Abstract: A plugging device launcher for use with a subterranean well can include a release mechanism. The release mechanism can include an actuator operative to displace at least one elongated member. The elongated member is engaged with at least one plugging device. A method of releasing plugging devices into a subterranean well can include placing a plugging device launcher in communication with a wellbore of the well, and operating an actuator of the plugging device launcher, thereby displacing at least one elongated member of the plugging device launcher. The displacing step can include disengaging the elongated member from at least one of the plugging devices.

Abstract: A non-return valve (19) for a water supply system (1) or a pump (4) is integrated in a flow channel (14) of the water supply system (1). The non-return valve (19) includes a sealing body (21) which is mounted within the channel (14), blocks the channel (14) in a first position forming the closure position and releases the channel (14) in a second position forming the opened position. The sealing body (21) is movably arranged on a holder (31) which includes a closure body (15), with which the holder (31) is releasably fastened in a housing opening.

Abstract: Yieldable object landing feature including a first object landing region configured to receive and support a first size object, a second object landing region configured to receive and support a second size object, and a stress riser disposed to initiate crack formation in the second object landing region.

Abstract: The present disclosure relates to multiple stage operations, and more particularly to systems and methods for performing second stage cementing operations with a stage tool. A stage tool comprises: a mandrel; an opening seat; a closing seat; a plurality of ports; a closing sleeve; and a packer element, wherein the opening seat is attached to an interior surface of the mandrel, wherein the closing seat is attached to the interior surface of the mandrel, wherein the plurality of ports is configured to allow fluid communication between the interior surface of the mandrel and an exterior surface of the mandrel, wherein the closing sleeve is disposed on the exterior surface of the mandrel and coupled to the closing seat, wherein the packer element is disposed on the exterior surface of the mandrel.

Abstract: Embodiments disclosed herein describe fracturing methods and systems, wherein pressure differentials and fluid flow rates may be utilized to stimulate multiple zones, sleeves, or ports with the same tool.

Abstract: A quick coupling assembly includes a first coupling element (10) and a second coupling element (50) that is inserted into the first coupling element. The first coupling element has a coupling body (12) and a valve (20), which define a volume displacement passage. When the second coupling element (50) is inserted, the second coupling element mechanically acts on the valve (20) to expel contaminants from the quick coupling assembly via the volume displacement passage. The valve includes a poppet (22) and a biasing spring (24), and the volume displacement passage includes a leak path (66) defined between the coupling body and the poppet. The poppet has an inward contour (68) that is spaced apart from the coupling body to define the leak path. The poppet has a widened portion (70) that provides a sealing surface when the assembly is fully coupled. The second coupling element (50) mechanically acts on the poppet (22) during insertion to expel the contaminants via the volume displacement passage.

Abstract: A plug insert for use in a frac plug tool comprising a plug top, a plug body and an elastomeric O-ring, The plug top is shaped to rest on a seat of an upper end of a mandrel of the frac plug tool and the plug body is shaped to fit in a flow passage of the mandrel wherein the plug body includes a shear pin opening. The elastomeric O-ring is locatable around a portion of the plug body and sized to block fluid flow through the flow passage of the mandrel when the plug body is located in the flow passage. A frac plug tool for use in a well comprising the plug insert and a shear pin to hold that insert above the mandrel seat of the tool and method of assembling the tool are also disclosed.

Abstract: A system includes a drill bit, and a tubular connected thereto. The tubular is configured to be rotated to rotate the drill bit and drill a length of a borehole and cemented in place. The tubular and the drill bit form a conduit to permit cement to be pumped through the tubular and the drill bit and into an annulus. The system also includes a collar disposed between the tubular and the drill bit. The collar includes a receptacle made from a drillable material, which has a profile that corresponds to a shape of a component deployed through the length of the tubular, and is configured to form a substantially fluid tight seal between the component and the drillable material when the component is seated in the receptacle. The collar and the component prevent backflow of the cement.

