Abstract: A pressurization tool comprises a body for connection to a tubular by box, and pin, and providing for flow of fluid by way of a throughbore of varying cross-section to form chambers. A lower chamber accommodates a spring that contacts a shoulder providing a reaction surface for compression of the spring under applied force. The chamber merges into intermediate chamber that accommodates a movable index sleeve that cooperates with an index pin inserted through the wall of the tool body. Associated with the upper part of the index sleeve is a valve seat assembly, positioned to abut the index sleeve and moveable therewith, said valve seat assembly being configured to receive a plug or ball, and in one unpressurised configuration, is located in a wider chamber that permits fluid flow around the assembly.

Abstract: An apparatus for isolating fluid flow in a bottomhole tool assembly comprises a generally cylindrically shaped flow tube with a side, a top, and a bottom; an upper ball seat connected to the top of the flow tube; a lower ball seat connected to the bottom of the flow tube; a plurality of openings in the side of the flow tube; a tapered inner diameter in the upper ball seat, acting as a ball valve; a tapered inner diameter in the lower ball seat, acting as a ball valve, smaller than the tapered inner diameter in the upper ball seat; an upper sub attached to the bottomhole tool assembly; a lower sub attached to the bottomhole tool assembly; shear pins connecting the upper ball seat to the upper sub; and a limiting pin in the lower sub below the lower ball assembly.

Abstract: A downhole tool incorporating a sleeve assembly with an actuatable element, such as the seat of a plug-and-seat combination, and a seal assembly, such as a flapper seal assembly. The sleeve assembly is movable between a first position, in which the seal assembly is opened and inhibited from closing by contact with the sleeve assembly, and a second position in which the seal assembly is closed. Upon closing of the flapper assembly, the downhole tool may withstand higher pressures with reduced risk of failure to maintain a pressure differential across the tool.

Abstract: A plug counter includes a seat receptive of a plug in a first position and capable of passing the plug in a second position. A first sleeve is in operable communication with the seat and is longitudinally movable in response to movement of the seat between the first position and the second position. A second sleeve is in operable communication with at least one of the first sleeve and the seat and is configured to index upon passage of the plug. A key is in operable communication with the seat and is configured to prevent movement of the seat to the second position after a selected number of plugs have passed the seat. A third sleeve is in operable communication with the first sleeve, and a release member is in operable communication with the third sleeve and is configured to move the third sleeve after it is released.

Abstract: A wellbore servicing system, comprising a sleeve system comprising a ported case, a sliding sleeve within the case and movable between a first sleeve position in which the sleeve restricts fluid communication via the case and a second sleeve position in which the sleeve does not, a radially divided segmented seat movable between a first seat position in which the seat restricts movement of the sleeve and a second seat position in which the seat does not, and a sheath covering a portion of the seat, the sleeve system being transitionable from a first, to a second, to a third mode, in the first mode, the sleeve is in its first position and the seat in its first position, in the second mode, the sleeve is in its first position and the seat in its second position, and, in the third mode, the sleeve is in its second position.

Abstract: A wellbore servicing apparatus comprising a housing substantially defining an axial flowbore and comprising one or more ports, an expandable seat, and a sliding sleeve slidably fitted within the housing, the sliding sleeve being transitional from a first position to a second position and from the second position to a third position, wherein, in the first position, the sliding sleeve does not permit fluid communication via the one or more ports and the expandable seat is retained in a narrower, non-expanded conformation, wherein, in the second position, the sliding sleeve permits fluid communication via the one or more ports and the expandable seat is retained in a narrower, non-expanded conformation, and wherein, in the third position, the sliding sleeve does not permit fluid communication via the one or more ports and the expandable seat is allowed to expand into a wider, expanded conformation.

Abstract: A downhole apparatus for engaging a borehole in a subterranean formation includes a tubular body having a longitudinal axis and a first bore, an actuation element having a second bore and is positioned within the first bore of the tubular body, a drilling fluid flow path extending through the first and second bores, and a restriction element trap positioned within the second bore of the actuation element. The actuation element is configured to selectively retain an operable component of the downhole apparatus in an initial position and the restriction element trap is configured for retentively receiving a restriction element. A restriction element trap for use with an actuation element for retentively receiving a restriction element and an expandable reamer apparatus for enlarging a borehole in a subterranean formation are also provided. Further provided is a method of activating a downhole apparatus within a borehole of a subterranean formation.

