The present disclosure relates to a particularly effective well configuration that can be used for single well steam assisted gravity drainage of SW-SAGD wherein steam flashing through production slots is prevented by included passive inflow control devices or active interval control valves in the completion.

A plug assembly including a breaker object and a plug, having a first position in which the breaker object is not in contact with the plug and a second position where the breaker object is in contact with the plug, wherein the movement from the first position to the second position initiated by pressure applied to the plug, wherein: the breaker object includes an impact surface where the impact surface is the projection of the plug surface onto the breaker object, and the impact surface includes an impact point wherein: the impact point is the portion of the plug which makes contact with the breaker object when the plug assembly is in the second position; and the impact surface has the cross sectional shape of a portion of a conic section.

A well tool device (1) comprising a housing (10) having a through channel (11) with a first end (11a) and a second end (11b), said housing (10) further comprises a breakable ball seat (15), wherein a drop ball (17) received in the ball seat (15) partially or fully closes fluid communication in the through channel (11) of the housing (10). The breakable ball seat (15) is made of brittle and/or tempered glass, wherein the ball seat (15) is broken by a pressure build up in the housing (10) forcing the ball seat (15) against one or more disintegrating means (16), said disintegrating means (16) are provided as inside protrusions in the through channel (11).

A toe valve (1) comprising; a housing (200) having an interior and exterior; a sliding sleeve (8); a counter mechanism (2) comprising a cylinder, a ratchet piston (11, 27) with first and second ends, and a ratchet shaft (14, 28) connected to the second end; a trigger assembly (3) comprising a trigger housing, and a release piston (19), wherein the trigger assembly (3) is arranged between the counter mechanism (2) and the sliding sleeve (8), and wherein the release piston (19) is configured to activate the sliding sleeve (8), and the ratchet shaft (14, 28) is configured to activate the release piston (19), wherein the toe valve (1) further comprises; a closed chamber (15) enclosing the ratchet shaft (14, 28) and defined at least partly by the cylinder comprising a chamber fluid with a chamber pressure (P2); an inlet pressure port (6) configured to be in communication with a wellbore fluid with a wellbore pressure (P1), and wherein the first end of the ratchet piston (11, 27) is in fluid communication with the inlet pressure port (6), wherein the ratchet piston (11, 27) is configured to move towards the trigger assembly (3) to a new position and compress the chamber fluid when the wellbore pressure (P1) is larger than the chamber pressure (P2); a retaining mechanism (29) configured to retain the ratchet shaft (14, 28) in the new position; and a valve mechanism interconnecting the first and second ends of the ratchet piston (11, 27) and configured for equalizing the pressure across the ratchet piston (11, 27).

A protection system for a drilling riser. The drilling riser includes a main drilling riser bore and a drilling riser annulus and extends from a floating installation to a location on a seafloor and is fluidly connected to a subsea BOP. The system includes a fluid conduit which extends from the floating installation to a lower region of the drilling riser. The fluid conduit is fluidly connected with the drilling riser annulus in the drilling riser. The fluid conduit provides at least one of a rapid pressure relief and a fluid bypass for the main drilling riser bore to prevent the drilling riser from an uncontrolled pressure build-up due to an inadvertent plugging or a restriction resulting in a maximum allowable working pressure (MAWP) of the drilling riser being exceeded, if a restriction, a plug or a blockage exists in the drilling riser annulus or in riser outlets.

Disclosed is a sliding sleeve assembly that includes a sliding sleeve sub coupled to a work string extended within a wellbore, the sliding sleeve sub having one or more ports defined therein that enable fluid communication between an interior and an exterior of the work string, a sliding sleeve arranged within the sliding sleeve sub and movable between a closed position, where the sliding sleeve occludes the one or more ports, and an open position, where the sliding sleeve has moved to expose the one or more ports, a sleeve profile defined on an inner surface of the sliding sleeve, a wellbore dart having a body and a plurality of collet fingers extending longitudinally from the body, and a dart profile defined on an outer surface of the plurality of collet fingers, the dart profile being configured to selectively mate with the sleeve profile.

A temporary well isolation device which has an axial passage that comprises a temporary housing having an internal cavity containing a chemical material and a temporary barrier or plug member that can be actuated by an external mechanism to allow fluid to flow into the internal chamber and contact the chemical material in the internal chamber. When the chemical material is exposed to fluid, the chemical material causes the temporary housing to corrode, dissolve, and/or degrade.

A barrier assembly for a wellbore is disclosed. The barrier assembly includes a housing, a shroud in the housing, and a plug in the shroud. The shroud and plug are made of a dissolvable material that will establish a fluid barrier until such time as the shroud and/or plug dissolves thereby releasing from the housing. The plug is held to the shroud with a shear screw which is susceptible to shearing with application of sufficient pressure to terminate the fluid barrier before the plug and/or shroud dissolves.

A downhole sub has a body defined by a wall extending in an axial direction from a first end to a second end. An inner surface of the wall defines a flow path through the downhole sub and an outer surface of the wall defines an outer diameter of the downhole sub. A compartment extends from the outer surface into the wall to having a depth less than a thickness of the wall. A housing may be removably fixed in the compartment. One or more mobile devices may be disposed in the housing. Each of the one or more mobile devices includes a sensor encapsulated in a protective material. A control element may block an opening of the housing, the control element is made of a dissolvable material configured to dissolve at a predetermined depth in a wellbore and release the one or more mobile devices into the wellbore.

A stage tool comprises a body with a tubular wall, defining an outer surface and an inner surface. Fluid ports, such as cement circulation ports, extend through the tubular wall. The stage tool further comprises a primary closing sleeve. The primary closing sleeve may be movable along the outer surface of the tubular wall for closing the ports when the treatment of the wellbore stage ends. A secondary closing sleeve may be movable along the inner surface of the tubular wall for closing the port in case of failure of the primary closing sleeve or for redundancy. The primary closing sleeve may be actuated by an internal member joined to the primary closing sleeve by a crosslink and movable on the inner surface. The internal member and the secondary closing sleeve may move along different surfaces on the internal wall to avoid interference.