Abstract: A technique is provided for actuating devices deployed in a wellbore. The technique utilizes an actuator that cooperates with a downhole device, such as a well tool. The actuator has a phase change material that can be caused to undergo a phase change upon an appropriate input. The phase change of the material is used to provide the force necessary for actuation of the downhole device.

Abstract: Apparatus for controlling a downhole device such as a choke, the apparatus comprising a housing, a mandrel connected to the downhole device and moveable within the housing to move the device between different positions, and a detent mechanism to selectively lock the mandrel in one of the positions within the housing. The first and second positions are typically defined by physical stops on the apparatus such as shoulders, or dogs and grooves etc, and are typically placed at set positions that define the different configurations of the device. Thus, the movement of the downhole device is governed by the detent mechanism, rather than by variable factors such as pressure changes.

Abstract: Methods and devices for utilizing an electrically-actuated wireline insert safety valve (WLSV) within a wellbore. Power is delivered to an electrically actuated WLSV to actuate the WLSV via inductive charging and without the use of wired contact.

Abstract: A crossover for gravel packing has multiple outlets that are selectively covered as they wear from erosion with the covering of an outlet exposing another for slurry flow to continue. Outlets are selected by a series of balls that get larger and land on progressively higher and larger seats on sleeves. As a sleeve shifts to cover a spent outlet it moves away from a new outlet for continuation of slurry flow to the outlet opened by virtue of the shifting sleeve.

Abstract: A system and method for drilling a well bore with an under-balanced hydrostatic pressure. The system comprises a tubular containing a first port and wherein a well bore annulus is formed between the well bore and the tubular member, and a compression member disposed about the outer portion of the tubular member, the compression member having extending therefrom an internal sliding mandrel, and wherein the internal sliding mandrel contains a second port. The system further comprises an external sliding sleeve operatively associated with the internal sliding mandrel, wherein the external sliding sleeve containing a third port, and wherein in a closed position the first, second and third port are misaligned and in an open position the first, second and third port are aligned. The system also includes a compressible seal disposed about the external sliding sleeve and in contact With the internal sliding mandrel, the compressible seal responsive to a longitudinal weight transferred to the compression member.

Abstract: A circulation control valve includes an opening between the valve exterior and an interior passage, an internal closure device for permitting and preventing flow through the opening, a valve device initially preventing flow through the opening, and an internal chamber. The valve device opens upon application of a pressure differential between the passage and the exterior to thereby permit communication through the opening, and the closure device displaces upon a second pressure differential between the passage and the internal chamber to thereby prevent communication through the opening. Another valve includes first and second valve devices.

Abstract: An apparatus for controlling fluid flow into a wellbore tubular includes a flow control member that selectively aligns a port with an opening in communication with a flow bore of the well bore tubular. The flow control member may have an open position wherein the port is aligned with the opening and a closed position wherein the port is misaligned with the opening. The flow control member moves between the open position and closed position in response to a change in drag force applied by a flowing fluid. A biasing element urges the flow control member to the open or the closed position. The apparatus may include a housing receiving the flow control member. The flow control member and the housing may define a flow space that generates a Couette flow that causes the drag force. The flow space may include a hydrophilic and/or water swellable material.

Abstract: A chemical injection system for controlling injection of an injection fluid from an injection fluid supply at a surface location into a production tubing assembly having an upper flow path, a first flow zone, and a second flow zone. The chemical injection system comprises a first fluid injection line configured to inject the injection fluid into the first flow zone and a second fluid injection line configured to inject the injection fluid into the second flow zone. A main fluid supply line is configured to fluidly connect both the first fluid injection line and the second fluid injection line to the injection fluid supply.

Abstract: An apparatus and a method for selectively controlling fluid flow. The apparatus includes a body member having a throughbore formed therein. The apparatus also includes at least one bypass port formed in the body member and a rotatable member arranged for insertion and rotation within the throughbore of the body member. The rotatable member in the throughbore creates first and second annular portions. The apparatus further comprises a moveable member, wherein the moveable member is moveable between a first configuration which defines a first fluid flow path between the first and second annular portions and a second configuration which defines a second fluid flow path between the first annular portion and the at least one bypass port. The moveable member is typically moveable between the first and second configurations in response to fluid flow along the first fluid flow path.

