Abstract: An adaptive fluid switch for regulating the production rate of a fluid. The adaptive fluid switch includes a fluid control valve having a fluid selector, a swirl chamber and a self-impinging valve element. When the fluid produced through the adaptive fluid switch has a viscosity greater than a first predetermined level, the fluid selector determines the fluid to be a selected fluid such that the fluid swirls in one direction in the swirl chamber and follows a low resistance flow path in the valve element. When the fluid has a viscosity less than a second predetermined level, the fluid selector determines the fluid to be a non-selected fluid such that the fluid swirls in the opposite direction in the swirl chamber and follows a high resistance flow path in the valve element, thereby regulating the production rate of the fluid responsive to changes in the viscosity of the fluid.

Abstract: An adaptive fluid switch for regulating the production rate of a fluid. The adaptive fluid switch includes a fluid control module having a fluid selector, a swirl chamber and a self-impinging valve element. When the fluid produced through the adaptive fluid switch has a viscosity greater than a first predetermined level, the fluid selector determines the fluid to be a selected fluid such that the fluid swirls in one direction in the swirl chamber and follows a low resistance flow path in the valve element. When the fluid has a viscosity less than a second predetermined level, the fluid selector determines the fluid to be a non-selected fluid such that the fluid swirls in the opposite direction in the swirl chamber and follows a high resistance flow path in the valve element, thereby regulating the production rate of the fluid responsive to changes in the viscosity of the fluid.

Abstract: A downhole valve has a valve body having at least one port and slidably receiving in a longitudinal bore thereof at least a first sliding sleeve for opening and closing the at least one port. The first sliding sleeve has a circumferential actuation groove. An actuation assembly is extendable into the first sliding sleeve and has an actuation housing axially movably receiving thereon a compressible sealing element and a slip assembly. The slip assembly has one or more slips radially outwardly extendable under a hydraulic pressure for engaging the circumferential actuation groove of the first sliding sleeve for opening the at least one port, and the actuation assembly is longitudinally extendable to position a portion thereof on an inner side of the one or more slips for supporting the one or more slips at a radially outwardly extended configuration.

Abstract: A sliding sleeve apparatus that has a flow inhibitor that slows the fluid flow between the interior passageway of the sliding sleeve and the well annulus to allow pressure equalization between the interior passageway of the sliding sleeve and the well annulus to occur prior to placing the sliding sleeve in a fully open position. The inhibited or restricted fluid flow reduces wear on the seals and other components of the sliding sleeve, which extends the operative life of the tool.

Abstract: The disclosure is directed to top caps for gear rod rotators and polished clamps. Disclosed top caps include an elongated top cap body extending along a central vertical axis, the top cap body including a top face, a bottom face, and an exterior perimeter surface defining an outer perimeter of the top cap body, and a polished rod opening extending along the central vertical axis of the top cap body, the polished rod opening defining an interior circumferential surface of the top cap body and configured to receive a polished rod. Additionally, disclosed top caps include a nesting region along the top face, the nesting region configured to receive at least a portion of the polished rod clamp, and a mounting rim on the bottom face and extending outwardly from the bottom face along a longitudinal axis of the top cap body, the mounting rim including a mounting rim outer diameter, a mounting rim inner diameter, and a mounting rim bottom face.

Abstract: A drilling well pulling tool comprising a longitudinal body having an inner cavity. A sleeve is slideably disposed about a portion of the longitudinal body, the sleeve moveable from a first position to a second position. A dog member is retractable from an extended position to a retracted position relative the body when the sleeve is moved from the first position to the second position. A release lug abuts and resists movement of the sleeve from the first position, the lug releasable to the inner cavity thereby permitting slideable movement of the sleeve. An electromechanical actuator releases the release lug upon actuation.

