Abstract: A downhole apparatus for use in a tubular include a mandrel, a first slip, a cone, and a seal element. The mandrel, which can be permanent or temporary, has a first end shoulder. The first slip is disposed on the mandrel adjacent the first end shoulder, and the cone is disposed on the mandrel adjacent the first slip. The cone is movable relative to the first end shoulder to engage the first slip toward the tubular. The seal element is disposed on the mandrel adjacent the cone. At least a portion of the seal element is composed of a dissolvable metallic material and is expandable outward from the mandrel. The expanded portion of the seal element forms a metal seal against the tubular and seals off fluid communication in the annular space between the seal element and the tubular.

Abstract: A downhole apparatus for use in a tubular include a mandrel, a first slip, a cone, and a seal element. The mandrel, which can be permanent or temporary, has a first end shoulder. The first slip is disposed on the mandrel adjacent the first end shoulder, and the cone is disposed on the mandrel adjacent the first slip. The cone is movable relative to the first end shoulder to engage the first slip toward the tubular. The seal element is disposed on the mandrel adjacent the cone. At least a portion of the seal element is composed of a dissolvable metallic material and is expandable outward from the mandrel. The expanded portion of the seal element forms a metal seal against the tubular and seals off fluid communication in the annular space between the seal element and the tubular.

Abstract: A downhole apparatus for use in a tubular include a mandrel, a first slip, a cone, and a seal element. The mandrel, which can be permanent or temporary, has a first end shoulder. The first slip is disposed on the mandrel adjacent the first end shoulder, and the cone is disposed on the mandrel adjacent the first slip. The cone is movable relative to the first end shoulder to engage the first slip toward the tubular. The seal element is disposed on the mandrel adjacent the cone. At least a portion of the seal element is composed of a dissolvable metallic material and is expandable outward from the mandrel. The expanded portion of the seal element forms a metal seal against the tubular and seals off fluid communication in the annular space between the seal element and the tubular.

Abstract: Methods and apparatus provides an improved shunt nozzle which is part of an alternative pathway for a slurry to by-pass an obstruction such as a sand bridge during gravel packing. The nozzle includes a hardened insert that lines a surface of an aperture in a shunt. A jacket secured to the shunt receives the insert, which is trapped from movement relative to the jacket.

Abstract: An expandable threaded connection between segments of expandable tubulars. The present invention utilizes two complementary thread segments. The first segment of the threaded connection utilizes standard box and pin threads. In the second segment of the threaded connection, material is removed from the stab flank of the pin threads to reduce the standard width of the pin threads, while the box threads of the second segment are standard thread width. The use of the reduced thread width in the pin threads of the second segment allows for a loose fit between the pin threads of the second segment and the box threads of the second segment. The loose fit between the pin and box threads of the second segment allows radial and axial movement between those threads without causing disengagement of the threaded connection during the expansion process.

Abstract: The present invention generally provides apparatuses and methods for an improved shunt nozzle which is part of an alternative pathway for a slurry to by-pass an obstruction such as a sand bridge during gravel packing. In one embodiment, the nozzle has a hardened insert that lines a surface of a hole in the shunt and seats on a surface of a wall proximate the hole, thereby restraining movement of the insert relative to the shunt for welding an outer jacket to the shunt.

Abstract: The present invention generally relates to a method and an apparatus for placing fiber optic control line in a wellbore. In one aspect, a method for placing a line in a wellbore is provided. The method includes providing a tubular in the wellbore, the tubular having a first conduit operatively attached thereto, whereby the first conduit extends substantially the entire length of the tubular. The method further includes aligning the first conduit with a second conduit operatively attached to a downhole component and forming a hydraulic connection between the first conduit and the second conduit thereby completing a passageway therethrough. Additionally, the method includes urging the line through the passageway. In another aspect, a method for placing a control line in a wellbore is provided. In yet another aspect, an assembly for an intelligent well is provided.

Abstract: The present invention generally relates to a method and an apparatus for placing fiber optic control line in a wellbore. In one aspect, a method for placing a line in a wellbore is provided. The method includes providing a tubular in the wellbore, the tubular having a first conduit operatively attached thereto, whereby the first conduit extends substantially the entire length of the tubular. The method further includes aligning the first conduit with a second conduit operatively attached to a downhole component and forming a hydraulic connection between the first conduit and the second conduit thereby completing a passageway therethrough. Additionally, the method includes urging the line through the passageway. In another aspect, a method for placing a control line in a wellbore is provided. In yet another aspect, an assembly for an intelligent well is provided.

Abstract: A packing assembly which is connectable to reeled tubing and which can be inserted in and pushed through a wellbore tube by the reeled tubing. The packing assembly is hydraulically set in a locking and sealing position in the wellbore by fluid introduced from the reeled tubing and, after use, is hydraulically released and removed from the wellbore. An actuating apparatus is provided for hydraulically actuating the packing assembly and can be converted in a manner to pull the packing assembly from the wellbore. Prior to the removal of the packing assembly from the wellbore, the wellbore fluid pressure is equalized across the packing assembly.

Abstract: A compact, retrievable packer has a unitary mandrel body which is intersected by one or more longitudinal bores. The effective running length of the packer is reduced by an improved arrangement of packer components which serve multiple functions. The hydraulic actuator includes a cylinder housing which also serves as an internal slip housing, a lower element retainer, a piston extension, and a part of the release apparatus. A release sleeve serves as a part of the release apparatus, as a mandrel for engaging a locking slip, and forms a fixed boundary of the hydraulic pressure chamber. The effective running length of the packer is further reduced by making the upper wedge for reacting the setting forces as an integral part of the packer mandrel body.

