A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

A flow management and separation system for a horizontal wellbore having a primary artificial lift device having an intake has (a) a sealed central flowpath from a fluidseeker weighted keel inlet, through a recovery flow tube, a seal bore extension and a dip tube having a pump intake sealing assembly in fluid communication with the lift device intake; and (b) a mixed fluid flow path from a fluidseeker internal bypass passage, through an annulus of at least one slug catcher comprising a perforated shell.

A flow management and separation system for a horizontal wellbore having a primary artificial lift device having an intake has (a) a sealed central flowpath from a fluidseeker weighted keel inlet, through a recovery flow tube, a seal bore extension and a dip tube having a pump intake sealing assembly in fluid communication with the lift device intake; and (b) a mixed fluid flow path from a fluidseeker internal bypass passage, through an annulus of at least one slug catcher comprising a perforated shell.

A method of plugging a hydrocarbon well includes deploying a downhole tool to remove at least a portion of a casing at a section of well to be plugged. Deploying a blocking device downhole to block a bottom of the section of well to be plugged. Deploying a plugging material downhole onto the blocking device to fill an area to be plugged. Deploying an exothermic fluid downhole, wherein activation of the exothermic material liquefies the plugging material. Allowing the plugging material and the exothermic fluid to solidify form a cast-in-place plug that fills the section of well to be plugged.

A downhole tool includes a housing configured to be connected between two tubular members. The housing includes a chamber and a plug assembly is disposed in the chamber and divides the chamber into an up-hole portion and a downhole portion. The plug assembly includes a glass member having a predetermined residual surface compression, at least a first face, and at least one strength-reducing surface feature on the first face. The strength-reducing surface feature is configured to cause the glass member to disintegrate when the glass member is exposed to a pressure in the up-hole portion of a magnitude that creates a tensile stress on the first face that exceeds the predetermined residual surface compression.

A downhole tool includes a housing configured to be connected between two tubular members. The housing includes a chamber and a plug assembly is disposed in the chamber and divides the chamber into an up-hole portion and a downhole portion. The plug assembly includes a glass member having a predetermined residual surface compression, at least a first face, and at least one strength-reducing surface feature on the first face. The strength-reducing surface feature is configured to cause the glass member to disintegrate when the glass member is exposed to a pressure in the up-hole portion of a magnitude that creates a tensile stress on the first face that exceeds the predetermined residual surface compression.

The present invention discloses a permanent packer and an extended gas lift method using the permanent packer, the method comprising: S1. imbedding the extended gas lift embedded pipe when setting the permanent packer, wherein the extended gas lift embedded pipe has an upper end being closed and a lower end being open, is provided therein with a one-way valve through which the fluid can pass from top to bottom; S2. lowering a breaking device from the production casing when in the extended gas lift, to break the upper end of the extended gas lift embedded pipe such that the upper and lower ends of the extended gas lift embedded pipe are communicated; and S3. injecting gas into the production casing, lifting the accumulated liquid in the bottom hole to the ground surface, to complete the extended gas lift. The method does not affect the sealing property of the permanent packer, can fully adapt to the demand in the early and middle stages of gas well development, and meanwhile can realize extended gas lift without workover in the middle and later stages of gas well development, and has low implementation cost and good safety.

An electronic trigger system includes a longitudinal housing including detection, electronics, and actuation sections disposed therein. The detection section includes a pressure sensor for receiving a predetermined pressure signal, and an electronic control board including at least one battery is disposed in the electronics section. The actuation section includes a prefill chamber, a setting piston disposed in the prefill chamber, an actuation device, an atmospheric chamber, and a pressure port. A predetermined amount of prefilled fluid at hydrostatic pressure is trapped between the setting piston and the actuation device in the prefill chamber. The actuation device isolates the prefilled fluid at hydrostatic pressure in the prefill chamber from the atmospheric chamber. Actuation occurs when, upon receipt of the predetermined pressure signal by the pressure sensor, the electronic control board transmits power to the actuation device, causing the prefilled fluid to flow through the actuation device and into the atmospheric chamber.

An electronic trigger system includes a longitudinal housing including detection, electronics, and actuation sections disposed therein. The detection section includes a pressure sensor for receiving a predetermined pressure signal, and an electronic control board including at least one battery is disposed in the electronics section. The actuation section includes a prefill chamber, a setting piston disposed in the prefill chamber, an actuation device, an atmospheric chamber, and a pressure port. A predetermined amount of prefilled fluid at hydrostatic pressure is trapped between the setting piston and the actuation device in the prefill chamber. The actuation device isolates the prefilled fluid at hydrostatic pressure in the prefill chamber from the atmospheric chamber. Actuation occurs when, upon receipt of the predetermined pressure signal by the pressure sensor, the electronic control board transmits power to the actuation device, causing the prefilled fluid to flow through the actuation device and into the atmospheric chamber.