Abstract: A high speed, fail-safe device for an electric actuator that can be independently triggered in the event of an emergency shutdown is provided. An electromagnetic brake is attached to the roller nut of the screw actuator. When actuated, the brake prevents rotation of the roller nut, and therefore enables linear movement of the roller nut upon rotation of the lead screw to linearly move an output shaft to actuate the valve. During actuation a return spring is compressed to enable retraction of the output shaft upon system failure. During such failure, the electric break is de-energized, which allows the roller nut to rotate and linearly move under force of the return spring to retract the output shaft to its fail-safe condition. A soft-stop/over-travel system is provided to limit the impact loads on the lead screw.

Abstract: A control system for generating and utilizing at least one or more addressed datagrams that communicate information to and from devices along piping assemblies comprising; one or more transmitters, one or more receivers, and one or more controllers and/or transponders wherein the transmitters transmit information via one or more addressed datagrams encoded within a fluid medium to one or more receivers among the piping assemblies, is described. Transmitters or transponders convert datagrams into signals that are transmitted within the fluid medium and the receivers receive signals from the transmitters and also convert signals from the fluid medium which is converted back into datagrams. The controllers receive and decode the datagrams so that the controllers selectively communicate and perform logical operations on piping assembly devices according to directions received from the addressed datagrams.

Abstract: A downhole communication and control system configured for use in a non-sequential order of treating a borehole, the system includes a string having at least three ports including first, second, and third longitudinally spaced ports arranged sequentially in a downhole to uphole manner in the string; at least three frac sleeve systems including first, second, and third frac sleeve systems arranged sequentially in a downhole to uphole manner in the string and arranged to open and close the first, second, and third ports, respectively, each frac sleeve system having self-powered, electronically triggered first and second sleeves; and, communication signals to trigger the first, second, and third frac sleeve systems into moving the first and second sleeves to open and close the ports. Also included is a method of completing downhole operations in a non-sequential order.

Abstract: A method for activating a shifting tool comprises introducing a shifting tool in a desired wellbore zone where it is exposed to a pre-determined hydrostatic pressure. The shifting tool comprises at least one key that is configured to be expanded and released from a retracted position when the shifting tool is subjected to the pre-determined hydrostatic pressure.

Abstract: A device for opening or closing a fluid flow path comprises: a fluid inlet, wherein the fluid inlet comprises one end of the fluid flow path; an inlet covering, wherein the inlet covering is adjacent to the fluid inlet; and a material, wherein the material is capable of expanding or contracting via a change in temperature; wherein the expansion or contraction of the material causes movement to the inlet covering, and wherein the movement of the inlet covering either opens or closes the fluid flow path. A method for opening or closing a fluid flow path using the device comprises: allowing or causing a change in temperature to the material.

Abstract: Injection of gas into a managed pressure drilling system to provide for operation of the drilling system in a pressure window defined by the pore pressure of a formation being drilled and a fracture pressure of the formation. The gas is injected through gas injection ports and drilling fluids are allowed to flow between the drilling annulus and the gas injection system though a plurality of flow ports that are disposed vertically below the gas injection ports in the borehole being drilled. The gas injection ports and the flow ports are configured so that when gas is flowing through the gas injection ports, the flow ports are sealed.

Abstract: An apparatus for isolating a first zone from a second zone in a subterranean wellbore. The apparatus includes an outer tubular and an inner tubular disposed within the outer tubular forming an annular flow path therebetween that is in fluid communication with the first zone. The inner tubular defines a central flow path that is in fluid communication with the second zone. A sleeve having at least one seal is positioned in the annular flow path and is axially movable relative to the inner and outer tubulars between a closed position wherein the seal engages the inner tubular and an open position wherein the seal engages the outer tubular. A mandrel is slidably disposed within the inner tubular and is coupled to the sleeve. The mandrel is operable to shift the sleeve between the open position and the closed position responsive to changes in pressure within the central flow path.

Abstract: An apparatus for fluid treatment of a borehole, the apparatus allowing initial outflow injection of fluids into a wellbore in which it is installed and then is actuable to allow fluid inflow control.

