In one embodiment, an annular isolation device for a riser includes a tubular body connectable to the riser. A closure member is rotatable between a closed position isolating fluid communication in the tubular body and an open position permitting fluid communication through the tubular body. The annular isolation device further includes an actuator disposed outside the tubular body and operable to rotate the closure member between the open position and the closed position.

Disclosed herein is a reservoir isolation valve for secondary completion, which includes a shell assembly, a sleeve assembly arranged in the shell assembly, a reset spring arranged between the shell assembly and the sleeve assembly, a movable tube, an inner limit tube, an outer limit tube, an outer bearing socket, an inner bearing socket, a thrust bearing, a ball valve arranged in the sleeve assembly, a stepped shaft fixed on the ball valve, a transmission mechanism configured for connecting the movable tube to the stepped shaft and allowing the stepped shaft to rotate and a startup part.

An arrangement for extracting hydrocarbons in oil wells, of the type having a wellhead and an extraction assembly comprised of a fluid collecting container, a suction tube extending inside the fluid collecting container and an extraction rod provided with a plunger that moves inside the extraction tube and which allow to carry out the extraction of hydrocarbons without the need of having equipment or suction pumps/pressurization.

A downhole valve includes a housing, and a sleeve positioned within the housing. The sleeve has a first axial end, a second axial end, and a seat positioned between the first and second ends. The sleeve defines an opening facing in a radial direction. The sleeve prevents fluid flow in an opposite radial direction, away from the opening. The valve also includes a retaining element coupled to or integral with the sleeve, and a first obstructing member positioned in the sleeve and movable between the seat and the retaining element. In a first position, the first obstructing member engages the seat and prevents fluid flow through the housing. In a second position, the first obstructing member is separated apart from the seat such that at least a portion of the opening is axially between the first obstructing member and the first obstructing member.

Disclosed is a work for oilwell plunger pumping under a packer system used to increase the wear life of API ball and seat valves and of ball and seat valves seat utilizing a piston actuator mechanism to unseat the ball from the seat, which during operation, create turbulent flow within the housing to increase force to move piston actuator like rifle bullet or weighted blow dart in dynamic high velocity high impact in stages to overcome hydraulic head and surface tension between ball and seat. Also disclosed umbrella shaped disks on the piston actuator for increased force to be used in both insert and tubing type down hole plunger oil well pumps. The labyrinth of fluid passages that are rectangular channels not holes help keep ball off its seat for complete down stroke and keep solids in suspension to prevent plugging of API ball in API valve cage. Part of the art is based on “Hydraulic Jump” theory by Leonardo Di Vinci in 1500's where thin film at the surface, greatly increases force due to physical changes to fluid at high speeds hitting objects.

Proppant flow back restriction systems, methods to reduce proppant flow back, and methods to deploy a screen over a port are disclosed. A proppant flow back restriction system includes a tubular extending through a wellbore and having a port disposed along the tubular. The system also includes a screen positioned along the tubular. The system further includes a cover disposed in an interior region of the tubular, where the cover is shiftable from a first position to a second position, and from the second position to a third position. The cover covers the port while the cover is in the first position, and uncovers the port while the cover is in the second position. The cover also engages the screen while shifting from the second position to the third position to shift the screen over the port.

A hybrid hydraulic gas pump system includes a hydraulic gas pump installed on the lower end of a production tubular where the production tubular incorporates a gas lift system. The hydraulic gas pump may be operated using the same gas in the annular region as the gas lift system or may be operated using an independent supply line where the independent supply line is concentric with, or at least within, the production tubular. In some instances, the gas pump chamber may simply be an upper packer including a pickup tube, a check valve, and a pressurized gas supply line or other pressurized gas access mechanism along with a lower packer including a check valve. Each upper and lower check valve allows fluid to flow from below the packer to above the packer.

A circulation tool includes a tubular outer body having a main bore and at least one flow port in a wall thereof, and a valve seat assembly including a valve body, a valve member, and locking elements are movably mounted within the outer body main bore. The valve seat assembly is biased towards a first position in which flow through the outer body flow port is prevented and the locking element is in the extended position, restricting passage of the valve member along the valve body bore and out of the valve body. The valve seat assembly is movable to a second position in which the locking element is in the retracted position, permitting passage of the valve member along the body bore and out of the body. The valve seat is also movable to a third position in which flow through the outer body flow port is permitted.

A tool circulates drilling fluid through and rotates a pipe string while making up or breaking out a stand of pipe. The tool includes a clad configured to grip and seal around the RCCT sub. The clad includes a body portion, an inner ring configured to selectively rotate independently, an outer ring configured to be stationary with respect to the inner ring, the outer ring having at least two annular protrusions, a first arm configured to engage with a first annular protrusion, a second arm configured to engage with a second annular protrusion, and a stinger configured to latch into the at least one side entry port and allow the sub and the drill pipe string to rotate independent of the clad. The clad is configured to avoid or prevent stuck pipe incidents.

A setting tool for actuating a well tool within a wellbore includes a sleeve telescopically engaging a mandreland a floating piston disposed between the sleeve and the mandrel. The floating piston has a first face subjected to a downhole hydrostatic pressure. The setting tool also includes a pressure chamber formed between the floating piston and the valve, a working fluid in the pressure chamber, and a fluid-tight collapse chamber formed between the valve and a sealed end of the sleeve. The valve selectively the working fluid from the pressure chamber into the collapse chamber if the working fluid reaches a predetermined primary pressure setting of the valve. The setting tool is connected to and actuated a consumer.