Abstract: A circulating sub apparatus including a substantially tubular outer body member having a throughbore formed therein and a substantially tubular inner body member. The outer body member having at least one hole formed therein and a displacement mechanism for producing movement of the inner body member relative to the outer body member such that the inner body member is moveable between an open configuration and an obturated configuration. The inner body member includes a seat member adapted to catch a dropped object, the seat member is located upstream of the hole(s) of the outer body member in both the open and obturated configurations, and wherein the seat member is adapted to permit at least a proportion of fluid to flow past the dropped object when it is seated thereon.

Abstract: A sliding sleeve valve for wellbore operations includes: a tubular body including a tubular wall including an outer surface and an inner surface defining an inner bore; a fluid port extending through the tubular wall and providing fluidic communication between the outer surface and the inner bore; a sliding sleeve in the inner bore slidably moveable between a port closed position and a port open position, the sliding sleeve including a ball seat on which a plug is landed to move the sleeve from the port closed position to the port open position; an initial sleeve holding mechanism for holding the sliding sleeve in the port closed position, the initial sleeve holding mechanism selected to be overcome by landing a plug on the ball seat to move the sliding sleeve; and a second sleeve holding mechanism for holding the sliding sleeve in the port closed position after the sliding sleeve is reclosed from the port open position to the port closed position, the second sleeve holding mechanism selected to be overcome b

Abstract: A tubular actuating system includes a tubular, a plurality of same plugs runnable within the tubular, an actuator disposed within the tubular, and a seatable member disposed at the actuator configured to be respositionable relative to the actuator between an unseated position and a seated position upon passage of at least one of the plurality of same plugs.

Abstract: A method of cementing a liner string into a wellbore includes deploying a liner string into a wellbore; pumping cement slurry into a workstring; and pumping a dart through the workstring, thereby driving the cement slurry into the liner string. The dart engages a first wiper plug and releases the first wiper plug from the workstring. The dart and engaged first wiper plug drive the cement slurry through the liner string and into an annulus formed between the liner string and the wellbore. The dart and engaged first wiper plug land onto a first fracture valve. The dart releases a first seat into the first wiper plug. The dart engages a second wiper plug connected to the first fracture valve and releases the second wiper plug from the first fracture valve.

Abstract: The segmented ball seat valve is an annular communication valve normally installed in a string of pipe that is to be deployed to a depth within a well. The segmented ball seat valve provides communication between the inside of the pipe and the well bore or casing through open ports. The segmented ball seat valve can be closed to shut off communication by dropping/pumping a ball to the segmented ball seat valve and applying pressure to close the valve. The application of pressure causes the ball seat assembly to move downward into an enlarged portion of the bore. The segments of the seat assembly move outward in the enlarged area to permit passage of the ball.

Abstract: The present invention is to an internal sleeve slidably received within a tubular housing. The sleeve and outer housing have windows that selectively align. Movement of the sleeve within the housing is controlled by a ball passing through the interior of the sleeve to activate a ratchet that allows the sleeve to move a set amount under the influence of a spring. A split seat at a lower end of the housing traps after a set number of balls have passed through the housing. A number of similar tools can be used to provide openings at various points that include coordinated ratchet steps so that only one tool at a time opens for fracturing or other purposes. A reverse flow causes a ball to impinge upon the next higher ball seat and thereby opening the seat to provide a full bore flow passage through the tool.

Abstract: Techniques and equipment to facilitate controlling flow of a fluid along a flow passage. A flow control assembly is placed along a flow passage, and a bypass is routed past the flow control assembly. Flow along the bypass is controlled by a flow bypass mechanism which may be operated via pressure increase within the flow control assembly. A shear device restricts the opening of the bypass, and a dampening device acts to limit the shear device to exposure of forces from the pressure increase.

Abstract: A multi-function diverter tool is disclosed that allows positive-indication opening and closing of the tool in a downhole environment.

