor stator is at a radial center of the motorized pump. The motorized pump has a centrifugal pump radially surrounding the motor stator. The centrifugal pump includes an impeller and a diffuser.

Abstract: Systems and methods for producing hydrocarbons from a subterranean well include a first electrical submersible pump section having an outer motor body, and a motor stator. A central bore extends through the motor body and is sized to accommodate a motor rotor assembly. A second electrical submersible pump section has the motor rotor assembly, a seal section, and a pump section. The first electrical submersible pump section has a downhole ring shaped to secure the first electrical submersible pump section to a downhole production tubing, and has an uphole ring shaped to secure the first electrical submersible pump section to an uphole production tubing. The second electrical submersible pump section has a deployment connector operable to connect to an installation line for rig-less installation and removal of the second electrical submersible pump section.

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 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.

Abstract: A hanger system for a well includes a pipe spool and a tubing hanger removably coupled to the pipe spool. The pipe spool includes a spool housing defining a cylindrical spool bore extending longitudinally through the spool housing, an electrical port in the spool housing with an electrical port opening in an inner surface of the spool housing, a communication port in the spool housing with a communication port opening in the inner surface of the spool housing, and a control port in the spool housing having a control port opening in the inner surface of the spool housing. The communication port connects to a communication module, the control port connects to a control fluid supply, and the electrical port connects to a power supply. The tubing hanger includes a hanger housing, and an electrical conduit, communication conduit, and control conduit extending through the hanger housing.

Abstract: A downhole production assembly includes a downhole pump that can be positioned at a downhole location in a wellbore, and a cavitation chamber located upstream of an inlet of the downhole pump in the wellbore. The cavitation chamber can induce cavitation in a wellbore fluid pumped in the uphole direction by the downhole pump to prevent scaling on the downhole pump.

Abstract: A first platform is mounted to a central riser that is configured to flow a fluid into or out of a wellbore. The central riser is fluidically and structurally attached to a wellhead. The first platform is positioned relative to the central riser to allow access to substantially all external portions of the central riser from the first platform. A second platform is positioned above and supported by the first platform. The first platform is positioned between the second platform and the wellhead. The second platform is movable relative to the first platform.

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: Examples of fiber reinforced and powered coil tubing include a hollow fiber reinforced composite coiled tubing with a tubing wall having an inner surface, an outer surface and a wall thickness. The inner surface is formed to prevent absorption of fluids flowed through the coiled tubing to the tubing wall. The tubing can connect a power source at a surface of a wellbore to downhole equipment positioned within the wellbore. An electrical power conductor is embedded in the tubing wall. The conductor can transfer power from the power source to the downhole equipment. The tubing can be used to lower, install and remove downhole equipment into the wellbore without a work-over rig. The downhole equipment can be operated by transmitted power through the electrical power conductor.

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.

Abstract: Systems and methods for removing fluid from a subterranean well with a fluid removal system includes lowering an elongated member into tubing of the subterranean well to a lower position, the elongated tubing having a plunger or valve body located at an end, wherein fluid passes past the plunger or through a valve opening as the valve body moves into the subterranean well. The plunger or valve body is moved in a direction out of the subterranean well so that fluid cannot pass the plunger or through the valve opening, moving the fluid out of the subterranean well.

Abstract: An electrical submersible pump (ESP) and method for pumping fluid from a wellbore. The ESP has a motorized pump with an external rotor motor topology. The motorized pump fits into casing in the wellbore. The motorized pump includes a motor having a motor stator and a motor rotor. The motor stator is at a radial center of the motorized pump. The motorized pump has a centrifugal pump radially surrounding the motor stator. The centrifugal pump includes an impeller and a diffuser.

Abstract: An integrated system is disclosed to handle production of multiphase fluid consisting of oil, gas and water. The production stream is first separated into two streams: a liquid dominated stream (GVF<5% for example) and a gas dominated stream (GVF>95% for example). The separation can be done through shrouds, cylindrical cyclonic, gravity, in-line or the like separation techniques. The two streams are then routed separately to pumps which pump dissimilar fluids, such as a liquid pump and a gas compressor, and subsequently recombined. Both pumps are driven by a single motor shaft which includes an internal passageway associated with one of the pumps for reception of the fluid from the other pump, thereby providing better cooling and greater overall efficiency of all systems associated therewith. A method for providing artificial lift or pressure boosting of multiphase fluid is also disclosed.

Abstract: A system and method for boosting the pressure of a low-pressure multiphase mixture into a high-pressure multiphase mixture. The system includes a gas-liquid separator, a liquids pump and a liquid piston compressor. The method includes introducing the low-pressure multiphase mixture into the pressure boost system, operating such that a low-pressure liquid and a low-pressure gas form, boosting the pressure of the low-pressure liquid to a high-pressure liquid, introducing low-pressure gas during a charging period into the liquid piston compressor, converting the low-pressure gas into high-pressure gas using the high-pressure liquid during a compression period, discharging the high-pressure gas form the liquid piston compressor, and mixing the high-pressure liquid and gas such that the high-pressure multiphase mixture.

Abstract: A well tool assembly, system, and method for handling well debris is described. The assembly includes an electric submersible pump (ESP) configured to be positioned within a wellbore and a well debris cutting tool configured to be positioned downhole relative to the ESP within the wellbore. The ESP is configured to rotate in a first direction to pump well fluid in an uphole direction. The well debris cutting tool is configured to rotate in a second direction opposite the first direction and to grind debris carried by the well fluid in the uphole direction.

Abstract: A system and method for boosting the pressure of a low-pressure multiphase mixture into a high-pressure multiphase mixture. The system includes a gas-liquid separator, a liquids pump and a liquid piston compressor. The method includes introducing the low-pressure multiphase mixture into the pressure boost system, operating such that a low-pressure liquid and a low-pressure gas form, boosting the pressure of the low-pressure liquid to a high-pressure liquid, introducing low-pressure gas during a charging period into the liquid piston compressor, converting the low-pressure gas into high-pressure gas using the high-pressure liquid during a compression period, discharging the high-pressure gas form the liquid piston compressor, and mixing the high-pressure liquid and gas such that the high-pressure multiphase mixture.

Abstract: A hanger system for a well includes a pipe spool and a tubing hanger removably coupled to the pipe spool. The pipe spool includes a spool housing defining a cylindrical spool bore extending longitudinally through the spool housing, an electrical port in the spool housing with an electrical port opening in an inner surface of the spool housing, a communication port in the spool housing with a communication port opening in the inner surface of the spool housing, and a control port in the spool housing having a control port opening in the inner surface of the spool housing. The communication port connects to a communication module, the control port connects to a control fluid supply, and the electrical port connects to a power supply. The tubing hanger includes a hanger housing, and an electrical conduit, communication conduit, and control conduit extending through the hanger housing.

Abstract: An integrated system is disclosed to handle production of multiphase fluid consisting of oil, gas and water. The production stream is first separated into two streams: a liquid dominated stream (GVF <5% for example) and a gas dominated stream (GVF >95% for example). The separation can be done through shrouds, cylindrical cyclonic, gravity, in-line or the like separation techniques. The two streams are then routed separately to pumps which pump dissimilar fluids, such as a liquid pump and a gas compressor, and subsequently recombined. Both pumps are driven by a single motor shaft which includes an internal passageway associated with one of the pumps for reception of the fluid from the other pump, thereby providing better cooling and greater overall efficiency of all systems associated therewith. A method for providing artificial lift or pressure boosting of multiphase fluid is also disclosed.