Abstract: Disclosed herein is a shut off system for a hydrocarbon recovery mandrel comprising an inline valve assembly comprising a nipple comprising a chemical flow line; the chemical flow line being operative to transfer fluids from outside the wellbore to a mandrel channel; where the mandrel channel is disposed in the mandrel; a valve assembly comprising a cylinder and a piston shaft; where the cylinder contacts the chemical flow line; where the piston shaft reciprocates in the cylinder in response to opposing applied pressures; where the piston shaft contacts a sealing object that is operative to facilitate or to prevent fluid flow from the chemical flow line to the mandrel channel; where the cylinder comprises a port that provides fluid communication from the cylinder to the mandrel channel; and an actuating assembly; where the actuating assembly is operative to displace the piston shaft in the cylinder to prevent fluid communication between the chemical flow line and the mandrel channel.

Abstract: The present disclosure is directed to a downhole bypass tool that includes an inlet for receiving fluid into a housing of the bypass tool. The bypass tool also includes a flow directing apparatus disposed in the housing for directing fluid to flow into an operational flow path of a vibratory tool. The vibratory tool is at least partially disposed within the hosing of the bypass tool. The flow directing apparatus operates selectively bypass the operational flow path of the vibratory tool such that the fluid bypasses the operational flow path of the vibratory tool and flows out of an outlet of the bypass tool.

Abstract: An apparatus and method for controlling fluid flow in a blowout preventer. In one embodiment, an apparatus for connecting fluid lines includes a socket fluid connector and a plug fluid connector. Each connector includes a flow channel. The plug fluid connector is detachably connectable to the socket fluid connector at a connection end of the plug and socket fluid connectors such that the flow channels align. Each of the socket and plug fluid connectors includes a check valve in the flow channel. The check valve is configured to prevent fluid flow through the connector flow channels while the plug and socket fluid connectors are not connected, and to enable bidirectional fluid flow through the connector flow channels while plug and socket fluid connectors are connected.

Abstract: A Bottom Hole Assembly (BHA) tool and methods of downhole fluid management are disclosed. The BHA is deployed on a conveyance string to access a completion string and forming a tool annulus therebetween. A first assembly having a first bore fluidly connected to the conveyance string. A second assembly supports an packer for releasably sealing to the completion string, and a third assembly supporting a packer actuator thereon, the second assembly telescopically movable within the third assembly for forming a resettable packer releasably sealable to the completion string. A bypass valve is formed between the first and second assembly. Closing of the bypass valve directs fluid through a treatment port uphole of the resettable packer to the tool annulus and opening of the bypass valve bypasses fluid about the resettable packer. The packer actuator can further comprise an anchor for releasably anchoring to the completion string.

Abstract: Disclosed is a secondary system and method for initiating a down hole operation in a wellbore when a primary activation system fails. The primary activation system is configured to provide fluid communication between a first chamber and a second chamber in response to a primary activation operation. The secondary activation system includes a passageway between the first chamber and the second chamber, and a rupture member positioned in the passageway. The rupture member has a threshold pressure differential at which the rupture member ruptures to afford fluid communication between the first chamber and the second chamber to thereby initiate the down hole operation if the primary activation system fails. The primary activation operation may be configured to move a trigger member to initiate the down hole operation, whereas the secondary activation operation may be configured to initiate the down hole operation without moving the trigger member.

Abstract: A back-up ring for use in a liner top test tool for testing casing integrity in a wellbore is disclosed. The back-up ring is comprised of first and second ring elements that are biased apart by a compression springs. The first ring element has a plurality of radially extending flanges that cover a plurality of channels in the second ring element when the back-up ring is compressed against a seal element on the liner top test tool to seal the wellbore casing.

Abstract: Various implementations described herein are directed to a vibration tool, e.g., for use in drilling or other downhole operations. In one implementation, the vibration tool may include a housing having a bore extending therethrough. The vibration tool may also include a piston subassembly positioned inside the bore, where the piston subassembly is configured to oscillate when fluid flow inside the piston subassembly exceeds a predetermined flow rate. The vibration tool may further include a valve mechanism positioned around the piston subassembly, where the valve mechanism is configured to restrict fluid to flow inside the piston subassembly when the valve mechanism is in a closed state and configured to allow the fluid to flow from the piston subassembly to the bore when the valve mechanism is in an open state.