Abstract: A valving system includes a tubular and a sleeve slidably engaged with the tubular having a seat thereon. The sleeve is configured to occlude flow from an inside of the tubular to an outside of the tubular when in a first position, allow flow between an inside of the tubular and an outside of the tubular at a first location upstream of the seat and a second location downstream of the seat when in a second position, and allow flow between an inside of the tubular and an outside at the tubular at the first location and not the second location when in a third position. The valving system also includes a disappearing member in operable communication with the tubular and the sleeve configured to prevent movement of the sleeve to the third position until disappearance thereof.

Abstract: A system and method for selectively stimulating a plurality of producing zones in a wellbore in oil and gas wells. The system includes a plurality of modules connected in a string that may be selectively actuated to stimulate a producing zone. Each module may be adapted to engage a tubing run ball seat. After installation of the string within the wellbore, a ball seat may be run into the well and positioned to selectively engage a desired module. The ball seat may be used to open a sleeve of the module permitting the stimulation of the producing zone. After stimulation of the producing zone, the ball seat may be removed from the wellbore rather than needing to drill out the ball seat. The sleeve may include a profile adapted to engage a shifting tool permitting the selective closure of the sleeve after stimulation of the producing zone.

Abstract: A control mechanism for a downhole tool including a mandrel having a throughbore, at least one activation port, and at least one bypass port, a first sleeve detachably mounted within the throughbore at a first position and moveable to a second position, the first sleeve having a first seat, and a second sleeve detachably mounted within the throughbore at a third position located axially above the first position and moveable to a fourth position, the second sleeve having a second seat. A method of hydraulically actuating and deactuating a downhole tool, the method including disposing the downhole tool and a control mechanism in a well.

Abstract: A cement retainer comprises a plug that may be run into casing on a wire line and set in a conventional manner. A passage through the plug allows cement to be pumped therethrough. A wiper plug follows the cement, wipes the inside of the casing and latches onto the retainer to prevent back flow of cement. In some embodiments, the cement retainer and wiper plug are made of drillable materials allowing a series of squeeze operations to be conducted, one after another without undue delay, and then be drilled up in a single bit run. In some embodiments, the cement retainer and wiper plug are made of metals, drillable or non-drillable, or other long lived materials in order to plug wells in the process of abandoning them.

Abstract: Disclosed herein is a segmented seat for use in wellbore servicing systems, comprising an annular-shaped seat with an upward facing surface for receiving an obturator, the seat defining a central passageway. The seat comprises one or more slots or passageways and, wherein at least one slot or passageway extends continuously between seat segments. The at least one slot or passageway contains a nonmetallic material suitable for retaining the segments together yet frangible or flexible enough to allow the segments to separate when forced to do so. The segments have gripping surfaces which prevent or inhibit rotation of the seat during removal.

Abstract: An actuation dart for actuating a target tool in a tubing string, the actuation dart includes: a body conveyable through the tubing string to reach the target tool; a control module configured to respond to contact with at least one downhole tool in the tubing string to locate the target tool; and an actuation mechanism for actuating the target tool when it is located.

Abstract: A technique that is usable with a well includes deploying a plurality of location markers in a passageway of the well and deploying an untethered object in the passageway such that the object travels downhole via the passageway. The technique includes using the untethered object to sense proximity of at least some of the location markers as the object travels downhole, and based on the sensing, selectively expand its size to cause the object to become lodged in the passageway near a predetermined location.

Abstract: The present application is to a method of sequentially drilling a number of frac sleeves in a down hole well. The design enables the removal of fracture sleeve pistons from between treatment zones without requiring drilling or milling of the sleeve while allowing for full flow of fluids after treatment. A number of plugs or pistons having sequentially smaller central bores allows for balls to sequentially be inserted through the tool to selectively close off the pistons to isolate one zone from another. A release tool may inserted into the tool to engage and unthread the plugs to open up the inner diameter of the tool to allow greater production flow through the tool. The plugs may have mating tabs and holes so that as each plug is unthreaded it falls to the next plug and engages so that each plug may sequentially be unthreaded from the sleeve.

Abstract: A device to allow a single ball size to actuate at least two downhole tools. Typically when a large number of ball actuated devices are run in a single well the total number of devices is limited by the increasing size of the balls required to actuate each sequential device. By having a mechanism that allows at least two tools to be actuated by each ball size the total number of ball actuated devices may be at least doubled.