Abstract: A flow transported obturating tool for actuating a valve in a wellbore includes a housing including a radially translatable engagement assembly, and a core slidably disposed in the housing, wherein the engagement assembly is configured to shift the valve from a first closed position to an open position when the core is in a first position relative to the housing, and wherein the engagement assembly is configured to shift the valve from the open position to a second closed position in response to the core being displaced from the first position to a second position that is spaced from the first position in a first axial direction.

Abstract: The present invention relates to a downhole well tubular structure configured to be arranged in a borehole in a formation, comprising a well tubular part having an opening and an inner face, the well tubular part having an axial extension, a first sleeve configured to slide within the well tubular part along at least part of the inner face, the first sleeve having a first end face and a second end face, the first sleeve having a first sleeve groove facing away from the well tubular part, the first sleeve groove of the first sleeve having a first groove face extending radially and facing away from the first end face, and the first sleeve groove of the first sleeve having a second groove face inclining away from the first groove face, wherein the well tubular part has a first inclined face facing the first end face of the first sleeve, the first inclined face inclining from the inner face away from the first sleeve, wherein the well tubular part comprises a second inclined face facing the first inclined face, t

Abstract: A liner and bridge plug are installed in a hydrocarbon well that has a casing and a section to be lined by the liner. The liner and bridge plug are installed by providing a tubing string that carries a bridge plug and a liner setting tool, the liner setting tool carrying a liner, inserting the tubing string into the hydrocarbon well until the liner is at a desired location along the casing, activating the liner setting tool to install the liner, activating the bridge plug to seal the wellbore and disengaging the tubing string from the bridge plug and the liner.

Abstract: Apparatuses, systems and methods for plugging a well bore. A plug formation apparatus includes a plug support tool having a substantially cylindrical and hollow body having one or more ports for fluid communication between an interior of the plug formation apparatus and an annulus of a well bore, a base extending radially around an outer surface of the body, and an elastically deformable member extending radially around an outer surface of the body beyond the base and supported by the base; a top-of-cement bypass sub having one or more ports, actuatable between a closed position and an open position; a detachment member coupled with the top-of-cement bypass sub; and a length of tubing fluidically coupled with an upper portion of the plug support tool and a lower portion of the top-of cement bypass sub.

Abstract: A method includes pumping cement to a bore of a shifting sleeve disposed in a ported component seated in a cased bore above a liner; flowing the cement from the bore of the shifting sleeve through radial passages of the shifting sleeve and radial passages of the ported component; and flowing the cement to an annulus between a casing of the cased bore and the liner.

Abstract: Embodiments of a bottomhole assembly (BHA) for completion of a wellbore are deployed on electrically-enabled coiled tubing (CT) and permit components of the BHA to be independently electrically actuated from surface for completion of multiple zones in a single trip using a single BHA having at least two electrically-actuated variable diameter packers. One or both of the packers may be actuated to expand or retract for opening and closing off a variety of flowpaths between the BHA and the wellbore, in new wellbores, old wellbores, cased wellbores, wellbores with sleeves and in openhole wellbores. Additional components in the BHA, which may also be electrically—actuated or powered, permit perforating, locating of the BHA in the wellbore such as using casing collar locators and microseismic monitoring in real time or in memory mode.

Abstract: A diverter assembly includes a tubing segment and one or more sleeve members disposed therein. The tubing segment includes apertures that are selectively alignable with apertures of an inner sleeve disposed within the tubing segment. The tubing segment includes a series of stops (e.g., shear pins) to arrest movement of the first sleeve within the bore of the tubing segment. A first one or more ball seats are included in the first sleeve such that deployment of a first ball and pressurization of the well above the first ball causes a first set of shear pins to fail, thereby allowing the first sleeve to slide downhole to cause apertures of the sleeve to align with apertures of the tubing segment, thereby causing fluid to flow to an annulus between the tubing segment and wellbore wall.

Abstract: A valve collar for a downhole packer includes a flow path. The flow path includes an opening valve and closing valve. The valve collar further includes a lockout valve piston. The lockout valve piston is positioned such that in an unset position, the flow path is open and in a set position, the flow path is blocked by the lockout valve piston. The lockout valve piston may be adapted to be shifted from the unset position to the set position by a pressure spike inside the valve collar. The lockout valve piston may be held in the unset position by a temporary restraint.