Abstract: A well packer for sealing an annular space within a well bore around a tubing string including a tubular mandrel, an expandable seal assembly on the mandrel for sealing around the mandrel with a well bore wall, a slip assembly on the mandrel for releasably locking the packer with the well bore wall, a drag spring and slip carrier assembly around the slip assembly, and an interlock assembly for selectively coupling the drag spring and slip carrier assembly with the mandrel for operating the packer through running, set, and release modes. The interlock assembly includes running segments movable a limited distance on the mandrel to prevent jamming of the packer parts in response to mandrel rotation in a non-setting direction. The interlock assembly also includes locking segments having structure to fully seat the segments on the mandrel under load and to minimize packer element compression loss during setting.

Abstract: A packing assembly which is connectable to reeled tubing and which can be inserted in and pushed through a wellbore tube by the reeled tubing. The packing assembly is hydraulically set in a locking and sealing position in the wellbore by fluid introduced from the reeled tubing and, after use, is hydraulically released and removed from the wellbore. An actuating apparatus is provided for hydraulically actuating the packing assembly and can be converted in a manner to pull the packing assembly from the wellbore. Prior to the removal of the packing assembly from the wellbore, the wellbore fluid pressure is equalized across the packing assembly.

Abstract: A latching seal unit for use on a tubing string in a well bore for connecting the tubing string into a well packer having a receiving head provided with one or more latching lugs, the seal unit including a top sub connectable on a tubing string, a tubular locator body connected with the top sub, a latching collet cage having straight-slots mounted on the locator body formed of circumferentially spaced collet fingers defining longitudinal slots and guide surfaces providing entrances into the slots and a latching recess along each of the longitudinal slots, the longitudinal slots being sized to form an interference fit with the latching lugs in the well packer, and the latching recesses being sized to receive the latching lugs, a tubular seal body connected with the locator body, annular seal elements assemblies on the seal body for sealing with a packer bore, and a mule-shoe guide on the seal body below the seal element assemblies.

Abstract: A dual string well packer which is anchored at a downhole location within the bore of a well casing string by relative longitudinal movement between the primary tubing string and the secondary tubing string. The well packer is set by applying tension via the secondary string. The well packer is released from its downhole location by applying tension via the primary string. The invention is particularly adapted for use in well completions that are subject to thermocycling such as steam injection wells. However, the anchoring and releasing mechanism of the present invention can be readily adapted for use with any dual string well packer. The present invention includes an improved method for well completion, minimizing tubing handling requirements during the installation and removal of the production tubing strings and associated dual string well packer.

Abstract: A well tubing extension joint including a trash barrier. A top sub having an internal locking recess is connected on the upper end of a well packer mandrel. A trash barrier is connected on the lower end of an upper tubing string for releaseably engaging the top sub to permit the upper tubing string to move longitudinally relative to the packer and packer top sub. The trash barrier includes a body having locking collet fingers for releaseably locking the body in the top sub at the locking recess. The body has external rings seals for sealing with the top sub and an internal wiper seal for sealing with the upper tubing string extending through the body.

Abstract: Disclosed is apparatus and method for a system useful in establishing a metal to metal seal between conduit joints in wells. A milling tool having means controlling down force on and positioning the cutter is used to cut and/or finish a seat on a shoulder in a well conduit, which will mate and seal with metal seal surfaces on seal units lowered on conduits into the well. One seal unit has elastomeric seals in addition to the metal seals.

Abstract: A latch for releasably anchoring well tools at a preselected downhole location within a well bore. The latch includes collet heads which are sized to be received within an annular recess. The downhole location is defined by the annular recess and a no-go shoulder which limits the movement of the latch into the well bore. The latch is activated by application of force in one direction after contact with the no-go shoulder. A first set of pins is sheared during activation of the latch to prevent retraction of the collet heads from the recess. A second set of pins is sheared by applying force in the opposite direction to allow release of the collet heads from the recess.

Abstract: A submersible pump system for petroleum production in which the pump is suspended from an H-member with production passing up one leg of the H-member and gas passing up the other leg of the H-member. Valve means provide for alternately directing the liquid in a recirculating path through the H-member to the pump while closing in gas flow and closing the cross-member in the H-member and providing for gas and liquid flow through the separate legs of the H-member. The system is coordinated with a subsurface safety valve in the tubing above the H-member and the valve means and subsurface safety valve are controlled by the same pressure line.

Abstract: A packer utilizing a C-slip in which, during release of the packer, the upper expander pulls the C-slip off of the lower expander. If a packer is stuck in the well, the upper expander is keyed to the slip to prevent rotation of the upper expander during milling.

Abstract: A tubular member, to be a segment of the casing string, is provided with a polished bore at its upper end and a locking profile at its lower end. The locking profile includes a bearing shoulder and internal left hand threads for coaction with a latching mechanism. Another tubular member, to be a segment of the production tubing, has groups of circumferentially separated flutes to (1) maintain concentricity of the tubing segment, (2) provide axial flow passages between the segments, and (3) provide support for components of the tubing segment. A tubular packing mandrel, mounted on flutes, carries external annular packing for sealing engagement with the polished bore. The lower end of the packing mandrel defines an annular valve seat; and a tubular valve closure member, mounted in sliding, sealing relation on the tubing segment, has a coacting upward facing valve seat. A valve spring urges closure of the valve closure member.