Abstract: A downhole tool includes a housing configured to be connected between two tubular members. The housing includes a chamber and a plug assembly is disposed in the chamber and divides the chamber into an up-hole portion and a downhole portion. The plug assembly includes a glass member having a predetermined residual surface compression, at least a first face, and at least one strength-reducing surface feature on the first face. The strength-reducing surface feature is configured to cause the glass member to disintegrate when the glass member is exposed to a pressure in the up-hole portion of a magnitude that creates a tensile stress on the first face that exceeds the predetermined residual surface compression.

Abstract: A system includes a string disposed in a wellbore, a first valve coupled to the string, the first valve including a sleeve having an engagement profile with a first coded sequence, a second valve coupled to the string, the second valve including a sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve, and a first dart flow transportable through the string, the first dart including a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to engage the engagement profile of the second valve, wherein the first dart actuates the sleeve of the second valve between first and second positions in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve.

Abstract: A sliding sleeve valve for use in a borehole includes an outer housing including a radial housing slot, a sliding sleeve slidably disposed in the outer housing, the sliding sleeve including a radial sleeve slot and configured to have a first position that restricts fluid communication between the sleeve slot and the housing slot and a second position, spaced from the first position, that permits fluid communication between the sleeve slot and the housing slot, an actuator housing coupled to the outer housing, wherein the actuator housing includes an actuator chamber defined by an inner surface, and wherein the actuator chamber is disposed between an inner surface and an outer surface of the actuator housing, and an actuator assembly disposed in the actuator chamber, wherein the actuator assembly is configured to control movement of the sliding sleeve between the first and second positions.

Abstract: Plug assemblies for plugging a wellbore tubular and methods relating thereto are disclosed. In an embodiment, the plug assembly includes a central axis and a seal sub including a plurality of axially extending fingers and a tapered outer surface. In addition, the plug assembly includes a sealing element coupled to the axially extending fingers of the seal sub. Further, the plug assembly includes a slip sub including a tapered inner surface, and a plurality of axially extending fingers. The fingers of the slip sub each include one or more teeth. The seal sub is configured to be at least partially inserted within the slip sub so that the tapered outer surface engages with the tapered inner surface, and axial advance of the tapered inner surface within the tapered outer surface is to radially expand the fingers of the slip sub to engage with an inner surface of the tubular.

Abstract: A system includes a string disposed in a wellbore, a first valve coupled to the string, the first valve including a sleeve having an engagement profile with a first coded sequence, a second valve coupled to the string, the second valve including a sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve, and a first dart flow transportable through the string, the first dart including a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to engage the engagement profile of the second valve, wherein the first dart actuates the sleeve of the second valve between first and second positions in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve.

Abstract: A sliding sleeve valve for use in a borehole includes an outer housing including a radial housing slot, a sliding sleeve slidably disposed in the outer housing, the sliding sleeve including a radial sleeve slot and configured to have a first position that restricts fluid communication between the sleeve slot and the housing slot and a second position, spaced from the first position, that permits fluid communication between the sleeve slot and the housing slot, an actuator housing coupled to the outer housing, wherein the actuator housing includes an actuator chamber defined by an inner surface, and wherein the actuator chamber is disposed between an inner surface and an outer surface of the actuator housing, and an actuator assembly disposed in the actuator chamber, wherein the actuator assembly is configured to control movement of the sliding sleeve between the first and second positions.

Abstract: Plug assemblies for plugging a wellbore tubular and methods relating thereto are disclosed. In an embodiment, the plug assembly includes a central axis and a seal sub including a plurality of axially extending fingers and a tapered outer surface. In addition, the plug assembly includes a sealing element coupled to the axially extending fingers of the seal sub. Further, the plug assembly includes a slip sub including a tapered inner surface, and a plurality of axially extending fingers. The fingers of the slip sub each include one or more teeth. The seal sub is configured to be at least partially inserted within the slip sub so that the tapered outer surface engages with the tapered inner surface, and axial advance of the tapered inner surface within the tapered outer surface is to radially expand the fingers of the slip sub to engage with an inner surface of the tubular.