Abstract: Methods, systems, and devices for sealing stage tool leaks are disclosed. In one aspect a stage tool for wellbore cementing comprises an external stage tool body and a sliding sleeve within the external stage tool body configured to regulate cement flow through the stage tool. At least a portion of the sliding sleeve comprises a meltable alloy configured to seal a leak. The meltable alloy is configured to be melted by a heating source, flow into the leak, and resolidify as the melted alloy cools, thereby sealing the leak.

Abstract: A non-return valve (19) for a water supply system (1) or a pump (4) is integrated in a flow channel (14) of the water supply system (1). The non-return valve (19) includes a sealing body (21) which is mounted within the channel (14), blocks the channel (14) in a first position forming the closure position and releases the channel (14) in a second position forming the opened position. The sealing body (21) is movably arranged on a holder (31) which includes a closure body (15), with which the holder (31) is releasably fastened in a housing opening.

Abstract: A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

Abstract: The inflatable sleeve (13) comprises: a mandrel (15) extending in a longitudinal direction; an inflatable casing (17) placed around the mandrel (15); a tubular sheath (19) slid around the casing (17), the tubular sheath (19) having a central segment (27) and first and second longitudinal ends (23, 25) situated on either side of the central segment (27), the first and/or second ends (23, 25) of the tubular sheath (19) being fixed to the mandrel (15), the tubular sheath (19) being extensible from a rest state to an expanded state. The tubular sheath (19) has a predetermined circumferential elongation capacity from the rest state of the tubular sheath (19); and the first and/or second ends (23, 25) of the tubular sheath (19) have a longitudinal elongation capacity from the rest state of the tubular sheath (19) comprised between 1.05 and 2.5, chosen to limit the diametric expansion of the first and/or second ends (23, 25) of the tubular sheath and give the first and/or second ends their shape (23, 25).

Abstract: The present invention relates to a downhole flow control device for controlling a flow of a fluid from a borehole into a well tubular structure and/or from the well tubular structure into the borehole, comprising a base tubular having an axial axis and adapted to be mounted as part of the well tubular structure, the base tubular having a first opening, a first sleeve arranged within the base tubular, the first sleeve having a first sleeve part and a second sleeve part with a second opening, and the first sleeve being adapted to slide along the axial axis for at least partly aligning the first opening with the second opening, wherein a second sleeve is arranged at least partly between the second sleeve part and the base tubular, and an engagement element is arranged for engaging an indentation of the second sleeve part in a first position and for disengaging the indentation of the second sleeve part in a second position. Furthermore the present invention relates to a downhole system.

Abstract: A subsurface release plug system includes a plug mandrel body and a plug. The plug mandrel body includes a bore, a flow port fluidly connected to the bore, and a sleeve adjustable from a first position to a second position. The sleeve prevents fluid flow through the flow port when in the first position and allows fluid flow through the flow port when in the second position. The plug is releasably connected to the plug mandrel body, wherein the plug is configured to be released from the plug mandrel body by fluid flowing through the flow port.

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: An apparatus for introducing a drop ball into a well is provided. In one embodiment, the apparatus includes a wellhead assembly mounted over a well and a ball launcher for routing a drop ball into the wellhead assembly. The ball launcher includes a fluid conduit coupled to the wellhead assembly and a pilot ball disposed in the fluid conduit. The ball launcher also includes a stop positioned in the fluid conduit to prevent movement of the pilot ball past the stop while allowing movement of the drop ball past the stop and into the wellhead assembly. Additional systems, devices, and methods are also disclosed.

Abstract: Embodiments of a bottomhole assembly (BHA) for completion of a wellbore are deployed on electrically-enabled coiled tubing (CT) and permit components of the BHA to be independently electrically actuated from surface for completion of multiple zones in a single trip using a single BHA having at least two electrically-actuated variable diameter packers. One or both of the packers may be actuated to expand or retract for opening and closing off a variety of flowpaths between the BHA and the wellbore, in new wellbores, old wellbores, cased wellbores, wellbores with sleeves and in openhole wellbores. Additional components in the BHA, which may also be electrically-actuated or powered, permit perforating, locating of the BHA in the wellbore such as using casing collar locators and microseismic monitoring in real time or in memory mode.