Abstract: A safety valve for use in well bore operations, for example, in cooperation with a progressive cavity pump or rodpump. One version of a safety valve (1) is designed for use with upper and lower conduits in the form of upper and lower pump rod strings (16, 18) located in wellbore production tubing (50). The safety valve comprises a housing (2) having a longitudinal bore (3) extending therethrough; a coupling member (14) for coupling the upper rod string to the lower rod string, the coupling member sealably mounted within the longitudinal bore; an annular flow passage (8) bypassing the coupling member; and a valve sleeve (23) located in the annular flow passage. In use, the valve sleeve is utilised to control flow of fluid through the flow passage bypassing the coupling member.

Abstract: A system and method for drilling a well bore with an under-balanced hydrostatic pressure. The system used in the method includes a tubular member containing a first port, a compression member disposed about the outer portion of the tubular member and having an internal sliding mandrel extending therefrom with a second port, an external sliding sleeve having a third port and being in contact with the internal sliding mandrel and operatively associated with the internal sliding mandrel, and a compressible seal disposed about the external sliding mandrel that is responsive to a longitudinal weight transferred to the compression member. In a closed position the first, second and third port are misaligned and in an open position the first, second and third ports are aligned.

Abstract: A downhole debris recovery tool including a ported sub coupled to a debris sub, a suction tube disposed in the debris sub, and an annular jet pump sub disposed in the ported sub and fluidly connected to the suction tube is disclosed. A method of removing debris from a wellbore including the steps of lowering a downhole debris removal tool into the wellbore, the downhole debris removal tool having an annular jet pump sub, a mixing tube, a diffuser, and a suction tube, flowing a fluid through a bore of the annular jet pump sub, jetting the fluid from the annular jet pump sub into the mixing tube, displacing an initially static fluid in the mixing tube through the diffuser, thereby creating a vacuum effect in the suction tube to draw a debris-laden fluid into the downhole debris removal tool, and removing the tool downhole debris removal tool from the wellbore after a predetermined time interval is also disclosed.

Abstract: A circulation control valve. A method of controlling circulation flow between an interior flow passage of a tubular string and an annulus external to the tubular string in a subterranean well includes the steps of: interconnecting a valve in the tubular string, the valve including at least one opening for providing fluid communication between the interior flow passage and the annulus; applying an increased pressure to the interior flow passage while fluid communication through the opening between the interior flow passage and the annulus is prevented, thereby permitting fluid communication through the opening between the interior flow passage and the annulus; and then applying another increased pressure to the interior flow passage while fluid communication through the opening between the interior flow passage and the annulus is permitted, thereby preventing fluid communication through the opening between the interior flow passage and the annulus.

Abstract: A tubular valve system includes, a tubular, a primary valve actuatable to control occlusion of at least one port fluidically connecting an inner bore of the tubular with an outside of the tubular, and a contingency valve actuatable to control occlusion of at least one port fluidically connecting the inner bore with the outside of the tubular.

Abstract: Disclosed herein is a downhole flow-actuated actuator. The actuator includes, a first tubular, a second tubular longitudinally movably disposed within the first tubular and movable in response to fluid flow therethrough, the second tubular having a full bore therethrough, and a movable member movably attached to the second tubular and movable with the second tubular relative to the first tubular. The movable member is movable between a first position and a second position, the movable member is unobstructive of the full bore when in the first position and at least partially occluding of the full bore when in the second position, the movable member is movable from the first position to the second position in response to movement of the second tubular.

Abstract: A downhole tool for use within a well has a body with a first downhole fluid passage provided in the body. The first downhole fluid passage has an upper inlet and a lower outlet. A first sleeve member is slidably mounted to the body such that the first sleeve member is movable between a first position in which the first sleeve member extends from the body and a second position in which the first sleeve member is substantially retracted into the first downhole fluid passage of the body. A guide adapted to guide an object travelling within the first downhole fluid passage to the first sleeve member is provided.