Abstract: A technique facilitates avoidance of premature actuation of a liner hanger in a wellbore. The technique utilizes a running string which may be coupled to a liner having a liner hanger. The running string extends into the liner in a manner which creates an inner pressure region within the running string, an intermediate pressure region between the running string and the liner, and an outer or annulus pressure region surrounding the liner. The inner pressure region is initially isolated from the intermediate pressure region by a closure mechanism during, for example, movement downhole. The closure mechanism selectively closes off a port used to actuate the liner hanger.

Abstract: A downhole tool includes a body supported from a running string; and a releasing assembly for releasing from set liner hanger portions of the tool to be retrieved to the surface. The releasing assembly includes a connecting member for engaging the tool with a liner hanger, a piston hydraulically moveable in response to fluid pressure within the tool body from a lock position to a release position for releasing the connecting member, and a clutch for rotationally releasing the tool body from the liner hanger. Rotation of the running string moves a nut upward along the body so that the running string may then be picked up to disengage the tool from the liner hanger.

Abstract: A downhole tool includes a body supported from a running string; and a releasing assembly for releasing from set liner hanger portions of the tool to be retrieved to the surface. The releasing assembly includes a connecting member for engaging the tool with a liner hanger, a piston hydraulically moveable in response to fluid pressure within the tool body from a lock position to a release position for releasing the connecting member, and a clutch for rotationally releasing the tool body from the liner hanger. Rotation of the running string moves a nut upward along the body so that the running string may then be picked up to disengage the tool from the liner hanger.

Abstract: A downhole tool includes a body supported from a running string; and a releasing assembly for releasing from set liner hanger portions of the tool to be retrieved to the surface. The releasing assembly includes a connecting member for engaging the tool with a liner hanger, a piston hydraulically moveable in response to fluid pressure within the tool body from a lock position to a release position for releasing the connecting member, and a clutch for rotationally releasing the tool body from the liner hanger. Rotation of the running string moves a nut upward along the body so that the running string may then be picked up to disengage the tool from the liner hanger.

Abstract: A technique facilitates avoidance of premature actuation of a liner hanger in a wellbore. The technique utilizes a running string which may be coupled to a liner having a liner hanger. The running string extends into the liner in a manner which creates an inner pressure region within the running string, an intermediate pressure region between the running string and the liner, and an outer or annulus pressure region surrounding the liner. The inner pressure region is initially isolated from the intermediate pressure region by a closure mechanism during, for example, movement downhole. The closure mechanism selectively closes off a port used to actuate the liner hanger.

Abstract: A pressurizing device includes a main housing having a central bore therethrough and a ball drop module removably disposed within the main housing, the ball drop module including a ball seat hingedly attached within the ball drop module and configured to receive a dropped ball, wherein the ball seat is configured to rotate about a hinge from a closed position to an open position when a pressure above the ball seat exceeds a preset limit.

Abstract: A downhole tool includes a body supported from a running string; and a releasing assembly for releasing from set liner hanger portions of the tool to be retrieved to the surface. The releasing assembly includes a connecting member for engaging the tool with a liner hanger, a piston hydraulically moveable in response to fluid pressure within the tool body from a lock position to a release position for releasing the connecting member, and a clutch for rotationally releasing the tool body from the liner hanger. Rotation of the running string moves a nut upward along the body so that the running string may then be picked up to disengage the tool from the liner hanger.

Abstract: A pressurizing device includes a main housing having a central bore therethrough and a ball drop module removably disposed within the main housing, the ball drop module including a ball seat hingedly attached within the ball drop module and configured to receive a dropped ball, wherein the ball seat is configured to rotate about a hinge from a closed position to an open position when a pressure above the ball seat exceeds a preset limit.