Abstract: Methods and systems for producing hydrocarbons. An example method includes producing a non-hydrocarbon liquid from a first horizontal wellbore, the first horizontal wellbore extending from a vertical wellbore and through a hydrocarbon producing formation. The method further includes pumping the non-hydrocarbon liquid with a first pump into a second horizontal wellbore, the second horizontal wellbore extending from the vertical wellbore and disposed downhole and underneath the first horizontal wellbore. The method additionally includes pumping a hydrocarbon liquid uphole to a surface with a second pump disposed downhole of the first horizontal wellbore.

Abstract: A system for protecting an Electrical Submersible Pump (ESP) string from gas slugs in a downhole well environment. The system comprises an intake tube having a first and second end and one of a packer having a bypass channel and an inverted shroud coupled to the intake tube and the ESP string. The intake tube is independent of a pump and a motor of the ESP string. The system can comprise a bypass tube for channeling the gas slug downstream of the pump. The bypass tube is integrated with the packer. The inverted shroud is coupled with the first end of the intake tube and a section of production tubing downstream from the pump and the motor. The inverted shroud forms a bypass path channel within a casing annulus.

Abstract: Methods and systems for producing hydrocarbons. An example method includes producing a non-hydrocarbon liquid from a first horizontal wellbore, the first horizontal wellbore extending from a vertical wellbore and through a hydrocarbon producing formation. The method further includes pumping the non-hydrocarbon liquid with a first pump into a second horizontal wellbore, the second horizontal wellbore extending from the vertical wellbore and disposed downhole and underneath the first horizontal wellbore. The method additionally includes pumping a hydrocarbon liquid uphole to a surface with a second pump disposed downhole of the first horizontal wellbore.

Abstract: Apparatus and method for passive gas separation in a through-tubing-conveyed (TTC) pump system comprise abruptly reversing a flow direction of wellbore fluids from flowing up the wellbore to down into a liquids reservoir. The generally annular liquids reservoir is formed between a production tubing and a pump of the TTC pump system. Wellbore fluids flowing up the production tubing are diverted into the annulus via one or more outlet ports in the production tubing. The wellbore fluids flow up the annulus until encountering one or more inlet ports in the production tubing, which redirects the wellbore fluids from the annulus down into the liquids reservoir. The reversal of flow direction causes gas in the wellbore fluids to separate from liquids as the gas continues moving up the wellbore instead of changing direction with the liquids. The substantially gas free liquids are then pumped by the pump up to the surface.

Abstract: Apparatus and method for passive gas separation in a through-tubing-conveyed (TTC) pump system comprise abruptly reversing a flow direction of wellbore fluids from flowing up the wellbore to down into a liquids reservoir. The generally annular liquids reservoir is formed between a production tubing and a pump of the TTC pump system. Wellbore fluids flowing up the production tubing are diverted into the annulus via one or more outlet ports in the production tubing. The wellbore fluids flow up the annulus until encountering one or more inlet ports in the production tubing, which redirects the wellbore fluids from the annulus down into the liquids reservoir. The reversal of flow direction causes gas in the wellbore fluids to separate from liquids as the gas continues moving up the wellbore instead of changing direction with the liquids. The substantially gas free liquids are then pumped by the pump up to the surface.

Abstract: Methods and systems for producing hydrocarbons. An example method includes producing a non-hydrocarbon liquid from a first horizontal wellbore, the first horizontal wellbore extending from a vertical wellbore and through a hydrocarbon producing formation. The method further includes pumping the non-hydrocarbon liquid with a first pump into a second horizontal wellbore, the second horizontal wellbore extending from the vertical wellbore and disposed downhole and underneath the first horizontal wellbore. The method additionally includes pumping a hydrocarbon liquid uphole to a surface with a second pump disposed downhole of the first horizontal wellbore.

Abstract: A system for protecting an Electrical Submersible Pump (ESP) string from gas slugs in a downhole well environment. The system comprises an intake tube having a first and second end and one of a packer having a bypass channel and an inverted shroud coupled to the intake tube and the ESP string. The intake tube is independent of a pump and a motor of the ESP string. The system can comprise a bypass tube for channeling the gas slug downstream of the pump. The bypass tube is integrated with the packer. The inverted shroud is coupled with the first end of the intake tube and a section of production tubing downstream from the pump and the motor. The inverted shroud forms a bypass path channel within a casing annulus.

Abstract: A system for protecting an Electrical Submersible Pump (ESP) string from gas slugs in a downhole well environment. The system comprises an intake tube having a first and second end and one of a packer having a bypass channel and an inverted shroud coupled to the intake tube and the ESP string. The intake tube is independent of a pump and a motor of the ESP string. The system can comprise a bypass tube for channeling the gas slug downstream of the pump. The bypass tube is integrated with the packer. The inverted shroud is coupled with the first end of the intake tube and a section of production tubing downstream from the pump and the motor. The inverted shroud forms a bypass path channel within a casing annulus.