Abstract: A cementing tool for use in a well has a housing and a closing sleeve received thereabout. An operating sleeve is received in the housing and is interconnected with the closing sleeve so that movement in the operating sleeve will cause the closing sleeve to move. The closing sleeve is detachably connected to the housing and is movable from the first or open position to a second or closed position in which it covers cementing ports defined in the housing. The tool has a plurality of lock rings that are moved with the closing sleeve. A plurality of locking grooves are adapted to receive the lock rings such that the engagement of any of the lock rings with any of the locking grooves will prevent the closing sleeve from moving out of the closed position.

Abstract: A system is provided for switching between redundant control systems for a subsurface safety valve (SSV) while being able to isolate the closure spring from hydrostatic pressure in the control line of the system that is not being used. There are two control lines that connect to discrete operating pistons that are both coupled to the flow tube. Each operating piston is connected to a control rod with the control rods terminating near opposed ends of a pivoting member. Pushing down on one rod pushes up on the other rod so that the other rod is held supported and the hydrostatic pressure in its associated control line doesn't affect the force needed by the closure spring to close the SSV. Releasing control line pressure puts the system in neutral to allow either of the systems to be reselected.

Abstract: Disclosed is an apparatus, method and system comprising one or more devices capable of modulating fluid flow, the fluid being a liquid or a gas resulting in a pressure fluctuation in a fluid flowing within a flow channel, comprising: a flow modulating device that acts as a servo valve such that the device comprises a shaft and a moveable actuator that slides along the shaft, wherein the shaft and the actuator are positioned at any angle within a principal fluid flow channel such that the fluid flows through the principal fluid flow channel.

Abstract: Bypass assembly 100 includes stinger 150 received by receptacle bore 172 of tubular receiver 120 attached to tube 106. Bypass pathway 140 connects stinger port(s) (158, 158?) to slip hanger 122 supported hydraulic conduit 108 to bypass the tube 106. Tube 106 can be a subsurface safety valve or hydraulic nipple anchored within production tubing. Bypass assembly 200 includes upper 202 and lower 203 hydraulic nipples in production tubing 210, with respective tubular anchor seal assemblies (220, 230) engaged therein. Bypass pathway 214 connects hydraulic conduit 208 to slip hanger 242 supported hydraulic conduit 216 to bypass tubular anchor seal assemblies (220, 230). Bypass assembly 300 includes upper 302 and lower 303 hydraulic nipples in production tubing 310, with respective tubular anchor seal assemblies (320, 330) engaged therein. Bypass passage 318 connects stinger 350 to slip hanger 342 supported hydraulic conduit 316 to bypass tubular anchor seal assemblies (320, 330).

Abstract: An apparatus for actuating a downhole tool within a well bore comprises a cylindrical mandrel extending longitudinally through the downhole tool; an interventionless, hydrostatic, top-down actuating piston disposed about the mandrel and forming a first chamber and a second chamber therebetween; and a rupture disk that prevents fluid communication between the well bore and the first chamber until sufficient hydrostatic pressure is applied to the well bore to fail the rupture disk. A method of actuating a downhole tool comprises connecting a top-down actuating module to the downhole tool, running the downhole tool to a desired depth within a well bore, pressuring up the well bore without pressuring up an internal flow bore extending through the top-down actuating module, hydrostatically actuating an upper piston of the top-down actuating module to exert an actuation force onto the downhole tool, and actuating the downhole tool.

Abstract: A tool for shifting a sleeve into at least one intermediate position between stops has a shifting key that only can move the sleeve a finite amount before it is forced out of contact with the sleeve. An overpull key is released for engagement with the sleeve before the shifting key is forced out. The overpull key resists movement until a noticeable predetermined force is applied at which point the overpull key is freed from the sliding sleeve for a normal release. If any key fails to release, an emergency release is provided that independently displaces the key so that the tool can be removed. The tool can be operated in either an uphole or a downhole direction to shift the sleeve depending on the orientation of the keys. Embodiments using a single key type are contemplated.

