A downhole apparatus including a tubular body, first and second ports in a wall of the body, and a fluid pressure-responsive valve arrangement having a locked first configuration associated with a first pressure in which the first port is open and the second port is closed, an unlocked second configuration associated with a second pressure higher than the first pressure in which the first port is open and the second port is closed, and a third configuration associated with a third pressure lower than the second pressure in which the second port is open and the first port is closed.

Apparatus and method for sealingly connecting tubular members in a wellbore. In an arrangement where a portion of a tubular member is radially expanded into sealing contact within a second tubular member, and the second tubular member has circumferential recesses on an inner surface, a resilient member protrudes from a side wall of the recesses. The resilient member is acted on by the portion of the tubular member during expansion and maintains sealing contact to the portion after expansion.

A method of making a radially expandable device, including extruding a bulk of a material in an extrusion direction to form an extruded member. The material operatively arranged to disintegrate upon exposure to a selected borehole fluid; and forming a tubular body with the extruded member such that the extrusion direction is aligned circumferentially with respect to the tubular body.

A technique facilitates joining of sections of tubing and related monitoring. An expandable tubular member may be coupled with an external tubing, e.g. a casing. The expandable tubular member is deployed into the external tubing to a desired position. Then, an expandable portion of the expandable tubular member may be plastically deformed in a radially outward direction and into engagement with the external tubing. A sensor system may be combined with the expandable tubular member to monitor a characteristic of the expandable tubular member.

A downhole system and method is disclosed for sealing an inflow control device installed in a subterranean formation along a length of production tubing adjacent a productive zone of the subterranean formation. The system includes a truss structure radially expandable between a contracted configuration and an expanded configuration and a sealing structure disposed radially external to the truss structure. The truss structure and the sealing structure are set in their expanded configurations so that the sealing structure is put into engagement with the inflow control device so as to restrict the flow of fluids from the subterranean formation into the production tubing at the location of the inflow control device.

A system includes an inner string assembly disposed within an outer casing. The inner string assembly includes a seal member in sealing engagement with the outer casing. An expansion sleeve is coupled to an end of the outer casing. An expandable liner is coupled to the expansion sleeve. A cone assembly is coupled to the inner string assembly and positioned proximate to the expansion sleeve when the inner string is in a running position.

An apparatus for use in wellbore includes a device having a shape conforming member that includes a shape memory alloy that has been compressed from a first expanded shape to a second compressed shape. The apparatus further includes a device for supplying electrical energy to the shape memory alloy downhole to transform the shape memory alloy from the second shape to or near the first shape.

A well tool includes a deformable liner configured to be positioned within a wellbore. The deformable liner is configured to be deformed radially. The well tool includes a first inflatable packer configured to be positioned within the deformable liner. The first inflatable packer is configured to be inflated while positioned within the deformable liner to deform the deformable liner radially. The well tool includes a second inflatable packer configured to be positioned around the deformable liner. The second inflatable packer is configured to be inflated to an inner wall of the wellbore.

A pressure intensifier for morphing tubulars downhole. An elongate mandrel defines an inner bore, being co-axially located within an elongate hollow outer cylindrical body to form a co-axial annular bore therebetween. Pistons are mounted upon the mandrel with each piston having an annular fluid facing face extending across the annular bore, with fluid communication between the inner bore and the annular bore to act upon each face. Stops are located on an inner surface of the outer cylindrical body to limit travel of each piston. A morph fluid is located in the annular bore between an opposing face of a first piston and a first stop, with the first stop having delivery ports to deliver the morph fluid at a greater pressure than the pressure of fluid delivered through the inner bore.

A deployment assembly for expanding a liner string in a wellbore includes: a tubular mandrel having a bore therethrough; an expander linked to the mandrel and operable between an extended position and a retracted position; an extension tool disposed along the mandrel and operable to extend the expander; and a retraction tool disposed along the mandrel. The retraction tool has: an upper piston in fluid communication with the mandrel bore and operable to retract the expander; a lower piston in fluid communication with the mandrel bore and operable to balance the upper piston; a valve disposed between the pistons for isolating the lower piston from the upper piston in a closed position; and an electronics package linked to the valve for opening and closing the valve in response to receiving a command signal.