Abstract: A device for controlling fluid flow from a subsurface fluid reservoir into a production tubing siring includes, a tubular member defining a central bore. At least one nozzle extends through a side wall of the tubular member. A popper is moveable between an open position where fluids can flow into the central, bore through the nozzle, and a closed position where the nozzle is fluidly sealed. A circumferential external bead profile is located, on the stem and a circumferential groove is located in the nozzle for mating with the head profile of the stem and maintaining the popper in a closed position. The device can also have a shear member disposed between the stem of the popper and an inner surface of the nozzle for supporting the popper in an open position before the popper Is moved to the closed position.

Abstract: A sliding sleeve has an associated shock absorber to limit shock loading to the shifting apparatus when the end of travel is reached. An adjacent sleeve defined an annular cavity in a manner that does not reduce the drift dimension of the shifting sleeve. The cavity has a fluid in it and the movement of the shifted sleeve causes the movement of the shock absorber sleeve to reduce the fluid volume in the annular cavity. The volume reduction forces fluid through a restriction to regulate the speed of the sliding sleeve as a travel stop is reached. The fluid can be a gas, an incompressible fluid or grease. The restriction can be temporarily covered such as with a rupture disc. Room to compensate for thermal expansion can be provided in the annular space.

Abstract: The present invention is a valve tool utilized for hydraulically fracturing multiple zones in an oil and gas well without perforating the cement casing. An oil/gas well completion method involves the use of a valve that is installed as part of the casing string of the well. A mandrel-less casing provides for cement flow within the casing when the valve element is in a closed position and allows for axial flow of fracturing fluid through the cement casing to fracture the formation near the valve when the sleeve is open. The invention disclosed herein is an improved valve used in this process.

Abstract: A wellbore servicing system including a work string and a valve tool defining an flowbore, wherein the valve tool is transitionable from a first mode to a second mode, from the second mode to a third mode, and from the third mode to a fourth mode, wherein the valve tool transitions from the first mode to the second mode upon an application of pressure to the flowbore of at least a threshold pressure, wherein the valve tool transitions from the second mode to the third mode upon a dissipation of pressure from the flowbore to not more than the threshold pressure, and wherein, in the first mode, the valve tool allows fluid communication via the flowbore in a first direction and disallows fluid communication in a second direction. Further, in the second, and third modes, the valve tool allows fluid communication in both the first and second directions.

Abstract: According to one embodiment, a recirculation safety valve is disclosed. The valve has a tubular body with mandrel that is axially shifted in response to annulus pressure. Shifting of the mandrel can either close a safety valve or close a safety valve and open a recirculation port. The valve has an annular actuation chamber that relieves that pressure to prevent inadvertent shifting of the mandrel.

Abstract: A downhole tool includes a pressure activated flow switch for selectively actuating and deactuating a device, such as a reaming block. The flow switch is deployed external to the flow bore and includes a flow piston configured to reciprocate between axially opposed open and closed positions such that the device is actuated when the flow piston is in the open position and deactuated when the flow piston is in the closed position. The flow piston is configured to translate from the closed position to the open position when a differential pressure exceeds a predetermined threshold. The flow piston may be further configured to remain in the open position at differential pressures less than the threshold.

Abstract: An apparatus and method for controlling fluid flow in a blowout preventer. In one embodiment, an apparatus for connecting fluid lines includes a socket fluid connector and a plug fluid connector. Each connector includes a flow channel. The plug fluid connector is detachably connectable to the socket fluid connector at a connection end of the plug and socket fluid connectors such that the flow channels align. Each of the socket and plug fluid connectors includes a check valve in the flow channel. The check valve is configured to prevent fluid flow through the connector flow channels while the plug and socket fluid connectors are not connected, and to enable bidirectional fluid flow through the connector flow channels while plug and socket fluid connectors are connected.