Abstract: A method of actuating one or more isolation valves in a well can include conveying a tubular string into the well, the tubular string including a shifting tool, inserting the shifting tool into an isolation valve, thereby opening the isolation valve, and withdrawing the shifting tool from the isolation valve, the isolation valve remaining open after the withdrawing. A completion system for use in a well can include multiple isolation valves, and a shifting tool which opens one isolation valve, allowing full bore inner diameter and not restricting flow, and closes another isolation valve. A shifting tool for actuating multiple isolation valves in a well can include multiple shifting profiles, whereby one shifting profile opens an isolation valve, and another shifting profile closes another isolation valve.

Abstract: A balanced piston toe sleeve allows a pressure test cycle to be carried out before opening the bore of the toe sleeve to the wellbore. The balanced piston toe sleeve includes a valve assembly in which a valve piston separates a valve cylinder into a balancing cylinder and an actuation cylinder. The actuation cylinder is coupled to the bore through a check valve which allows unidirectional flow into the actuation cylinder. The balancing cylinder is in fluid communication with the bore. After a pressure test cycle, the pressure in the balancing cylinder reduces, while the pressure in the actuation cylinder is retained by the check valve. The valve piston shifts into the open position, allowing fluid flow from the bore to the toe sleeve.

Abstract: A drill string apparatus includes an upper casing section having a port collar. The port collar provides a controllable opening from an interior of the upper casing section to an annulus around the upper casing section. A lower casing section is coupled to the upper casing section through a swivel. The lower casing section includes an external casing packer and a casing pad coupled to an external portion of the lower casing section. The external casing packer is expandable to an annulus around the lower casing section before a cement operation to avoid cement loss circulation to weak formation below the packer.

Abstract: In some aspects, a downhole assembly is provided that can include a window joint positioned within a tubular element and a bypass restrictor. The bypass restrictor can be positioned in an annulus between an outer surface of the window joint and an inner surface of the tubular element. The bypass restrictor can restrict the flow of a pressurized fluid via the annulus from a first end to a second end of a wiper plug.

Abstract: A secondary cementing apparatus includes a drill string, a coupling coupled to a distal end of the drill string, and a tool coupled to a distal end of the coupling, the tool having a distal portion offset from a central axis of the drill string, and the coupling configured to allow selective rotation of the tool with respect to the drill string. A method for plugging a hole includes rotating a drill string about a central axis of the drill string, wherein a distal end of the drill string is coupled to a tool, the tool having an offset distal portion from a central axis of the drill string; and flowing a fluid down the drill string and out of the offset distal portion of the tool as the drill string is rotated.

Abstract: Flow control assemblies comprise a housing that includes a housing body that defines a housing conduit, an injection conduit that extends through the housing body, and a ball sealer seat. The ball sealer seat defines a portion of the injection conduit, is defined on an inner surface of the housing, and is sized to receive a ball sealer to restrict fluid flow from the casing conduit through the injection conduit. The flow control assemblies further include a sliding sleeve that is located within the housing conduit and defines an isolation ball seat. The flow control assemblies also include a retention structure that is configured to retain the sliding sleeve in a first configuration and to selectively permit the sliding sleeve to transition from the first configuration to a second configuration.

Abstract: A toe circulation sub for a wellbore liner, the toe circulation sub comprising: a body including a connection for connecting the body to a wellbore liner to define an inner facing portion open to an inner diameter of the liner and an outer facing portion open to an outer surface of the liner; a bore through the body from the inner facing portion to the outer facing portion; and, a ball seat in the bore formed to stop and seal with a ball to plug flow through the bore to close the toe circulation sub. The toe circulation sub is useful for methods and may be installed in a wellbore liner.

