A method includes deploying a tubing having a tubing bore in a casing in a wellbore, the tubing including a cup packer forming an annular barrier across a tubing-casing annulus separating the tubing-casing annulus into an upper annulus and a lower annulus, the cup packer having a fluid conduit extending substantially parallel to the tubing bore, and a barrier valve coupled with the fluid conduit to permit one-way fluid flow from the upper annulus to the lower annulus, communicating a fluid from the upper annulus through the barrier valve to the lower annulus, and closing the barrier valve in response to pressure in the upper annulus being less than pressure in the lower annulus.

Disclosed herein are various embodiments of methods and systems for drilling a wellbore into an oil or gas production zone to prevent formation damage in the reservoir using underbalanced or near-balanced drilling techniques, wherein a jet pump drilling assembly is used to create a vacuum around the drill bit. The design of this jet pump drilling assembly prevents the flow of all drilling/power fluid from entering a drill bit Only fluids from the reservoir are allowed to enter the drill bit. The assembly includes a barrier to ensure that no drilling/power fluid discharged from the jet pump located above the drill bit can flow back around to the jet pump jet pump suction ports located in the drill bit thus preventing any drilling/power fluid from ever contacting the drill bit.

A system for cementing a tubular within a wellbore includes a connector; a tubular housing attached to the connector and disposed in the tubular; and a plug disposed in the tubular housing and releasably attached to the tubular housing.

A system for cementing a tubular within a wellbore includes a connector; a tubular housing attached to the connector and disposed in the tubular; and a plug disposed in the tubular housing and releasably attached to the tubular housing.

Provided is method for gravel packing dual zones within a wellbore and integrating a zonal isolation system. The method, in one embodiment, includes creating an outer sub-assembly and an inner sub-assembly, wherein the inner sub-assembly is positioned within the outer sub-assembly. The method further includes running the outer sub-assembly proximate a bottom of a downhole portion of a wellbore, and setting an uphole packer in an uphole portion of the wellbore and a downhole packer in the downhole portion of the wellbore. The method further includes gravel packing an upper zone and a lower zone, pulling the gravel pack service tool assembly out of the wellbore thereby isolating the upper zone and the lower zone from each other and the wellbore, and running an upper completion into the wellbore to open one or both of the upper zone or the lower zone for production.

Provided is method for gravel packing dual zones within a wellbore and integrating a zonal isolation system. The method, in one embodiment, includes creating an outer sub-assembly and an inner sub-assembly, wherein the inner sub-assembly is positioned within the outer sub-assembly. The method further includes running the outer sub-assembly proximate a bottom of a downhole portion of a wellbore, and setting an uphole packer in an uphole portion of the wellbore and a downhole packer in the downhole portion of the wellbore. The method further includes gravel packing an upper zone and a lower zone, pulling the gravel pack service tool assembly out of the wellbore thereby isolating the upper zone and the lower zone from each other and the wellbore, and running an upper completion into the wellbore to open one or both of the upper zone or the lower zone for production.

A method of plugging a formation fracture includes drilling, with a drill string configured to flow drilling fluid, a wellbore, where, at a downhole location, the drilling fluid is lost through a formation fracture. The method also includes deploying, through the drill string, a plugging assembly to the downhole location of the wellbore. The plugging assembly includes a flexible fiber sheet releasably coupled to a pumpable dart such that when the plugging assembly reaches the downhole location, the flexible fiber sheet is released from the dart to flow, with the drilling fluid, to the formation fracture to at least partially overlay the formation fracture. The method also includes adding, to the drilling fluid, lost circulation material configured to accumulate on a portion of the flexible fiber sheet to at least partially fluidically plug the formation fracture.

A method of plugging a formation fracture includes drilling, with a drill string configured to flow drilling fluid, a wellbore, where, at a downhole location, the drilling fluid is lost through a formation fracture. The method also includes deploying, through the drill string, a plugging assembly to the downhole location of the wellbore. The plugging assembly includes a flexible fiber sheet releasably coupled to a pumpable dart such that when the plugging assembly reaches the downhole location, the flexible fiber sheet is released from the dart to flow, with the drilling fluid, to the formation fracture to at least partially overlay the formation fracture. The method also includes adding, to the drilling fluid, lost circulation material configured to accumulate on a portion of the flexible fiber sheet to at least partially fluidically plug the formation fracture.

An isolation device for use with a casing gas separator. The device incorporates multiple cups, some upward-facing and others downward-facing. The downward-facing cup or cups seal against an internal surface of the casing gas separator to divert flow into the annulus of the separator and enable the separation process. The upward-facing cup or cups hold a pressurized fluid when the device is being located within the casing. Upon reaching the upper ports of the casing gas separator, the fluid releases into the annulus, allowing an operator to determine the location of the device and accurately place it within the casing gas separator.

A pressure control device for use in an oil well is described. The pressure control device comprises a support member configured to be located on a mandrel or a tubular, the support member defining at least one conduit throughbore configured to receive a conduit and a flexible cup member mounted to the support member. In use, a conduit can pass through the pressure control device intact.