Abstract: A collar for a refracturing liner includes a body having a first end and a second end, the first end being configured to connect to a first liner segment, and the second end being configured to connect to a second liner segment. The body defines an inner diameter surface extending between the first and second ends. The collar also includes at least one radial expansion feature formed in the body, wherein the at least one radial expansion feature is configured to deform radially outward when the body is axially compressed, and wherein the at least one radial expansion feature is configured to engage a surrounding tubular and form a fluid flow barrier therewith.

Abstract: An apparatus for use in a string of tubulars includes a first sub having a bore, a second sub attached to the first sub, the second sub having a bore in fluid communication with the bore of the first sub, and a barrier assembly having a frangible member that is configured to break by applying a fluid pressure to the barrier.

Abstract: A downhole tool and a tool assembly, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, a first swage positioned at least partially within the bore and including a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat, and a second swage positioned at least partially within the bore. The first and second swages are configured to move toward one another in the bore, such that the first and second swages deform end portions of the expandable sleeve radially outwards and into engagement with a surrounding tubular, and the expandable sleeve, in an expanded configuration in which the end portions engage the surrounding tubular, defines an unexpanded portion between the expanded end portions.

Abstract: A downhole tool and a method for operating the downhole tool, in which the downhole tool includes a first sensing member, and a second sensing member. The first and second sensing members have a first communication status when the downhole tool is in a first configuration. The first and second sensing members have a second communication status that is different from the first communication status when the downhole tool is in a second configuration. The downhole tool is prevented from actuating prior to the first and second sensing members having the second communication status, and the downhole tool is permitted to actuate after the first and second members have the second communication status.

Abstract: An apparatus for use in a string of tubulars includes a first sub having a bore, a second sub attached to the first sub, the second sub having a bore in fluid communication with the bore of the first sub, and a barrier assembly having a frangible member that is configured to break by applying a fluid pressure to the barrier.

Abstract: Downhole tools and methods, of which the downhole tool includes an expandable sleeve defining a bore therethrough, and a first body positioned at least partially within the bore of the expandable sleeve. The first body is slidable relative to the expandable sleeve, and sliding the first body along the bore of the expandable sleeve causes the expandable sleeve to radially expand so as to actuate the downhole tool from a run-in configuration to a set configuration. The downhole tool also includes an isolation device received at least partially in the expandable sleeve in the set configuration. A pressure on the isolation device is at least partially transmitted to the expandable sleeve as a radially-outward force.

Abstract: A downhole tool and a tool assembly, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, a first swage positioned at least partially within the bore and including a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat, and a second swage positioned at least partially within the bore. The first and second swages are configured to move toward one another in the bore, such that the first and second swages deform end portions of the expandable sleeve radially outwards and into engagement with a surrounding tubular, and the expandable sleeve, in an expanded configuration in which the end portions engage the surrounding tubular, defines an unexpanded portion between the expanded end portions.

Abstract: A downhole tool, tool assembly, and method, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, and including a shoulder that extends inward from the bore, a first swage positioned at least partially within the bore and including a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat, a second swage positioned at least partially within the bore. The first and second swages are configured to deform the expandable sleeve radially outwards when the first and second swages are moved toward one another within the expandable sleeve, and the shoulder is configured to prevent at least one of the first and second swages from sliding therepast.

Abstract: A plugging device, apparatus, and method. The plugging device includes an expandable member configured to move from a first, retracted position to a second, expanded position, a counter configured to count a number of restrictions in a conduit that the plugging device passes through, and an actuator configured to move the expandable member from the first position to the second position in response to the counter counting a predetermined number of restrictions. The expandable member in the expanded position prevents the plugging device from passing through a target restriction.

Abstract: A downhole tool, tool assembly, and method, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, and including a shoulder that extends inward from the bore, a first swage positioned at least partially within the bore and including a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat, a second swage positioned at least partially within the bore. The first and second swages are configured to deform the expandable sleeve radially outwards when the first and second swages are moved toward one another within the expandable sleeve, and the shoulder is configured to prevent at least one of the first and second swages from sliding therepast.

Abstract: Methods of controlling flow into a formation through the use of a stimulation valve in a tubular assembly installed in a well. Fluid is pumped into the formation through one or more ports in the stimulation valve. The stimulation valve defines a conduit for flow of fluids through the stimulation valve. The ports are adapted to allow flow of fluids between the conduit and the exterior of the stimulation valve and to receive a ball sealer for shutting off flow of fluids through the ports. The ports then are closed by introducing a plurality of ball sealers into the fluid. The fluid carries the ball sealers into the valve where they seat on and shut off flow of the fluid through the ports.

