A method of producing fluid from a wellbore includes operating a pump located proximate to a zone of fluid influx in the wellbore to draw a reservoir fluid from a reservoir into the wellbore at the zone of fluid influx. The pump is coupled to a tubing string extending above the pump, and a packer is coupled to the tubing string proximate to an upper end of the zone of fluid influx and seals an annular space around the tubing string. The method includes operating the pump to produce the reservoir fluid from the wellbore through the tubing string. A pump includes a drive chamber with a drive piston, a production chamber with a production piston coupled to the drive piston, and axially separated traveling valves.

A member that is a single element for controlling flow through an inflow control device, has anisotropic density configured to move the member relative to the inflow control device such that the inflow control device allows, fully blocks, or partially blocks flow from a zone to a production string based on a density of a fluid flowing into the inflow control device from the zone.

The present invention discloses a method for controlling a toe-end sliding sleeve in a horizontal well based on efficient decoding communication. The method comprises the following steps: forming a pressure wave signal by adjusting and controlling a pressure value in a wellbore according to a first preset encoding manner; acquiring a pressure value change signal in the wellbore, determining a reference time by using an STA/LTA method, and predicting pressure value to acquire a predicted pressure value signal curve; identifying a toe-end sliding sleeve control command in the acquired pressure wave signal by using a first preset decoding manner based on the fitness between the acquired pressure value signal curve and the predicted pressure value signal curve; and driving the toe-end sliding sleeve to perform actions according to the toe-end sliding sleeve control command. The method disclosed by the present invention is simple to operate, low in communication error rate, and aimed to solve the technical problems of complicated system of wellbore pressure test and sliding sleeve joint operation, high operation complexity, high bit error rate of pressure pulse communication, and long code element transmission time in the existing solutions in the prior art.

The present invention discloses a method for controlling a toe-end sliding sleeve in a horizontal well based on efficient decoding communication. The method comprises the following steps: forming a pressure wave signal by adjusting and controlling a pressure value in a wellbore according to a first preset encoding manner; acquiring a pressure value change signal in the wellbore, determining a reference time by using an STA/LTA method, and predicting pressure value to acquire a predicted pressure value signal curve; identifying a toe-end sliding sleeve control command in the acquired pressure wave signal by using a first preset decoding manner based on the fitness between the acquired pressure value signal curve and the predicted pressure value signal curve; and driving the toe-end sliding sleeve to perform actions according to the toe-end sliding sleeve control command. The method disclosed by the present invention is simple to operate, low in communication error rate, and aimed to solve the technical problems of complicated system of wellbore pressure test and sliding sleeve joint operation, high operation complexity, high bit error rate of pressure pulse communication, and long code element transmission time in the existing solutions in the prior art.

A body defines a central flow passage. A check valve is located within the central flow passage. The check valve is supported by the body. The check valve is arranged such that a fluid flow travels in a downhole direction during operation of the float collar. An auxiliary flow passage is substantially parallel to the central flow passage and is defined by the body. The auxiliary flow passage includes an inlet upstream of the check valve and an outlet at a downhole end of the float collar. A rupture disk seals the inlet of the auxiliary flow passage. The rupture disk is configured to burst at a specified pressure differential.

A bypass plunger combines a unitary or one-piece hollow body-and-valve cage, retains a dart valve within the valve cage portion of the hollow body using a threaded retaining nut secured by crimple detents. A series of helical grooves surround the central portion of the outer surface of the hollow body of the plunger to control spin during descent. A canted-coil-spring disposed within the retaining nut functions as a clutch. The valve cage includes ports that may be configured to control flow through the plunger during ascent. Other embodiments include clutch assemblies using canted-coil springs with split bobbins, and valve stems surfaced to achieve specific functions. Combinations of these features provide enhanced performance, durability and reliability at reduced manufacturing cost, due primarily to the simplicity of its design.

A bypass plunger combines a unitary or one-piece hollow body-and-valve cage, retains a dart valve within the valve cage portion of the hollow body using a threaded retaining nut secured by crimple detents. A series of helical grooves surround the central portion of the outer surface of the hollow body of the plunger to control spin during descent. A canted-coil-spring disposed within the retaining nut functions as a clutch. The valve cage includes ports that may be configured to control flow through the plunger during ascent. Other embodiments include clutch assemblies using canted-coil springs with split bobbins, and valve stems surfaced to achieve specific functions. Combinations of these features provide enhanced performance, durability and reliability at reduced manufacturing cost, due primarily to the simplicity of its design.

Devices that can be used to recover hydrocarbon production from closed-in oil wells capable of building up wellhead pressure and/or to sustain marginal oil production in oil wells are disclosed. Production in oil and natural gas producing wells in mature fields that have the ability to build up wellhead pressure and where the depletion of reservoir pressure has caused low or zero productivity may be automated. The devices include at least two bellows that facilitate their operation. The bellows may close the well to build up pressure in the wellhead and open the well to flow line pressure.

Devices that can be used to recover hydrocarbon production from closed-in oil wells capable of building up wellhead pressure and/or to sustain marginal oil production in oil wells are disclosed. Production in oil and natural gas producing wells in mature fields that have the ability to build up wellhead pressure and where the depletion of reservoir pressure has caused low or zero productivity may be automated. The devices include at least two bellows that facilitate their operation. The bellows may close the well to build up pressure in the wellhead and open the well to flow line pressure.

A method includes monitoring fluid production at a passive ICD installed in a base pipe in a wellbore. Responsive to monitored fluid production meeting one or more predetermined criteria, a remedial sleeve component is installed for the passive ICD. The remedial sleeve component includes: one or more ports which permit throughput of fluid into the base pipe; a closing portion which selectively opens and closes the one or more ports; and one or more sealing portions, which prevent a flow of fluid into the base pipe when the one or more ports are closed. The one or more ports are selectively opened or closed responsive to one or more additional predetermined criteria. A related system includes an actuation tool which deploys into the wellbore to actuate the closing portion to selectively open and close the one or more ports.