Abstract: A counter assembly including an actuatable component. A counter component is disposed with the actuatable component and initially in a first position relative the actuatable component and movable with respect to the actuatable component. A lock member is engaged in a track formed between the actuatable component and the counter component. The lock member is operatively arranged for enabling relative movement between the actuatable component and the lock member in a first direction only and between the counter component and the lock member in a second direction only. At least one iteration of travel of the counter component to a second position relative the actuatable component and back to the first position progresses the lock member incrementally along the track. The actuatable component is immovably locked to the counter component by the lock member when the lock member has reached an end of the track.

Abstract: A technique provides a system and methodology for treating a plurality of zones, e.g. well zones. A plurality of flow control devices is located along a tubular structure, such as a well string in a wellbore. Each flow control device or each set of flow control devices comprises a seat member having a unique profile relative to the profiles of the other flow control devices. Drop objects are designed with engagement features arranged to engage the profiles of specific flow control devices. For example, each drop object may have an engagement feature of a corresponding profile designed to engage the unique profile of a specific flow control device or of a specific set of flow control devices to enable actuation of the specific flow control device or the specific set of flow control devices once the drop object is dropped through the tubular structure.

Abstract: A downhole tool comprising a housing having at least one flow port disposed providing a communication path between the interior and exterior of the sleeve. A sleeve assembly has an expandable seat and an inner sleeve, and is moveable within the housing between a first position and a second position, wherein in the first position the sleeve assembly is radially positioned between the flow ports and the flowpath to substantially prevent fluid communication. Shearable port inserts are positioned within the flow ports, with each port insert having a shearable portion extending into the interior of the housing and engaging the sleeve assembly when the inner sleeve is in said first position.

Abstract: A plug counter including a j-slot sleeve; a helix sleeve in operable communication with the j-slot sleeve such that axial movement of the j-slot sleeve causes rotational movement of the helix sleeve; an anti-rotation sleeve disposed about the helix sleeve and having a keyway therein; and a key disposed in the keyway and responsive to movement of the helix sleeve and method.

Abstract: Apparatus and methods are provided for fracturing a well in a hydrocarbon bearing formation. The apparatus can include one or more valve sub-assemblies assembled into a tubing string inserted into an unlined well. The valve sub-assembly can include a sliding piston initially pinned in place to seal off ports that provide communication between the interior of the tubing string and a production zone of the formation. A ball can be inserted into a tubing string and moved along the tubing string by injected pressurized fracturing fluid until the ball sits on a valve seat of a valve sub-assembly coupled to the sliding piston to close off the tubing string below the valve. The force of the fluid forces the piston downwards to shear off the pins and open the ports. Fracturing fluid can then exit the ports to fracture the production zone of the formation.

Abstract: A series of sliding sleeves is actuated by a single ball that lands on a first ball seat and shifts the ball seat. The shifting of the ball seat also allows tubing pressure to communicate to a formerly atmospheric chamber on one side of a piston integrated into the back side of the sliding sleeve. The other side of the piston remains at atmospheric pressure so that the shifting of the ball seat not only releases the ball to go to the next ball seat but also puts a net force on the sliding sleeve to shift it against a travel stop to open a port to allow fracturing, even if there is cement in the annulus around the opened port.

Abstract: An apparatus and method for plugging a wellbore completion. The apparatus includes a body and a variable diameter ring. The body includes a first portion having a first diameter, and a second portion having a second diameter that is smaller than the first diameter. The variable diameter ring is disposed around the body and slidable on the first and second portions. The ring is configured to engage a flow path reduction device when located on the first portion, and to move past the flow path reduction device when located on the second portion.

Abstract: A ball drop wellhead control apparatus provides a ball controller between a frac ball drop or frac ball injector used to drop frac balls into a frac fluid stream being pumped into a subterranean well.

Abstract: An abrasive perforator tool with a bypass flow channel. The tool comprises a tubular body or housing with perforating nozzles in the sidewall. A sleeve assembly inside the central bore of the tool provides for sequential deployment of first and second sleeves. Prior to deployment of the sleeve assembly, pressurized fluid can be passed through the tool to operate other tools beneath the perforator in the bottom hole assembly. Deployment of the first sleeve diverts pressurized fluid through the nozzles for perforating. Deployment of the second sleeve redirects the pressurized flow through the outlet of the tool to resume operation of other tools below the perforator.