Abstract: A downhole tool, multi-stage cementing tool, and method for cementing. The tool includes a body having a bore axially therethrough and an opening radially therethrough, and a first sleeve positioned in the bore of the body. The first sleeve has an opening radially therethrough that is axially aligned with the opening of the body when the downhole tool is in a first configuration. An inner surface of the first sleeve defines a first seat. The tool also includes a second sleeve positioned in the first sleeve, with the second sleeve being aligned with the opening of the first sleeve and preventing fluid flow therethrough when the tool is in the first configuration. The second sleeve is configured to move axially and engage the first seat of the first sleeve when the tool is in a second configuration, so as to resist relative rotation between the first and second sleeves.

Abstract: A sliding sleeve opens with a deployed ball. The sleeve has a seat disposed in the housing, and the seat has segments biased outward from one another with a C-ring or other biasing element. Initially, the seat has an expanded state in the sliding sleeve so that the seats segments expand outward against the housing's bore. When an appropriately sized ball is deployed downhole, the ball engages the expanded seat. Fluid pressure applied against the seated ball moves the seat into the inner sleeve's bore. As this occurs, the seat contracts, which increases the engagement area of the seat with the ball. Eventually, the seat reaches the shoulder in the inner sleeve so that pressure applied against the seated ball now moves the inner sleeve in the housing to open the sliding sleeve's flow port.

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 sliding sleeve opens with a deployed ball. The sleeve has a seat disposed in the housing, and the seat has segments biased outward from one another with a C-ring or other biasing element. Initially, the seat has an expanded state in the sliding sleeve so that the seats segments expand outward against the housing's bore. When an appropriately sized ball is deployed downhole, the ball engages the expanded seat. Fluid pressure applied against the seated ball moves the seat into the inner sleeve's bore. As this occurs, the seat contracts, which increases the engagement area of the seat with the ball. Eventually, the seat reaches the shoulder in the inner sleeve so that pressure applied against the seated ball now moves the inner sleeve in the housing to open the sliding sleeve's flow port.

Abstract: The present invention provides wellbore pressure control system and method for well cementation stages, and relates to the offshore oil and gas exploitation field. The wellbore pressure control system comprises: an injection pump; and a control device, configured to control the injection pump to inject a fluid or gas through an injection pipeline to a return pipeline that communicates with an annular space of the wellbore to decrease the pressure in the return pipeline and thereby decrease the pressure in the annular space, wherein, the density of the fluid or gas is lower than the density of a drilling fluid in the annular space. The technical scheme of the present invention can effectively prevent leaky zones from being fractured by high-density cement slurry in the well cementation process that may cause safety accidents such as well kick and well blowout, etc.

Abstract: A sliding sleeve opens with a deployed ball. The sleeve has a seat disposed in the housing, and the seat has segments biased outward from one another with a C-ring or other biasing element. Initially, the seat has an expanded state in the sliding sleeve so that the seats segments expand outward against the housing's bore. When an appropriately sized ball is deployed downhole, the ball engages the expanded seat. Fluid pressure applied against the seated ball moves the seat into the inner sleeve's bore. As this occurs, the seat contracts, which increases the engagement area of the seat with the ball. Eventually, the seat reaches the shoulder in the inner sleeve so that pressure applied against the seated ball now moves the inner sleeve in the housing to open the sliding sleeve's flow port.

Abstract: In accordance with one aspect of the disclosure a system includes a plug launching assembly, including a housing. The system also includes a first flow assembly of the plug launching assembly including a first primary flow path configured to direct a fluid flow into a wellbore. Moreover, the first flow assembly is configured to transition from a first position to a second position within the plug launching assembly. Also, the first flow assembly is releasably coupled to the housing while in the first position. The system further includes a second flow assembly of the plug launching assembly coupled to the housing and positioned downstream of the first flow assembly. The first flow assembly engages the second flow assembly while the first flow assembly is in the second position. The system also includes a cement plug releasably coupled to the second flow assembly.

