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.

Aspects of the disclosure relate to convertible float valve assemblies, and associated components thereof, and methods of using convertible float valve assemblies. A convertible float valve assembly may comprise a sleeve, one or more valves and valve bodies coupled to the sleeve, and a collet coupled to the sleeve. A method may comprise lowering the convertible float valve assembly and a ball downhole, seating the ball on the collet, and releasing the sleeve from the one or more valve bodies.

A system and method of reverse stage cementing in which flow into a casing string from an annulus between the casing string and wellbore walls is pressure dependent; the flow is blocked after stage completion. The flow enters the casing string through a cementing sub integrally formed in the casing string. A flapper valve is in a sidewall of the cementing sub that opens when pressure in the annulus reaches a threshold value, and remains open until the annulus pressure falls below the threshold value. Flapper valve actuation is controlled by a hinge spring that is calibrated to open and close the flapper valve based on the annulus pressure. Also in the cementing sub is a sleeve that is positioned behind the flapper valve after the reverse stage cementing is completed. Sleeve actuation is timed to allow adequate time for the flapper valve to return to the closed position.

A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates.

Apparatus and methods pertaining to an adapter mechanically connecting a wireless actuator to an SCSSV subassembly that includes an SCSSV. The adapter mechanically connects to the SCSSV subassembly so that the adapter is situated uphole of the SCSSV subassembly when set in a tubular of a wellbore. An actuating piston is carried by the adapter. The actuating piston transfers an opening force to the SCSSV in response to receipt by the adapter of pressurized fluid from the wireless actuator, thereby opening a flapper of the SCSSV.

An apparatus, system, and method of use that enables control of fluid flow in a wellbore drill string with a pilot. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball. An accumulator can control the operations of the valve by selectively exerting pressure and/or fluid flow on the pusher rod.

A valve assembly (1) has a valve (14), for example a flapper valve, that is contained within an axially movable valve housing (11) in the form of a cartridge (10) that is received within the bore of a tubular member (5). More than one cartridge (10) may be connected in series. The valve (14) and cartridge (10) are pivotally connected (13) and axial movement of the cartridge (10) pivots the valve (14) around this connection (13) to open or close the valve (14). The valve assembly (1) can be actuated by an actuator assembly (50) having an actuator (61) for actuating the valve (14), and a resettable shuttle device (80) that retains the actuator (61) in different configurations within the actuator assembly (50). The actuator (61) can be moved relative to the valve (14), engaging the shuttle device (80) and changing the configuration of the shuttle device (80).

A valve element selectively opens and closes a radial aperture and an axial hole in a drilling element for drilling mud circulation. The valve element includes a fixing portion allowing the valve element to sealingly fix to the drilling element at the radial aperture. A body has an inlet aperture and an outlet aperture, and a duct for putting the apertures in communication with each other, defining a path for the drilling mud. A plug selectively seals the inlet aperture. A first sealing element is positioned in a housing formed in the axial hole of the drilling element. A shutter pivoted to the body includes a second sealing element to selectively and sealingly close the outlet aperture. The shutter selectively and sealingly closes the axial hole by abutting against the first sealing element. The valve element is adapted to keep the outlet aperture of the body normally closed.

A downhole valve assembly includes a safety valve and an actuator that opens and/or closes the valve. The actuator can be an electro-hydraulic actuator (EHA), an electro mechanical actuator (EMA), or an electro hydraulic pump (EHP). The downhole safety valve can also include an electric magnet.

A portion of a wellbore is put into communication or is isolated by selectively applying an axial or rotational force downhole. The axial force moves a shifting sleeve and deployment sleeve from an initial position to an opening position causing a valve element to move into an open configuration and allowing communication to the portion of the wellbore. The shifting sleeve is returned to the initial position and separated from the deployment sleeve, which is anchored to a retraction sleeve adjacent the valve element. Threads on the shifting and retraction sleeves become engaged when the deployment sleeve is moved to the opening position. The retraction sleeve is rotated by rotating the shifting sleeve, threaded engagement with the rotating retraction sleeve draws the deployment sleeve away from the valve element, and allows the valve element to move to a closed configuration.