Abstract: A differential pressure release sub includes a sub housing having a housing bore, a piston chamber communicating with the housing bore and at least one fluid port communicating with the piston chamber. A piston having a piston bore is disposed for axial displacement in the piston chamber from a first position wherein the at least one fluid port is fluidly sealed from the piston bore to a second position wherein the at least one fluid port is disposed in fluid communication with the piston bore. A first surface having a first surface area is on the piston. A second surface having a second surface area less than the first surface area of the first surface is on the piston.

Abstract: A casing joint assembly and methods for producing an annulus gas cap using the casing joint assembly. The casing joint assembly comprises a first valve and a second valve to control fluid pressure in the sealed annulus between the casing string and a wall of the well bore or another casing string.

Abstract: An inflow control device for a well screen comprising: a body having an internal bore, said body mountable in line with a base pipe of said well screen; a plurality of body apertures in a wall of said body, said apertures spaced longitudinally and circumferentially from each other, about said wall; a slide member in sliding engagement with an inner surface of said body, said slide member having a plurality of slide apertures; wherein the inflow control device is arranged to selectively and progressively increase the aperture area through the body through sliding the slide member, so as to align at least one of the body apertures with at least one of the slide apertures.

Abstract: A vibratory tool for use in a tubular string to prevent sticking or to release a stuck string features a fluid operated dart valve working in conjunction with an impact sleeve to deliver continuous axial jarring blows in opposed directions as long as flow is maintained. Movement of one of those components axially in opposed directions opens and closes access to opposed lateral ports so that a lateral vibration is also established as flow cyclically occurs and stops sequentially at opposed lateral outlets.

Abstract: An apparatus having a shock-absorbing sleeve is disclosed. The apparatus comprises a housing, an axially moveable sleeve received in the housing and a sealed annular space having a fixed volume axially between the housing and the sleeve. A barrier axially moveable with the sleeve divides the annular space into a first and a second chambers. The first and second chambers are filled with uncompressible dampening fluid. One or more metering passages across the barrier fluidly connect the first and chambers. During the axial movement of the sleeve, the volume of the first chamber is reduced and that of the second chamber is increased, forcing the fluid in the first chamber to flow into the second chamber in a controlled manner to dampen the movement of the sleeve.

Abstract: A valve includes: a housing; a mandrel disposed in the housing; a rupture disk disposed in a passageway of the mandrel; a sliding sleeve disposed between the housing and the mandrel; and a ball seat disposed in the mandrel. A method for actuating a valve includes: flowing a fluid through the valve; dropping a ball; seating the ball in the ball seat and blocking fluid flow through the mandrel; flowing fluid through the passageway to the sliding sleeve; moving the sliding sleeve axially within the valve; and exiting fluid through the openings of the housing and mandrel. A valve includes: a housing having an opening; a mandrel disposed in the housing; a sliding sleeve disposed between the housing and the mandrel; and a ball seat disposed in the mandrel blocking fluid communication between the mandrel and the passageway.

Abstract: A downhole isolation tool for insertion in a wellbore, for allowing, when a ported sliding sleeve thereof is slidably positioned in a first position and when coupled to a lower end of said pump apparatus, fluids within a hydrocarbon formation to be drawn through such tool and allowed to pass to the pump apparatus for pumping uphole, and when such sliding sleeve is positioned in a second position and decoupled from said lower end of the pump assembly, for preventing said fluids from passing therethrough and uphole.

Abstract: A housing can be mounted adjacent an isolation valve and after a fixed number of on and off pressure cycles allow a spring to push an actuator to operate the valve to an open position. The actuator, can be reset with a tool run into the module to move the actuator back against a power spring and hold that spring force until the pressure cycling begins again. The preferred application is for a formation isolation ball valve but other valves, such as sliding sleeves, or other types of downhole tools can be actuated with the module that permits a retrofit of a hydraulic operation to a heretofore purely mechanically actuated tool. The actuation force to initially open is boosted by a secondary potential energy source that is unlocked to give an initial boost force to the indexing spring that is part of a j-slot actuation mechanism.