Abstract: A downhole flow control apparatus comprising: at least one tubular body (1) locatable at a zone of a well, the tubular body (1) having a longitudinal through bore and one or more transverse ports (5a, 5b) and a port covering device (3) which, in use, is movable from a lower position in which the or each port is covered to an upper position in which the or each port is open; and at least one plugging device (6) which is operable to travel downhole from the surface to locate within and seal the through bore of the tubular body, the plugging device including moving means (10) to cause the port covering device (3) to move from the lower position to the upper position thus allowing fluid communication between the through bore and the or each port (5a, 5b).

Abstract: A sliding sleeve opens with a deployed ball. The sleeve has a seat disposed in the housing, and the seat has segments biased outward from one another with a C-ring or other biasing element. Initially, the seat has an expanded state in the sliding sleeve so that the seats segments expand outward against the housing's bore. When an appropriately sized ball is deployed downhole, the ball engages the expanded seat. Fluid pressure applied against the seated ball moves the seat into the inner sleeve's bore. As this occurs, the seat contracts, which increases the engagement area of the seat with the ball. Eventually, the seat reaches the shoulder in the inner sleeve so that pressure applied against the seated ball now moves the inner sleeve in the housing to open the sliding sleeve's flow port.

Abstract: In a drill string for oil wells and the like a method and apparatus for delivering fluids to the drilled hole employs a bypass port above fluid outlets in the distal end of the string. The port may be used to deliver fluid such as lost circulation material (LCM) to the drilled hole from the surface. A volume of the fluid may be locked in the string between the port and the fluid outlets such that fluid is prevented from passing from the hole into the string via the fluid outlets.

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: One disclosed sleeve assembly disposed within a base pipe includes a first sleeve portion having a first shear resistance for resisting movement of the sleeve assembly with respect to the base pipe, and a second sleeve portion moveable with respect the first sleeve portion and having a second shear resistance for resisting movement of the second sleeve portion with respect to the first sleeve portion, the second shear resistance being greater than the first shear resistance.

Abstract: A secondary cementing apparatus includes a drill string, a coupling coupled to a distal end of the drill string, and a tool coupled to a distal end of the coupling, the tool having a distal portion offset from a central axis of the drill string, and the coupling configured to allow selective rotation of the tool with respect to the drill string. A method for plugging a hole includes rotating a drill string about a central axis of the drill string, wherein a distal end of the drill string is coupled to a tool, the tool having an offset distal portion from a central axis of the drill string; and flowing a fluid down the drill string and out of the offset distal portion of the tool as the drill string is rotated.

Abstract: Zone isolation is a leading concern for operators that wish to fluidly treat a well. Typically in an open hole packers hydraulically actuated solid body packers have been are deployed at particular intervals along the wellbore to provide zonal isolation of various formations or portions of a formation. By isolating the various zones valves may be selectively opened or closed to treat a particular zone independently of the remainder of the well. In an improvement over the past procedures a cup style packer that is particularly useful in open hole may now be used.

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: 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: Systems and methods for remotely setting a downhole device. The system includes a base pipe having inner and outer radial surfaces and defining one or more pressure ports extending between the inner and outer radial surfaces. An internal sleeve is arranged against the inner radial surface and slidable between a closed position, where the internal sleeve covers the one or more pressure ports, and an open position, where the one or more pressure ports are exposed to an interior of the base pipe. A trigger housing is disposed about the base pipe and defines an atmospheric chamber in fluid communication with the one or more pressure ports. A piston port cover is disposed within the atmospheric chamber and moveable between blocking and exposed positions. A wellbore device is used to engage and move the internal sleeve into the open position by applying predetermined axial force to the internal sleeve.

Abstract: The present disclosure provides techniques for a self-extendable hydraulic wellbore cleaning tool. The cleaning tool includes one or more extending nozzles which eject cleaning fluid onto the walls of a wellbore with increased impact momentum due to the shorter range. The extending nozzles can extend from the cleaning tool to a distance away from the cleaning tool, bringing the point of ejection closed to the walls of the wellbore. In certain example embodiments, the cleaning tool also includes one or more flow guides which direct the flow of cleaning fluid ejected from the nozzles. The flow guides cause the cleaning fluid to rotate when ejected from the nozzles, and causes the cleaning fluid to impact the walls of the wellbore at an angle.