Abstract: A tool and associated method allows a liner top to be dressed. Then while maintaining a lateral port closed the tool can be used to circulate while being rotated and reciprocated. The tool features discrete j-slot mechanisms. The upper j-slot allows the lateral port to initially open while the lower j-slot keeps the lateral port open despite movement of the tool in opposed directions in the hole due to a barrier to the pin in the lower j-slot. When enough weight is set or the barrier is otherwise removed, the lateral port can be closed and the test packer set by set down weight with the lateral port closed. After the packer is unset the lateral ports can be reopened and circulation and swiveling on a bearing can occur even if the packer is temporarily actuated from the setting down motion that reopened the lateral ports.

Abstract: A flapper type downhole valve is opened by flow against the flapper. The flapper and the housing contain magnets that hold the flapper open after it has been opened by flow to keep the flapper from chattering from the flow going past it. The strength of the force is not sufficient to hold the flapper open against a torsion spring on a pivot pin, when there is no flow through the valve. The valve can still be held in the locked open position with no flow through the housing by pressurizing the surrounding annulus to position another magnet to increase the holding force to a level greater than the force of the torsion spring. The additional magnet is spring biased so that upon removal of annulus pressure it shifts to allow the flapper to close. Alternative designs with and without a flow tube are possible. Fixed or movable restrictions can be associated with the flow tube to create a force to shift it to open a flapper with flow into the well.

Abstract: A control system for a subsurface safety valve addresses normal open and closed operation and a failsafe operation if key system components fail. It features a single control line from the surface that splits at the subsurface safety valve and goes to one end of two discrete piston chambers that are aligned and isolated from tubing pressure. The piston in one chamber is larger than in the other and the pistons are connected for tandem movement. Each side of the unbalanced system's piston has a seal mounted to it and another for the rod attached to it that exits the chamber. A jumper line connects the chambers at a point between the seals in each chamber and features a large reservoir. The jumper line is filled with a compressible fluid. Fail safe closure of the valve occurs if any of the four seals fail.

Abstract: A downhole valve has a flow tube hydraulically actuated to open and close a flapper. The flow tube moved to a first position closes the flapper to restrict flow through the valve. The flow tube moved to a second position opens the flapper. A passable no-go device disposed in the valve permits or restricts mechanical passage through the valve in response to the position of the flow tube. The apparatus has a support and one or more dogs supported in windows of the support and biased by springs. The flow tube in the first position pushes the dogs to an extended position that restricts mechanical passage through valve so that a tool cannot be passed through the valve while the flapper is closed. When the flow tube is in the second position, however, the dogs retract so the tool can be passed through the valve while the flapper is open.

Abstract: A safety valve with a flapper/flow tube friction reducer. A safety valve for use in a subterranean well includes a closure assembly, an operating member which engages the closure assembly, and at least one of the closure assembly and the operating member including a friction reducing device which provides rolling contact between the closure assembly and the operating member. Another safety valve includes a flapper which rotates about a pivot relative to a seat, a flow tube which engages the flapper to rotate the flapper, and a friction reducing device which with rolling contact biases the flow tube toward the pivot when the flow tube engages the flapper. Yet another safety valve is described in which at least one of the flapper, the seat and the flow tube has a friction reducing device attached thereto which provides rolling contact between the flapper and the flow tube, or between the flow tube and the seat.

Abstract: A valve control system for a wellbore includes a fiber composite actuator functionally coupled to a valve operating member and means for controllably charging an interior of the actuator with fluid under pressure. A valve for a wellbore includes a valve stem and a valve seat associated with a valve body. The valve stem and valve seat are configured to enable fluid flow from an inlet port in the valve body to an outlet port in the valve body when the stem is moved from the seat. An axial contraction fiber composite actuator is functionally coupled to the valve stem. The valve includes means for controllably charging an interior of the actuator with fluid under pressure.