Abstract: An exercise tool assembly for operating a downhole tool auxiliary to a primary actuator system of the downhole tool includes a cylinder mandrel configured to be received in the central bore of the downhole tool. A piston mandrel is in and sealed with the cylinder mandrel. The exercise tool assembly is configured to couple to an actuator sleeve of the downhole tool and to couple to the downhole tool at a location apart from the actuator sleeve. The piston mandrel is responsive to a change in pressure in the central bore to translate relative to the cylinder mandrel and translate the coupling with the actuator sleeve relative to the coupling at the location apart from the actuator sleeve.

Abstract: A self-contained cut-off device for the use in oil and gas extraction comprises a body, a stop valve, a potential energy accumulator, and a hold-release arrangement. The arrangement, fixed in the body, is equipped with clamping elements. The valve comprises a drum-shaped valve head and a seat. The head outer surface has a conical groove for the clamping elements. On the inside, the head has a through passage for a flow with a conical portion expanding from the inlet to the outlet, and with a cylindrical portion at the outlet. The head comprises a replaceable nipple in the inlet of the passage. The seat comprises circulation passages in its annular part and has a boss made with a cylindrical surface and a spherical surface adapted to mate the cylindrical and conical portions of the passage, respectively. A sealed cavity for a lubricant is formed between the body and outer surface.

Abstract: A pump assembly for recovering hydrocarbons from downhole wells. The pump assembly comprising a seating surface adapted to sealingly engage an interior surface of a first circumferential seal means situated within production tubing when said pump assembly is in a downhole operative position. A downhole ported sleeve is further provided and comprises a first port means and a second port means. The ported sleeve is adapted to move within a seal sub comprising a lower seal means and an upper seal means. The first port means is positioned between the lower seal means and the upper seal means when the pump assembly is removed from the well, thereby preventing pressurized fluids and/or gases from reaching surface. A method for sealing a well upon removal of a pump is further disclosed.

Abstract: Systems and methods for producing from multiple zones in a subterranean formation are provided. The system can include a liner including a first frac valve, a second frac valve, and a formation isolation valve. The second frac valve can be positioned above the first frac valve, and the formation isolation valve can be positioned above the second frac valve. A completion assembly can be disposed at least partially within the liner. The completion assembly can include a valve shifting tool adapted to actuate the formation isolation valve between an open position and a closed position. The completion assembly can also include a first flow control valve in fluid communication with the first frac valve and a second flow control valve in fluid communication with the second frac valve.

Abstract: A technique provides a system and methodology for enhancing the operational life of an electric submersible pumping system. A completion is combined with a flow diverter valve and is positioned downhole in a wellbore. An electric submersible pumping system is coupled into the completion and the flow diverter valve is oriented to control fluid flow with respect to the electric submersible pumping system. For example, the flow diverter valve may be automatically operable to direct well fluid to the electric submersible pumping system when the pumping system is operating and to direct well fluid to bypass the electric submersible pumping system when the pumping system is not operating.

Abstract: Systems and methods for fracturing multiple zones in a wellbore. A first port in a first valve assembly can be opened with a shifting tool. A fluid flows through the first port to fracture a first zone, and the first port can be closed with the shifting tool after the first zone has been fractured. A second port can be opened in a second valve assembly with the shifting tool after the first port has been closed, wherein the second valve assembly is positioned below the first valve assembly. The fluid can flow through the second port to fracture a second zone, and the second port can be closed with the shifting tool after the second zone has been fractured.

Abstract: Disclosed are systems and methods of producing from multiple production zones with a single trip multi-zone completion system. One single trip multi-zone completion system includes an outer completion string having at least one sand screen arranged thereabout and a flow control device movably disposed within the at least one sand screen between an open position and a closed position, and an insert string arranged within the outer completion string and having at least one control and data acquisition module disposed thereon, the at least one control and data acquisition module having one or more mechanical coupling mechanisms extending therefrom and configured to locate and move the flow control device between the open and closed positions.