Abstract: A downhole tool and a method for fracturing a well, of which the method includes running downhole tool into a wellbore, the downhole tool including a ball seat including a dissolvable material and a protective layer that substantially prevents the dissolvable material from dissolving, and deploying an obstructing member into the wellbore. The obstructing member is caught by the ball seat. The method also includes performing one or more fracturing operations while the obstructing member engages the ball seat. Performing the one or more fracturing operations comprises introducing an abrading fluid to the ball seat, and the abrading fluid erodes at least a portion of the protective layer from the ball seat. The method also includes, after eroding the at least a portion of the protective layer, causing the dissolvable material of the ball seat to at least partially dissolve.

Abstract: Downhole tools and methods, of which the downhole tool includes an expandable sleeve defining a bore therethrough, and a first body positioned at least partially within the bore of the expandable sleeve. The first body is slidable relative to the expandable sleeve, and sliding the first body along the bore of the expandable sleeve causes the expandable sleeve to radially expand so as to actuate the downhole tool from a run-in configuration to a set configuration. The downhole tool also includes an isolation device received at least partially in the expandable sleeve in the set configuration. A pressure on the isolation device is at least partially transmitted to the expandable sleeve as a radially-outward force.

Abstract: A downhole tool and method. The downhole tool includes a first sensing member, and a second sensing member. The first and second sensing members have a first communication status when the downhole tool is in a first configuration. The first and second sensing members have a second communication status that is different from the first communication status when the downhole tool is in a second configuration. The downhole tool is prevented from actuating prior to the first and second sensing members having the second communication status, and the downhole tool is permitted to actuate after the first and second members have the second communication status.

Abstract: A plugging device, apparatus, and method. The plugging device includes an expandable member configured to move from a first, retracted position to a second, expanded position, a counter configured to count a number of restrictions in a conduit that the plugging device passes through, and an actuator configured to move the expandable member from the first position to the second position in response to the counter counting a predetermined number of restrictions. The expandable member in the expanded position prevents the plugging device from passing through a target restriction.

Abstract: A swellable packer includes a base pipe; a swellable sealing element disposed around the outer diameter of the base pipe; and at least one internal backup ring disposed within the swellable sealing element. It may be manufactured by disposing the internal backup ring on the base pipe; applying an elastomeric material over a section of the base pipe and the internal backup ring; and applying a bonding agent over the section of the base pipe and the at least one internal backup ring. It may be used to isolate a section of a well by disposing a swellable packer in the well, and exposing the swellable packer to a fluid, wherein the fluid exposure causes the elastomeric material to radially expand into contact with a well wall.

Abstract: An apparatus includes a counter for tracking and communicating a number of plug drops through a longitudinal bore; a plug element adapted to be dropped into the longitudinal bore; and a valve defining a plug seat to be disposed within the longitudinal bore to catch the plug element when the plug element is dropped and when the number of plug drops as communicated by the counter exceeds a predetermined number. A method, includes: dropping a plurality of plugs down a longitudinal bore in which a plurality of plug seats are disposed; counting the number of plug drops from within the longitudinal bore; and catching one of the plugs at a preselected one of the plug seats when the number of plug drops exceeds a predetermined number.

Abstract: Methods of controlling flow into a formation through the use of a stimulation valve in a tubular assembly installed in a well. Fluid is pumped into the formation through one or more ports in the stimulation valve. The stimulation valve defines a conduit for flow of fluids through the stimulation valve. The ports are adapted to allow flow of fluids between the conduit and the exterior of the stimulation valve and to receive a ball sealer for shutting off flow of fluids through the ports. The ports then are closed by introducing a plurality of ball sealers into the fluid. The fluid carries the ball sealers into the valve where they seat on and shut off flow of the fluid through the ports.

Abstract: An apparatus includes a counter for tracking and communicating a number of plug drops through a longitudinal bore; a plug element adapted to be dropped into the longitudinal bore; and a valve defining a plug seat to be disposed within the longitudinal bore to catch the plug element when the plug element is dropped and when the number of plug drops as communicated by the counter exceeds a predetermined number. A method, includes: dropping a plurality of plugs down a longitudinal bore in which a plurality of plug seats are disposed; counting the number of plug drops from within the longitudinal bore; and catching one of the plugs at a preselected one of the plug seats when the number of plug drops exceeds a predetermined number.

Abstract: Disclosed herein is a downhole tubular sealing system. The system includes, a tubular runnable in a downhole wellbore, a swellable seal disposed at the tubular that is sealable with the downhole wellbore when swelled, and at least one releasable member in operable communication with the tubular and the swellable seal. The at least one releasable member configured to longitudinally fix the swellable seal to the tubular when nonreleased and to longitudinally disengage the swellable seal from the tubular when released.