Abstract: Provided is a method for connecting coiled tubing strings, and a coiled tubing working connector, in accordance with one aspect of the disclosure. The method for connecting coiled tubing strings, in one aspect, includes lowering a downhole end of a first coiled tubing string within a wellbore, an uphole end of the first coiled tubing string remaining outside of the wellbore. The method, in one aspect, further includes coupling the uphole end of the first coiled tubing string to a downhole end of a second coiled tubing string while the uphole end of the first coiled tubing string remaining outside of the wellbore to form a combined coiled tubing string, and lowering the combined coiled tubing string within the wellbore.

Abstract: A method includes deploying a downhole tool within a wellbore. While the downhole tool is within the wellbore, the method also includes slotting or perforating a casing of the wellbore at the target interval to expose formation surrounding the wellbore. Further, the method includes flushing the target interval to remove wellbore debris from the target interval. Furthermore, the method includes pacing a cement or sealant plug at the target interval.

Abstract: The present disclosure generally relates to oilfield equipment and, in particular, to downhole tools, and related systems and methods for characterizing flow in a wellbore. More particularly, the present disclosure relates to methods and systems for obtaining flow data for evaluation of production profiles of wellbores. A system may be provided that comprises a work string, an external support device secured to an exterior of the work string, and at least one data collection device coupled to the external support device.

Abstract: A multilateral entry tool enables an operator to identify a target lateral wellbore, and efficiently guide a bottom hole assembly (BHA) into the target lateral for diagnostic, servicing or other wellbore operations. The multilateral entry tool provides independent control over both kick-over and orientation mechanisms such that the operator may either pivot the BHA without rotating, or rotate the BHA without pivoting. The BHA may be rotated in either direction, and the degree that the BHA can be pivoted may be fully adjustable. Sensors on the entry tool may penult the operator to verify a successful lateral entry, and the BHA may be straightened to reduce drag as the BHA is advanced into the lateral wellbore.

Abstract: A downhole treatment system, apparatus, and methods are disclosed. In some embodiments a treatment apparatus includes a first conduit configured to transport a first fluid from a first fluid source through a first enclosed channel to a first outlet. A second conduit is configured to transport a second fluid from a second fluid source through a second enclosed channel to a second outlet. The treatment apparatus further comprises a mixing applicator that includes the first outlet positioned to provide a discharge path for the first fluid that at least partially intersects a flow path of the second fluid within a confluence region within or external to the second conduit.

Abstract: A multilateral entry tool enables an operator to identify a target lateral wellbore, and efficiently guide a bottom hole assembly (BHA) into the target lateral for diagnostic, servicing or other wellbore operations. The multilateral entry tool provides independent control over both kick-over and orientation mechanisms such that the operator may either pivot the BHA without rotating, or rotate the BHA without pivoting. The BHA may be rotated in either direction, and the degree that the BHA can be pivoted may be fully adjustable. Sensors on the entry tool may penult the operator to verify a successful lateral entry, and the BHA may be straightened to reduce drag as the BHA is advanced into the lateral wellbore.

Abstract: A method of fracturing a formation penetrated by a wellbore, the method includes fracturing the formation by increasing an annulus pressure in the wellbore above a fracture initiation pressure. The method also includes decreasing the annulus pressure below a fracture closure pressure, and re-fracturing the formation by increasing the annulus pressure in the wellbore above the fracture initiation pressure.

Abstract: An actuatable wellbore isolation assembly including a housing defining an axial flowbore and including a mandrel portion, a first end portion, and a second end portion; a radially expandable isolating member positioned circumferentially about the housing; a sliding sleeve circumferentially positioned about the mandrel, the sliding sleeve being movable from a first position, in which the sliding sleeve retains the isolating member in a narrower non-expanded conformation, to a second position, in which the sliding sleeve does not retain the isolating member in the narrower non-expanded conformation; and an actuator assemblage configured to allow movement of the sliding sleeve from the first to the second position. In an exemplary embodiment, the actuator assemblage includes a biasing chamber having a biasing member disposed therein, wherein the biasing member is configured to apply a force to the sliding sleeve to move the sliding sleeve from the first to the second position.

Abstract: A method of fracturing a formation penetrated by a wellbore, the method includes fracturing the formation by increasing an annulus pressure in the wellbore above a fracture initiation pressure. The method also includes decreasing the annulus pressure below a fracture closure pressure, and re-fracturing the formation by increasing the annulus pressure in the wellbore above the fracture initiation pressure.

