A valve assembly for integration within a wellbore string disposed within a subterranean reservoir is provided. The valve assembly includes a valve housing having one or more injection ports for establishing fluid communication between a central passage and the reservoir. The valve assembly includes a valve sleeve operatively mounted within the valve housing and comprising a fluid channel adapted to establish fluid communication between the central passage and the injection ports, and configured to create a fluid flowrate restriction. The valve assembly has a flow adjuster connectable to the valve sleeve, and is selectively arranged to align an opening with the fluid channel and allow fluid to flow from the fluid channel through the opening to the injection port, wherein connecting the flow adjuster to the valve sleeve defines a flow length of the fluid channel to adjust the fluid restriction created by the fluid channel.

A valve arrangement is for a downhole apparatus having a tubular body having first and second ports in a wall thereof. The valve arrangement being configurable to be locked in a first configuration with the tubular body, such that the first port is closed and the second port is closed; configurable to be locked in a second configuration with the tubular body, such that the first port is open and the second port is closed; and configurable to be locked in a third configuration with the tubular body, such that the first port is closed and the second port is open.

A crossover tool for use in a wellbore includes: a tubular housing having a bypass port; a mandrel having a bore therethrough and a mandrel port in fluid communication with the mandrel bore, the mandrel movable relative to the tubular housing between a first position where the mandrel port is isolated from the bypass port and a second position where the mandrel port is aligned with the bypass port; and an actuator operable to move the mandrel between the first position and the second position. The actuator includes a first piston connected to the mandrel and a second piston operable in response to the first piston.

A well tool device includes a housing having an axial through bore; a sleeve section axially displaceable relative to the housing; a fluid flow preventing frangible disc; and an axial fluid passage bypassing the frangible disc when the well tool device is in an initial state, thereby allowing a fluid flow between a first location above the frangible disc and a second location below the frangible disc. The sleeve section includes an axial through bore aligned with the axial through bore of the housing. The axial fluid passage is closed when the well tool device is in a intermediate state. The fluid flow preventing frangible disc is provided in the bore of the sleeve section in sealing engagement with the sleeve section. The well tool device further includes a disc supporting device for supporting the frangible disc in relation to the sleeve section. The disc supporting device is releasably connected inside the sleeve section by a releasable connection device. The well tool device further includes a disintegration device disintegration of the frangible disc. The well tool device is in a final state when the frangible disc has been disintegrated by the disintegration device. The frangible disc is configured to be pushed axially relative to the sleeve section towards the disintegration device after release of the disc supporting device.

A tool for both perforating a well casing in a hydrocarbon formation and for subsequently fracturing the formation. The tool allows not only perforation and fracking, but in a preferred embodiment allows both perforation of the casing and fracking of the formation without having to further reposition the tool within the wellbore. The tool comprises a cylindrical member having thereon an upper and lower seal member and a longitudinal bore therein, and a cooperating piston which operates a punch to perforate the well casing. A flushing port is provided immediately uphole of the upper seal member, which port when said tool is lowered downhole allows fluid flowing up a longitudinal channel to flush an annular region immediately uphole of said upper seal, thereby greatly reducing the incidence of sand impaction and thereby better allow the tool to be moved uphole for further perforation and fluid injection into the formation.

An apparatus and method for displacing a sleeve within a downhole tool wherein the apparatus comprises an outer mandrel, and a sleeve extending between first and second ends slidably located within the outer mandrel wherein the sleeve and mandrel form first, second and third annular chambers therebetween. The first annular chamber is in fluidic communication with an interior of the sleeve. The second annular chamber is in fluidic communication with an exterior of the mandrel. The third annular chamber is substantially sealed. The method comprises pressurizing the second chamber through bores extending through the sleeve and releasing the pressure within the second chamber so as to permit a vacuum within a third sealed chamber and a pressure from an exterior of the mandrel to pressurize a first chamber to draw the sleeve towards a second end of the outer mandrel thereby uncovering the valve openings.

A new cement valve is disclosed for use in the production of an oil or gas well where hydraulic fracturing has been employed. In particular, the embodiments include a cement valve having a reclosable valve. When properly located, a first piston sleeve is hydraulically actuated to open the cement ports on the tool. After the cement has been pumped through the tool and the cement ports to a wellbore annulus, a blocking ball is dropped to stop flow through the tool. The tool is internally pressurized. The pressure overcomes shear pins to force downward movement of a ball housing inside the cement valve. This movement translates a travelling pin along a guide path, which rotates a ball valve inside the ball housing, releasing the blocking ball to open up the internal flow path through the cement valve at the same time the cement ports are closed.

A sliding valve for opening one or more fluid ports in a piping string, having a valve body and a sliding sleeve in a longitudinal bore thereof. The valve body has one or more fluid ports in an uphole portion thereof. The sliding sleeve is movable in the valve body between an uphole closed position closing the one or more fluid ports and a downhole open position opening the ports. The sliding sleeve has a longitudinal bore for receiving a collet, and/or a stop ring and/or a protective sleeve. The stop ring forms a stop shoulder for preventing downhole movement of the collet relative to the sliding sleeve.

A tubing conveyed tool for use in perforating a well bore utilizing abrasive perforating techniques. The perforating tool is particularly useful in non-vertical wells. The perforating tool is designed to permit running and setting a bridge plug, and then perforating the well bore without requiring the removal of the tool string. An eccentric weight bar can also be used to allow for directional perforating in non-vertical wells. The eccentric weight bar uses gravity to cause the bar to rotate to a predetermined position.

A valve assembly comprises an actuation fluid inlet, an actuation fluid outlet and a valve member moveable between a closed position in which the actuation fluid outlet is closed, and an open position in which the actuation fluid outlet is opened. A locking arrangement is provided for locking the valve member in its closed position, wherein the locking arrangement is operable in response to a first predetermined fluid pressure event associated with at least the actuation fluid inlet to release the locking arrangement to permit the valve member to be moved to its open position in response to a second subsequent predetermined fluid pressure event associated with at least the actuation fluid inlet.