Abstract: A technique provides for stimulating or otherwise treating multiple intervals/zones of a well by controlling flow of treatment fluid via a plurality of flow control devices. The flow control devices are provided with internal profiles and flow through passages. Hydraulic darts are designed for selective engagement with the internal profiles of specific flow control devices, and each hydraulic dart may be moved downhole for engagement with and activation of a specific flow control device.

Abstract: A technique provides for stimulating or otherwise treating multiple intervals/zones of a well by controlling flow of treatment fluid via a plurality of flow control devices. The flow control devices are provided with internal profiles and flow through passages. Mechanical darts are designed for engagement with the internal profiles of specific flow control devices, and each mechanical dart may be moved downhole for engagement with and activation of the specific flow control device associated with that mechanical dart.

Abstract: A receptacle sub that increases the venting flowrate during retrieval of a running tool is disclosed. The sub includes a sleeve with a bypass port in a central bore defined by a tubular body. The sleeve is selectively moveable from an upper position to a lower position. A seal on the sleeve seals the sleeve to the bore while a retainer holds the sleeve in the upper position. A bypass passage in the body is in fluid communication with the bypass port. A drop member lands on the sleeve, blocking downward flow through the sleeve and actuating a hydraulic function. The drop member receives a fluid pressure greater than the hydraulic function fluid pressure, releasing the retainer to move the sleeve to the lower position. This allows fluid communication from above the central bore through the bypass passage and through the bypass ports of the sleeve below the drop member.

Abstract: A method and apparatus for releasing a coiled tubing internal line from a bottom hole assembly. The internal line may not have strength sufficient to permit the application of a tension force at the surface to disconnect the internal line from the bottom hole assembly. The bottom hole assembly may include a ball seat adapted to retain a ball permitting the application of a pressure differential above and below the ball seat. An anchor assembly connected to the internal line may be adapted to disconnect from the bottom hole assembly upon the application of predetermined pressure differential. A predetermined pressure differential may be used to shear a portion of the internal line releasing an upper portion of the internal line from the bottom hole assembly.

Abstract: A method and apparatus for releasing a coiled tubing internal line from a bottom hole assembly. The internal line may not have strength sufficient to permit the application of a tension force at the surface to disconnect the internal line from the bottom hole assembly. The bottom hole assembly may include a ball seat adapted to retain a ball permitting the application of a pressure differential above and below the ball seat. An anchor assembly connected to the internal line may be adapted to disconnect from the bottom hole assembly upon the application of predetermined pressure differential. A predetermined pressure differential may be used to shear a portion of the internal line releasing an upper portion of the internal line from the bottom hole assembly.

Abstract: A technique provides a system and methodology for treating a plurality of zones, e.g. well zones. A plurality of flow control devices is located along a tubular structure, such as a well string in a wellbore. Each flow control device comprises a seat member with an annularly located recess having a unique profile relative to the annularly located recesses of the other flow control devices. Darts are designed with engagement features sized to correspond with selected annularly located recesses. Each dart may have an engagement feature of a specific length designed to engage the corresponding recess of a specific flow control device to enable actuation of that flow control device once the dart is dropped through the tubular structure.

Abstract: In general, module is lowered to a position in a well to communicate with completion equipment in the well for performing a check of a downhole condition. According to a result of the check, the module is used to actuate a component of the completion equipment. In further examples, a string is lowered into the well, where the string has a first coupler portion and a contraction joint. The contraction joint is used to align the first coupler portion on the string with a second coupler portion that is part of completion equipment in the well.

Abstract: The present invention generally relates to a valve assembly for use with a velocity string. The valve assembly is used during the snub-in operation and the snub-out operation of the velocity string. In one aspect, a valve for a velocity string is provided. The valve includes a body having a bore. The valve further includes a flapper member disposed in the body, wherein the flapper member includes a flapper that is movable between an opened position in which fluid flow is allowed to move through the bore in a first direction and a second direction, and a closed position in which fluid flow through the bore is blocked in the second direction. The valve further includes a sleeve member attached to the body by a releasable connection, wherein the sleeve member is configured to hold the flapper member in the opened position. The sleeve member is movable through the bore of the body upon release of the releasable connection.