Abstract: A system comprising a control valve comprising a flapper either activated or inactivated, when activated the flapper may be closed or open and, when inactivated the flapper is open, a first sleeve transitional from a first to a second position, and a second sleeve transitional from a first to a second position, when the first and second sleeves are in the first position, the flapper is activated, when the first sleeve is in the second and the second sleeve is in the first position, the flapper is inactivated, when the first and second sleeves are in the second position, the flapper is activated, the application of pressure to the first sleeve via a first member transitions the first sleeve from the first to the second position, and the application of pressure to the second sleeve via a second member transitions the second sleeve from the first to the second position.

Abstract: A system comprising a control valve comprising a flapper either activated or inactivated, when activated the flapper may be closed or open and, when inactivated the flapper is open, a first sleeve transitional from a first to a second position, and a second sleeve transitional from a first to a second position, when the first and second sleeves are in the first position, the flapper is activated, when the first sleeve is in the second and the second sleeve is in the first position, the flapper is inactivated, when the first and second sleeves are in the second position, the flapper is activated, the application of pressure to the first sleeve via a first member transitions the first sleeve from the first to the second position, and the application of pressure to the second sleeve via a second member transitions the second sleeve from the first to the second position.

Abstract: An actuatable wellbore isolation assembly including a housing defining an axial flowbore and including a mandrel portion, a first end portion, and a second end portion; a radially expandable isolating member positioned circumferentially about the housing; a sliding sleeve circumferentially positioned about the mandrel, the sliding sleeve being movable from a first position, in which the sliding sleeve retains the isolating member in a narrower non-expanded conformation, to a second position, in which the sliding sleeve does not retain the isolating member in the narrower non-expanded conformation; and an actuator assemblage configured to allow movement of the sliding sleeve from the first to the second position. In an exemplary embodiment, the actuator assemblage includes a biasing chamber having a biasing member disposed therein, wherein the biasing member is configured to apply a force to the sliding sleeve to move the sliding sleeve from the first to the second position.

Abstract: An actuatable wellbore isolation assembly comprising a housing generally defining an axial flowbore and comprising a mandrel portion, a first end portion, and a second end portion, a radially expandable isolating member positioned circumferentially about a portion of the housing, a sliding sleeve circumferentially positioned about a portion of the mandrel of the cylindrical housing, the sliding sleeve being movable from, a first position in which the sliding sleeve retains the expandable isolating member in a narrower non-expanded conformation to a second position in which the sliding sleeve does not retain the expandable isolating member in the narrower non-expanded conformation, and an actuator assemblage configured to selectively allow movement of the sliding sleeve from the first position to the second position.

Abstract: A system comprising a control valve comprising a flapper either activated or inactivated, when activated the flapper may be closed or open and, when inactivated the flapper is open, a first sleeve transitional from a first to a second position, and a second sleeve transitional from a first to a second position, when the first and second sleeves are in the first position, the flapper is activated, when the first sleeve is in the second and the second sleeve is in the first position, the flapper is inactivated, when the first and second sleeves are in the second position, the flapper is activated, the application of pressure to the first sleeve via a first member transitions the first sleeve from the first to the second position, and the application of pressure to the second sleeve via a second member transitions the second sleeve from the first to the second position.

Abstract: A bottom hole assembly is provided. The bottom hole assembly comprises an upper component, a lower component and a telescoping assembly disposed between the upper component and the lower component.

Abstract: An actuatable wellbore isolation assembly comprising a housing generally defining an axial flowbore and comprising a mandrel portion, a first end portion, and a second end portion, a radially expandable isolating member positioned circumferentially about a portion of the housing, a sliding sleeve circumferentially positioned about a portion of the mandrel of the cylindrical housing, the sliding sleeve being movable from, a first position in which the sliding sleeve retains the expandable isolating member in a narrower non-expanded conformation to a second position in which the sliding sleeve does not retain the expandable isolating member in the narrower non-expanded conformation, and an actuator assemblage configured to selectively allow movement of the sliding sleeve from the first position to the second position.

Abstract: A bottom hole assembly is provided. The bottom hole assembly comprises an upper component, a lower component and a telescoping assembly disposed between the upper component and the lower component.

Abstract: A tool assembly having a downhole shut-in valve, a packer, and one or more ports. The downhole shut-in valve may be configured to selectively permit flow from a conduit to a target zone of a wellbore. The packer may be configured to isolate the target zone of the wellbore. The ports may be between the conduit and the target zone. The downhole shut-in valve may be configured to close in about 5 seconds or less.

Abstract: An improved fluid container for facilitating the continuous and uninterrupted dispensing of fluid and related methods. Preferably, the fluid container includes a body having an upper portion and a lower portion. The upper portion of the body has an aperture formed therein for permitting fluid to be poured into and out of the body. A vent member is disposed in the body. The vent member has a fluid passageway allowing an external gas to pass through the vent member and into the body as fluid is poured out of the body. The vent member is permanently secured to the body.