Abstract: Valves comprise a chamber having a piston disposed therein. One side of the piston defines a hydrostatic chamber in fluid communication with an outside environment, such as wellbore annulus, through a port. Operatively associated with the piston on the other side is a sleeve in sliding engagement with an inner mandrel. The inner mandrel comprises a port that is initially blocked by the sleeve. Upon an increase in pressure within the annulus, the piston is moved causing the port in the sleeve to align with the port in the inner mandrel thereby allowing fluid to flow from the annulus into the bore of the inner mandrel. As a result, fluid can be circulated through the valve, or pressure within the annulus can be reduced. A return member is operatively associated with the piston to urge the piston toward the closed position after pressure within the wellbore annulus is reduced.

Abstract: A sliding sleeve has an inner sleeve that moves in a housing. For example, the inner sleeve can move open relative to a port in the housing when a deployed ball engages a seat in the inner sleeve. Because the seat and the ball (if remaining) are preferably milled out of the inner sleeve after use, the inner sleeve preferably does not rotate in the housing during milling operations. To accomplish this, an anti-rotation clutch assembly in the sliding sleeve helps prevent the inner sleeve from rotating. A wedged cone is formed on a distal end of the inner sleeve and press fits into a cupped shoulder on the inside of the sleeve's housing.

Abstract: A wellbore servicing apparatus is disclosed that includes a housing having one or more ports, a first sliding sleeve that is movable from a first position to a second position, a second sliding sleeve that is movable from a first position to a second position, a chamber within the housing, and an indicator within the chamber. When the first sliding sleeve is in the first position, the ports are obstructed and the second sliding sleeve is retained in the first position. When the first sliding sleeve is in the second position, the ports are unobstructed and the second sliding sleeve is not retained in the first position. When the second sliding sleeve is in the first position, the indicator is retained within the chamber. When the second sliding sleeve is in the second position, the indicator is not retained in the chamber.

Abstract: The present invention relates to a method of improving flow stability for a multiphase fluid flowing through a tubular element (1), comprising arranging a flow control device (2) along a flow path (F) through the tubular element (1), the flow control device (2) comprising a housing (4), an inlet (10) arranged on an upstream side of the control device (2), an outlet (23, 13) arranged on a downstream side of the control device (2), and a movable body (9) provided within the housing (4) along an internal flow path (11) through the control device (2) from the inlet (10) to the outlet (23, 13), the body (9) being arranged such that changes in velocity and/or properties and/or composition of the fluid flowing along the internal flow path (11) result in changes to the forces acting on the body (9) as a result of the Bernoulli principle, thereby adjusting the flow of fluid through the control device (2).

Abstract: A method and apparatus for a debris barrier assembly having a sleeve, an outer housing assembly coupled to the sleeve, and first and second biasing members disposed within the outer housing assembly. A support member is coupled to the sleeve and is in contact with an end of the first and second biasing members. The debris barrier assembly is coupled to a polished bore receptacle to prevent debris from entering the PBR. The debris barrier assembly is operable to compensate for a pressure differential between the internal region of the PBR and the external region of the surrounding wellbore. The debris barrier assembly and the PBR may be run in the wellbore on a work string, and the sleeve may be actuated to actuate a downhole tool connected to the sleeve to perform a downhole operation. The debris barrier assembly may be retrieved from the wellbore using the work string.

Abstract: A sliding sleeve device features a first sleeve that can be shifted with a dropped object on a seat and applied pressure to open a housing port. A second sleeve is in line with the first sleeve and be shifted to straddle the housing ports that we exposed when the opening sleeve was shifted initially. Snap rings or other locking devices can be used to hold the closing sleeve in the shifted position with the housing ports closed. The closing sleeve can also be shifted with a shifting tool that is run for example on coiled tubing. The opening sleeve can also optionally be shifted with a tool in an uphole direction to open the housing ports.

Abstract: A mechanical stage cementing tool that includes a mechanical opening and closing seat sleeve and a pin sub. The mechanical stage cementing tool may be converted to a hydraulic stage cementing tool by inserting a hydraulic tube assembly into the mechanical opening and closing seat sleeve at a hydraulic modification area and by adding a hydraulic seat to the pin sub. The stage cementing tool has a running-in-hole position, an open position, and a closed position.