A tubular joint installable on a tubular string disposable within a wellbore. The tubular joint may include includes a perforated section, a filter section, and a packer. The perforated section may be proximate a first end and may include a first plurality of orifices to allow fluid communication between a bore of the tubular joint and a first area surrounding the tubular joint proximate the perforated section. The filter section may be proximate a second end and may include a filter assembly sized to filter fluid flowing into the bore via a second plurality of orifices from a second area proximate the filter section. The packer may be disposed between the perforated section and the filter section and may be operable to isolate the first area from the second area when the tubular string is disposed within the well.

Provided, in one aspect, is an anchor for use with a downhole tool in a wellbore. The anchor, according to this aspect, may include a base pipe; and one or more expandable chambers positioned radially about the base pipe. The one or more expandable chambers may, in some aspects, be configured to move from a first collapsed state to a second activated state; and the one or more expandable chambers may be operable to handle at least 20.7 Bar of internal pressure in the second activated state to engage a wall of a wellbore.

A method for joining metallic well tubulars to be lowered into a wellbore (4) comprises the steps of: a) providing a first well tubular (6) having an upper end surface (6a), and a second well tubular (7) having a lower end surface (7a); b) lowering the first well tubular (6) into the wellbore (4), leaving the upper end thereof outside the wellbore (4); c) setting the second well tubular (7) in an axially aligned position on the first well tubular (6), with the lower end surface (7a) of the second well tubular (7) set against the upper end surface (6a) of the first well tubular (6); d) keeping the first and second well tubulars (6, 7) in said axially aligned position; e) welding the upper end of the first well tubular (6) to the lower end of the second well tubular (7), forming a circumferential weld bead (WL) in a position corresponding to said upper and lower end surfaces (6a, 7a); and f) lowering into the wellbore (4) the first well tubular (6) and the second well tubular (7) welded together. Step e) comprises the operations of: providing at least one laser welding head (13), configured for directing a laser beam (LB) towards a circumferential working zone (WA) that includes an upper end portion of the first well tubular (6) and a lower end portion of the second well tubular (7), the at least one laser welding head (13) being displaceable around the circumferential working zone (WA) according to a respective trajectory of revolution; providing at least one induction-heating device (141, 142), which is displaceable substantially according to the trajectory of revolution of the at least one laser welding head (13), the at least one induction-heating device (141, 142) being set upstream, respectively downstream, of the at least one laser welding head (13), with reference to the direction of revolution (R) of the at least one laser welding head (13); causing revolution of the at least one laser welding head (13) and revolution of the at least one induction-heating device (141, 142), in such a way that: the laser beam (LB) progressively forms the circumferential weld bead (WL); and the at least one induction-heating device (141, 142) supplies heat to a corresponding part (PH1, PH2) of the circumferential working zone (WA), which comprises respective parts of said upper and lower end portions of the respective first and second well tubulars (6, 7), before the laser

A string includes a pipe that is connected to an expansion mechanism and a retrieval tool that is connected to the pipe above the expansion mechanism. The retrieval tool includes a carrier that can selectively latch on an expandable liner and one or more actuators. The retrieval tool can ensure latching of the carrier while the expandable liner is above the Blow-out Preventer. The retrieval tool can prevent accidental latching of the carrier on the expandable liner during the expansion of the liner. By manipulating the pipe, the retrieval tool can force the carrier's release from the expandable liner.

A workstring apparatus for creating an annular seal in a wellbore is described. Workstring comprises at least one packer apparatus comprising a body portion and an elastomeric packer element which is deformable into an outwardly deployed condition to deform wellbore casing. A fluid accumulator is provided to hold fluid to actuate at least one hydraulic cylinder of the packer apparatus. An electrically powered pump is operable to pump fluid from accumulator into the hydraulic cylinders of packer apparatus to deform the elastomeric packer element outwardly. A wireline connects the workstring to the surface and provides electrical power to the workstring. Wireline may be an electrical feed such as a composite rod or e-coil.

A tool is provided for expanding the casing at one or more locations for arresting surface casing vent flow in an abandoned well. A setting tool is run into the bore having an expansion element supported thereon. The setting tool imparts a large axial force to radially expand the expansion element for plastically deforming the casing. A single use, pleated ring crushable expansion element can be actuated and left downhole. The pleated ring tool can be pre-charged with a highly viscous fluid, semi solid for transport, but plastic under load. A multi-use expansion element can be actuated, released, moved and actuated again at successive locations.

Expandable tube members that are fabricated from a composite material that includes a structural plastic, which structural plastic includes phase change materials that undergo a permanent expansion upon exposure to wellbore conditions. This permanent expansion of the structural plastic causes the expandable tube member to expand radially and/or longitudinally without the use of an expansion tool. The expandable tube member can be used to control fluid loss, patch wells, stabilize a formation in a wellbore, enhance flow, provide sand screening, and repair damaged pipes, casings, or liners.

Liner hangers and methods of use. An example method includes positioning a liner hanger in a wellbore; the liner hanger comprising: two sealing elements disposed on the exterior of the liner hanger and having a void space therebetween, and a pressure reducing metal element disposed between the two sealing elements. The method further includes trapping a wellbore fluid in the void space; wherein the wellbore fluid thermally expands in the void space creating an annular pressure in the void space; and reducing the annular pressure by materially altering the pressure reducing metal element.

A protective tubular is run downhole into a wellbore in a subterranean formation. A non-metallic tubular is disposed within the protective tubular. The non-metallic tubular includes an adapter. The adapter includes a spring-loaded latch, a ball seat, a shear pin, and a ball catcher. While intact, the shear pin holds a position of the non-metallic tubular relative to the protective tubular. A ball is used to shear the shear pin of the adapter, thereby allowing the non-metallic tubular to move relative to the protective tubular. Pressure is applied to the ball to move the non-metallic tubular relative to the protective tubular. The non-metallic tubular is coupled to the protective tubular using the spring-loaded latch of the adapter. Pressure is applied to the ball to shear the ball seat of the adapter. A fluid is flowed into the non-metallic tubular through an opening defined by the adapter.

A wellbore system includes a wellbore tubular with local inner diameter variation. The system includes a wellbore tubular that is positionable in a wellbore for producing hydrocarbon fluid. The wellbore tubular includes at least one portion of an inner wall with a greater inner diameter than other portions of the inner wall of the wellbore tubular. The system includes a fiber optic cable of a fiber optic sensing system that is positionable in the wellbore for measuring flow disturbance of production fluid at the at least one portion of the inner wall to monitor hydrocarbon production flow.