Abstract: A tubing conveyed tool for use in perforating a well bore utilizing abrasive perforating techniques. The perforating tool is particularly useful in non-vertical wells. The perforating tool is designed to permit running and setting a bridge plug, and then perforating the well bore without requiring the removal of the tool string. An eccentric weight bar can also be used to allow for directional perforating in non-vertical wells. The eccentric weight bar uses gravity to cause the bar to rotate to a predetermined position.

Abstract: A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in a pressure tight condition and later is needed to be in an open-port condition.

Abstract: A tubular actuating system includes, a tubular, a plurality of same plugs runnable within the tubular, and an alterable actuator disposed at the tubular. The actuator is alterable in response to passage of a first of the plurality of same plugs run into contact therewith. A second of the plurality of same plugs is seatingly engagable with the alterable actuator run thereagainst when in an altered condition such that pressure built up against the second of the plurality of same plugs causes actuational movement of the alterable actuator. A flapper seat is movably disposed at the alterable actuator between at least a first position defined by the alterable actuator in an unaltered position and a second position defined by the alterable actuator in an altered position.

Abstract: A hydraulically-actuated propellant stimulation downhole tool for hydrocarbon wells. According to one embodiment of the invention, the tool comprises a first section having an internal sidewall defining at least a portion of a flowpath, and a ported outer sidewall. A propellant volume having at least a portion within said first section. An annular portion has at least one pressure chamber having an end positioned adjacent to the propellant volume and an inlet providing a communication path to said flowpath. A detonator assembly is located within each pressure chamber proximal to the propellant volume such that detonation of the assembly causes detonation of the propellant volume. A firing pin is propelled toward the detonation assembly by providing communication between the pressure chamber and the flow path, causing a pressure differential between the pressure isolated ends of the firing pin.

Abstract: A system of sliding valves wherein the inserts of multiple sliding valves may be shifted to an open position using a single shifting ball. Each individual sliding valve has a movable insert that, depending upon the position of the insert within the sliding valve, may either block, permit fluid to radially flow between the interior and exterior of the sliding valve at a first rate, or permit fluid to radially flow between the interior and exterior of the sliding valve at some different second rate.

Abstract: A system for use in borehole completion is provided and includes a perforating sub, a firing sub having a first port and an interior and including a firing assembly disposable within the interior and operably coupled to the perforating sub and a drilling fluid barrier, which is formed with a second port and is displaceable toward a position at which the first and second ports align to form a fluid path through the interior that is sufficiently pressurizable to actuate the firing assembly, a drop plug selectively engageable with the drilling fluid barrier to enable displacement thereof to the position in response to applied pressures and an isolation sub, into which the drop plug is receivable following disengagement thereof from the drilling fluid barrier.

Abstract: A pluggable seat includes, a first portion, positionable within a tubular, that is receptive to a runnable member seatable thereagainst, a second portion positioned downstream of the first portion, having a radial dimension smaller than a smallest radial dimension of the first portion, and a profile disposed at the second portion configured to increase resistance to extrusion of a runnable member past the pluggable seat in comparison to the same pluggable seat without the profile.

Abstract: A selective downhole tool including a tubular having a longitudinal bore enabling passage of fluids there through. Having a valve opening in a wall of the tubular. An expandable ball seat selectively movable between a first size sized to trap a ball to block flow through the tubular. A larger second size sized to release the ball through the tubular. A valve cover longitudinally movable within the tubular, the valve cover including a dissolvable insert. Also included is a method of operating a downhole tool.

Abstract: A plug counter includes a seat receptive of a plug in a first position and capable of passing the plug in a second position. A first sleeve is in operable communication with the seat and is longitudinally movable in response to movement of the seat between the first position and the second position. A second sleeve is in operable communication with at least one of the first sleeve and the seat and is configured to index upon passage of the plug. A key is in operable communication with the seat and is configured to prevent movement of the seat to the second position after a selected number of plugs have passed the seat. A third sleeve is in operable communication with the first sleeve, and a release member is in operable communication with the third sleeve and is configured to move the third sleeve after it is released.