Abstract: A downhole system and related method, which may be used in an injection well for permitting removal, repair and or replacement of equipment installed in the well without unloading the formation in which the well is placed. The system generally includes an annulus sealing device, such as a packer, at least one valve, such as a flapper valve, a latching assembly and a rigid elongate member. The rigid elongate member may be connected to the latching assembly and serves the valve to open and close, or be permitted to open and close. The latching assembly serves to disconnect, and subsequently reconnect, equipment from the annular sealing device. Such release is accompanied by closure of the at least one valve and reconnection by opening of the at least one valve. The latching assembly has seals to prevent fluid from flowing around the latching assembly when the valve is open.

Abstract: Devices, systems and methods are disclosed for re-directing fluid flow from the interior of tubing placed in a well to the exterior of the tubing by use of selectively actuatable valves operable by engagement of a plug on a plug seat. The devices, systems, and methods disclosed may provide a flowback bypass for the flow of fluids around obstructions in the tubing when those obstructions occur at a predicted location within the tubing. The systems, devices and methods may also include a locking system operable by, among other things, plug and plug seat valves, and such locking system may be used to prevent opening of the flowback bypass until after a predetermined event has occurred.

Abstract: A liner hanger assembly to run-in a liner on a liner hanger, cement the liner in place and set the liner hanger in one trip. Then, a wellbore treatment process can proceed while the running string remains downhole or via a second trip. The liner hanger assembly includes a liner hanger running tool and a liner hanger.

Abstract: The described embodiments relate to a downhole tool that can capture a ball in a trap to prevent both upwell and downwell movement of the ball. Further, certain embodiments described herein may prevent fluid from flowing past a captured ball in either the upwell or downwell directions. Ball and seat valves incorporating such ball trap assemblies can be used to create a bi-directional plug which prevents fluid flow in either direction when the ball trap is engaged with an appropriately configured ball.

Abstract: The present disclosure relates to downhole tools, including downhole valves, which actuate via a pressure differential created across a shifting element having one or more pressure surfaces isolated from fluid, and fluid pressure, flowing through the interior flowpath. Embodiment downhole tools of the present disclosure may actuate in response to, among other signals, fluid pressure in the interior flowpath of the tool and fluid pressure communicated to a pressure surface of the shifting sleeve from the exterior of the tool. Certain embodiments may also have an outlet connector whereby fluid pressure from the downhole tool may be communicated to its exterior, including to additional tools in the tubing strings via flowlines connecting the two tools.

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 wellbore packer for setting against a wellbore wall in a wellbore, the wellbore packer including: a mandrel including a upper end and an lower end; and an outer housing encircling the mandrel and including a first compression ring, a second compression ring, an annular packing element encircling the mandrel and positioned between the first compression ring and the second compression ring, the sealing element being expandable to form an annular seal about the packer by compression between the first compression ring and the second compression ring; and an anchoring mechanism including a slip that is expandable outwardly into a set position and a slip actuation assembly to drive expansion of the slip.

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 circulation valve includes: an outer tubular sleeve telescopically mounted at its end over a tubular mandrel; a fluid passage between sleeve and the mandrel, the fluid passage providing fluid communication between the inner bore of the valve and its outer surface; a dual knife seal assembly to control flow out of the fluid flow path through the fluid passage, the dual knife seal assembly including a first annular knife seal edge and land that seal up when the sleeve and mandrel are in a fully axially compressed position and a second annular knife seal edge and land that seal up when the sleeve and mandrel are pulled into a fully in tension position; and, a J-slot position indexing mechanism including a slot and a key to guide movement of the sleeve and the mandrel between the fully in tension position and the fully compressed position. The circulation valve is employed in a wellbore treatment assembly and methods.

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 straddle packer tool for setting against a constraining wall includes: a drag assembly with a locking mechanism for locking a position of the drag assembly relative to the constraining wall; a mandrel installed in and axially moveable through an inner bore of the drag assembly; and a packing element housing including a first annular packing element and a second annular packing element spaced from the first annular packing element, the packing element housing positioned between a stop shoulder on the mandrel and the drag assembly, the packing element being settable to expand the first annular packing element and the second annular packing element by compression between the drag assembly and the stop shoulder. A valve sub including a pressure actuated piston is also described and may be operated to open using the straddle packer tool.

Abstract: A circulation valve includes: an outer tubular sleeve telescopically mounted at its end over a tubular mandrel; a fluid passage between sleeve and the mandrel, the fluid passage providing fluid communication between the inner bore of the valve and its outer surface; a dual knife seal assembly to control flow out of the fluid flow path through the fluid passage, the dual knife seal assembly including a first annular knife seal edge and land that seal up when the sleeve and mandrel are in a fully axially compressed position and a second annular knife seal edge and land that seal up when the sleeve and mandrel are pulled into a fully in tension position; and, a J-slot position indexing mechanism including a slot and a key to guide movement of the sleeve and the mandrel between the fully in tension position and the fully compressed position. The circulation valve is employed in a wellbore treatment assembly and methods.

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 methodology and apparatus for cutting shape(s) or profile(s) through well tubular(s), or for completely circumferentially severing through multiple tubulars, including all tubing, pipe, casing, liners, cement, other material encountered in tubular annuli. This rigless apparatus utilizes a computer-controlled, downhole robotic three-axis rotary mill to effectively generate a shape(s) or profile(s) through, or to completely sever in a 360 degree horizontal plane wells with multiple, nested strings of tubulars whether the tubulars are concentrically aligned or eccentrically aligned. This is useful for well abandonment and decommissioning where complete severance is necessitated and explosives are prohibited, or in situations requiring a precise window or other shape to be cut through a single tubular or plurality of tubulars.

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.