Provided is a downhole zonal isolation assembly. The downhole zonal isolation assembly, in accordance with one aspect, includes a rotating fracturing valve positionable within wellbore casing proximate a fracturing zone of interest. The downhole zonal isolation assembly, according to this aspect, further includes a rotating fracturing valve actuator coupled to the rotating fracturing valve, and rotating fracturing valve electronics coupled to the rotating fracturing valve actuator, the rotating fracturing valve electronics operable to activate the rotating fracturing valve actuator to move the rotating fracturing valve from a first wellbore casing open position to a second wellbore casing closed position.

Provided is a downhole zonal isolation assembly. The downhole zonal isolation assembly, in accordance with one aspect, includes a rotating fracturing valve positionable within wellbore casing proximate a fracturing zone of interest. The downhole zonal isolation assembly, according to this aspect, further includes a rotating fracturing valve actuator coupled to the rotating fracturing valve, and rotating fracturing valve electronics coupled to the rotating fracturing valve actuator, the rotating fracturing valve electronics operable to activate the rotating fracturing valve actuator to move the rotating fracturing valve from a first wellbore casing open position to a second wellbore casing closed position.

A downhole temporary pressure isolation tool configured to withstand very high gas pressures at high temperatures may be achieved by a variety of configurations, processes, and techniques. In particular implementations, a barrier valve having one or more frangible discs configured to resist fluid flow in a particular specified duration. In some implementations, the barrier valve may achieve a V0 rating. In one embodiment, for example, a barrier valve may prevent the passage of fluid (i.e., gas and/or liquid) at 15,000 psi and a temperature of 400 degrees F. for at least 15 minutes. If the barrier valve has two frangible ceramic discs, it may prevent the passage of fluid from two directions for at least 15 minutes.

A downhole temporary pressure isolation tool configured to withstand very high gas pressures at high temperatures may be achieved by a variety of configurations, processes, and techniques. In particular implementations, a barrier valve having one or more frangible discs configured to resist fluid flow in a particular specified duration. In some implementations, the barrier valve may achieve a V0 rating. In one embodiment, for example, a barrier valve may prevent the passage of fluid (i.e., gas and/or liquid) at 15,000 psi and a temperature of 400 degrees F. for at least 15 minutes. If the barrier valve has two frangible ceramic discs, it may prevent the passage of fluid from two directions for at least 15 minutes.

A self-destructible frac ball is described herein. The self-destructible frac ball is configured to seal a hydraulic flow path through a fluid conduit of a frac plug when engaged on a ball seat of the frac plug. The self-destructible frac ball includes an activation mechanism configured to activate a destructive medium in response to the satisfaction of at least one predetermined condition. The self-destructible frac ball also includes the destructive medium, which is configured to destroy the self-destructible frac ball and a corresponding destructible ball retainer when activated by the activation mechanism. The destruction of the self-destructible frac ball and the corresponding destructible ball retainer reestablishes the hydraulic flow path through the fluid conduit of the frac plug.

A self-destructible frac ball is described herein. The self-destructible frac ball is configured to seal a hydraulic flow path through a fluid conduit of a frac plug when engaged on a ball seat of the frac plug. The self-destructible frac ball includes an activation mechanism configured to activate a destructive medium in response to the satisfaction of at least one predetermined condition. The self-destructible frac ball also includes the destructive medium, which is configured to destroy the self-destructible frac ball and a corresponding destructible ball retainer when activated by the activation mechanism. The destruction of the self-destructible frac ball and the corresponding destructible ball retainer reestablishes the hydraulic flow path through the fluid conduit of the frac plug.

A method of using a downhole tool that includes the step of operating a workstring to run the downhole tool into a wellbore to a desired position. The downhole tool includes a mandrel having a proximate end with a first outer diameter; a distal end with a second outer diameter; a flowbore; and an inner set of shear threads disposed in the flowbore at the proximate end.

A method of using a downhole tool that includes the step of operating a workstring to run the downhole tool into a wellbore to a desired position. The downhole tool includes a mandrel having a proximate end with a first outer diameter; a distal end with a second outer diameter; a flowbore; and an inner set of shear threads disposed in the flowbore at the proximate end.

A settable down hole tool is of increased drillability and/or of increased expansibility. The improvement in drillability can be caused by fracturing cast iron slips into a large number of small pieces that can be circulated out of a well without further reduction in size. The improvement in expansibility can be partially caused by providing an expander cone of increased hardness thereby allowing an increased angle on the expander cone and slips. The improvement in expansibility can be partially caused by increasing the thickness of the slips.

Provided is a method for deploying a multi-zone completion assembly, as well as a downhole tool and a well system. In one aspect, the method for deploying the multi-zone completion assembly includes coupling a casing scraper assembly to an inner service tool string hanging from a beginning section of a packer assembly suspended from a rig floor, the inner service tool string located within and extending below the beginning section of the packer assembly, and the casing scraper assembly located entirely below the beginning section of the packer assembly string. In one or more other aspects, the method includes completing the packer assembly string from the rig floor as the inner service tool string and casing scraper assembly are hanging therefrom.