Abstract: A system and method comprising at least one ported sleeve assembly and a flapper assembly positioned downwell of the ported sleeve assembly. The system provides for the use of multiple ported sleeve assemblies for each stage of a hydrocarbon producing well that can be opened with a single element, and multiple stages, each have thFracturinge ability to be opened with a single element size.

Abstract: A downhole tool comprising a nested sleeve moveable from a closed position to an open position following actuation of a fluid control device. The fluid control device may selectively permit fluid flow, and thus pressure communication, into the annular space to cause a differential pressure across the shifting sleeve, and thereby moving the shifting sleeve to an open position. A static plug seat is positioned in the tubing or casing upwell of the downhole tool. When the shifting sleeve is opened, fluid flow is established through the static plug seat, allowing a dissolvable or disintegrable ball or other plug to engage the plug seat, preventing fluid flow past the plug seat to the opened downhole tool, thereby permitting pressurization of the tubing or casing, such as for a pressure test. Disintegration of the ball allows fluid communication to be re-established with the downhole tool, permitting fluid to flow through the tubing for subsequent operations.

Abstract: A downhole system and related method, the system comprising an annulus sealing device having a flow path therethrough, a first side, a second side, and a sealing element; a latch element positioned at the first side of the annulus sealing device; at least one check valve assembly positioned at the second side of the annulus sealing device, the at least one check valve assembly having an annular seat, a seat-engaging element rotatably movable relative to the annular seat, and a biasing member urging the seat-engaging element toward the annular seat element; a rigid elongate member extending at least partially through the latch element and having a first end, a second end, and an outer surface extending between the first end and the second end; and a fluid communication path between the annular seat and through the latch element at least partially defined by the rigid elongate member.

Abstract: A downhole tool comprising an inner sleeve with a plurality of sleeve ports and a housing positioned radially outwardly of the inner sleeve and having a plurality of housing ports, with the housing and inner sleeve partially defining a space radially therebetween. The space is occupied by a shifting sleeve. A fluid path extends between the interior flowpath of the tool and the space. A fluid control device, such as a burst disk, occupies at least portion of the fluid path. In one state, the shifting sleeve is in a first position between the housing ports and the sleeve ports to prevent fluid flow between the interior flowpath and exterior of the tool. The fluid control device may selectively permit fluid flow, and thus pressure communication, into the annular space to cause a differential pressure across the shifting sleeve.

Abstract: A downhole tool incorporating a sleeve assembly with an actuatable element, such as the seat of a plug-and-seat combination, and a seal assembly, such as a flapper seal assembly. The sleeve assembly is movable between a first position, in which the seal assembly is opened and inhibited from closing by contact with the sleeve assembly, and a second position in which the seal assembly is closed. Upon closing of the flapper assembly, the downhole tool may withstand higher pressures with reduced risk of failure to maintain a pressure differential across the tool.

Abstract: A downhole tool comprising an inner sleeve with a plurality of sleeve ports and a housing positioned radially outwardly of the inner sleeve and having a plurality of housing ports, with the housing and inner sleeve partially defining a space radially therebetween. The space is occupied by a shifting sleeve. A fluid path extends between the interior flowpath of the tool and the space. A fluid control device, occupies at least portion of the fluid path, and may selectively permit fluid flow, and thus pressure communication, into the space to cause a differential pressure across the shifting sleeve. When a sufficient differential pressure is reached, the shifting sleeve is moved from a first position to a second position, which opens the communication paths through the housing and sleeve ports between the interior flowpath and exterior of the tool.

Abstract: A valve seat assembly for actuating a connected downhole tool. The connected downhole tool may be mechanically connected, such as a sleeve positionable between flow ports through a housing, or hydraulically connected, such as through establishing a fluid communication path to the tool to cause actuation thereof. The valve seat assembly generally has a seating element with an having an inlet and an outlet; and a counting element configured to keep a tally of the number times a first pressure at the inlet exceeds a second pressure at the outlet by at least a pre-determined amount.

Abstract: A hydraulically actuated anchor and a mechanically actuated packer are used in combination to secure a production tubing system in a lateral prior to injection of a cement to line the lateral borehole in which the production tubing is positioned. The packer is expanded to prevent fluid cement material from flowing past the packer into a junction area of the lateral with other laterals and aid the removal of superfluous cement material after hardening of the injected cement material around the production tubing system.

Abstract: A cemented open hole selective fracing system is shown. In the producing zone, an open hole is drilled therein and a production tubing is cemented in place. At preselected locations along the production tubing, the production tubing will have sliding valves located there along. The sliding valves may be selectively opened by a shifting tool, and the cement around the sliding valve dissolved. Thereafter, the formation may be fraced immediately adjacent the opened sliding valve. By selectively opening different combinations of sliding valves, fracing can occur in stages with more fracing pressure and more fracing fluid being delivered deeper into the formation. Just as the sliding valves can be selectively opened with a switching tool, the sliding valves can also be selectively closed to protect the production of the well.