Abstract: A system for protecting an Electrical Submersible Pump (ESP) string from gas slugs in a downhole well environment. The system comprises an intake tube having a first and second end and one of a packer having a bypass channel and an inverted shroud coupled to the intake tube and the ESP string. The intake tube is independent of a pump and a motor of the ESP string. The system can comprise a bypass tube for channeling the gas slug downstream of the pump. The bypass tube is integrated with the packer. The inverted shroud is coupled with the first end of the intake tube and a section of production tubing downstream from the pump and the motor. The inverted shroud forms a bypass path channel within a casing annulus.

Abstract: A fluid moving system and apparatus for an electric submersible pump (ESP) is described. A fluid moving system includes a gas separator between an electric submersible pump and an ESP motor, the gas separator including a separation chamber including an impeller and a diffuser, the impeller including a plurality of regressively pitched main vanes interspersed between a plurality of mixer vanes, each of the plurality of main and mixer vanes extending along the hub with a positive slope and a concave top face, and a diffuser, the diffuser including blades extending along a diffuser body in a sloped direction substantially opposite the slope of the impeller main vanes, the blades having a concave top face and a regressive pitch that mirrors the pitch of the impeller main vanes, wherein the impeller vanes and diffuser blades serve to homogenize the well fluid while facilitating downstream movement.

Abstract: A well pump assembly has a barrel, a standing valve at an upper end of a standing valve chamber, and a plunger. A travelling valve admits well fluid into the barrel during a fill stroke. The travelling valve closes during a power stroke so that the plunger pushes well fluid from the barrel into the standing valve chamber. A gas release port extends from the standing valve chamber to the exterior of the pump assembly. A check valve in the gas release port has an outward flow blocking position for blocking liquid well fluid in the standing valve chamber from exiting through the gas release port while the plunger is in the power stroke. The cheek valve has a gas release position that enables gas present in the standing valve chamber to flow out the gas release port while the plunger is in the power stroke.

Abstract: A fluid moving system and apparatus for an electric submersible pump (ESP) is described. A fluid moving system includes a gas separator between an electric submersible pump and an ESP motor, the gas separator including a separation chamber including an impeller and a diffuser, the impeller including a plurality of regressively pitched main vanes interspersed between a plurality of mixer vanes, each of the plurality of main and mixer vanes extending along the hub with a positive slope and a concave top face, and a diffuser, the diffuser including blades extending along a diffuser body in a sloped direction substantially opposite the slope of the impeller main vanes, the blades having a concave top face and a regressive pitch that mirrors the pitch of the impeller main vanes, wherein the impeller vanes and diffuser blades serve to homogenize the well fluid while facilitating downstream movement.

Abstract: A well pump assembly has a barrel, a standing valve at an upper end of a standing valve chamber, and a plunger. A travelling valve admits well fluid into the barrel during a fill stroke. The travelling valve closes during a power stroke so that the plunger pushes well fluid from the barrel into the standing valve chamber. A gas release port extends from the standing valve chamber to the exterior of the pump assembly. A check valve in the gas release port has an outward flow blocking position for blocking liquid well fluid in the standing valve chamber from exiting through the gas release port while the plunger is in the power stroke. The check valve has a gas release position that enables gas present in the standing valve chamber to flow out the gas release port while the plunger is in the power stroke.

Abstract: An adapter for a motor head of an electric submersible pump enables a motor head having a pothole and cutaway to provide a direct-connect for a motor lead extension cable run downhole to the motor section of the pump. The adapter has a curved conduit independent of the motor head that positions adjacent the side of the motor head in the provided cutaway. The conduit's downhole end affixes (bolts) to the motor head with the end disposing in the pothole of the motor head. The conduit's uphole end affixes (bolts) adjacent the uphole end of the motor head. A termination block disposed in the conduit's uphole has sockets that are electrically connected to motor components via internal leads running through the conduit and the pothole. A mating termination on the end of a motor lead extension cable affixes (bolts) to the conduit's uphole end, and pin on the termination electrically couple to the sockets to convey power to the motor section.

Abstract: An electrical connector assembly for a cable having a plurality of insulated conductors comprises a body having a respective recess for receiving a terminating pin each of the conductors. A respective spigot sealingly engages within each of the recesses and has a passage for receiving an associated one of the terminating pins. Furthermore a seal is associated with each of the spigots for sealing the spigot relative to the associated terminating pin. The provision of a separate spigot for each of the conductors and for sealing engagement within a respective recess in the body enables the spigots to be sealingly fitted to the conductors prior to each spigot being introduced into its recess and sealingly engaged therein. This provides improved insulation of the conductor and increased creepage distance between the mating electrical parts and the outer surface of the housing of the assembly.

Abstract: An electrical connector assembly for a cable having a plurality of insulated conductors comprises a body having a respective recess for receiving a terminating pin each of the conductors. A respective spigot sealingly engages within each of the recesses and has a passage for receiving an associated one of the terminating pins. Furthermore a seal is associated with each of the spigots for sealing the spigot relative to the associated terminating pin. The provision of a separate spigot for each of the conductors and for sealing engagement within a respective recess in the body enables the spigots to be sealingly fitted to the conductors prior to each spigot being introduced into its recess and sealingly engaged therein. This provides improved insulation of the conductor and increased creepage distance between the mating electrical parts and the outer surface of the housing of the assembly.