Abstract: Disclosed herein is a downhole valve. The downhole valve includes, a flapper seat, a flapper sealable against the flapper seat, a spring housing in axial alignment with the flapper seat and a metal-to-metal seal disposed between the flapper seat and the spring housing. The metal-to-metal seal is sealable to both the flapper seat and the spring housing when in an energized position. Additionally, the metal-to-metal seal is a separate component from both the flapper seat and the spring housing.

Abstract: The present invention relates to a cementing or inflow regulation valve for conducting cementing operations or inflow regulation in a wellbore comprising a casing or tubing (2), wherein the cementing or inflow regulation valve (1) is inserted between the casing or tubing (2), wherein the cementing or inflow regulation valve (1) comprises an inner sliding sleeve valve (3) which in a closed position covers a number of openings (4) through an outer pipe (5) of the casing or tubing (2) and which in an open position uncovers said openings (4), the sliding sleeve valve (3) comprising a releasing means (6) requiring a certain force to be released both from the closed position to the open position, and vice versa.

Abstract: An annular choke mechanism is incorporated into a flow path within the outer housing of the sleeve valve to the interior flow ports of the sliding sleeve member. As the sliding sleeve member is moved axially within the housing, the lateral fluid ports of the sliding sleeve member are aligned within particular bore portions so that the size of the annular space between the fluid ports in the housing and the fluid ports in the sleeve is varied. The annular flow area through the annular space governs the rate of fluid flow through the valve.

Abstract: Methods and devices are provided for treating multiple interval well bores. More particularly, an isolation assembly may be used to allow for zonal isolation to allow treatment of selected productive or previously producing intervals in multiple interval well bores. One example of a method for treating a multiple interval well bore includes the steps of: introducing an isolation assembly to a well bore, the isolation assembly comprising a liner, one or more sleeves and a plurality of swellable packers, wherein the sleeves and swellable packers are disposed about the liner; deploying a shifting tool inside the liner, where the sleeves are configured so as to provide open, closed and open to screen positions when actuated by the shifting tool. An open position allows for treatment of the well bore while an open to screen position allows for receiving fluid from the well bore. A closed position re-establishes zonal isolation.

Abstract: A tool is actuated in a well based on one or more issued commands being interpreted and implemented by the apparatus. The apparatus comprises a power generation module that multiplies pressure delivered downhole to enable actuation of the tool without requiring delivery of the higher actuation pressure along the entire wellbore. An actuation module may be used in combination with the power generation module to control operation of the power generation module in response to command signals sent downhole.

Abstract: Systems and methods for opening and/or closing sliding sleeve valves while preventing significant stress upon and damage to the fluid seals that are disposed between the outer housing and the sleeve member elements of the valve. A shifting tool carries a latching device and a fluid closure portion with sacrificial seals. In operations the shifting tool is secured to the sleeve member with the latching device as the closure portion seals off across the fluid flow port of the sleeve member. The shifting tool is then moved to slide the sleeve member between open and closed positions.

Abstract: A control system for a downhole tool, such as a subsurface safety valve, features an operating piston that is insensitive to tubing pressure in the valve. The hydrostatic forces from the single control line from the surface are significantly reduced with a branch line to a piston bottom that is slightly smaller than the piston top. A variable volume between piston seals is connected to a low pressure compressible fluid reservoir to permit piston movement. The piston can be modular to facilitate assembly or bore offsets in the valve body. Failsafe closure upon seal failures is contemplated.

Abstract: A valve for downhole use has the ability to throttle between fully open and closed and is fully variable in positions in between. The valve is preferably responsive to flowing fluid viscosity and uses a three dimensional flow through restrictor in combination with a relatively movable cover. At a given flow, a higher viscosity fluid will create a greater relative movement and make it possible for flowing fluid to bypass more of the flow through member. In a particular application involving production from a zone, an array of such valves can allow more production where the viscosity is higher and less production where the viscosity drops due to, for example, water production.

Abstract: The present invention generally relates to a non-elastomeric cement through tubing retrievable safety valve configured to control fluid flow through a production tubing string. In one aspect, a valve for use in a wellbore is provided. The valve includes a tubular body. The valve further includes a flow tube having a bore therethrough, wherein the flow tube is disposed in the tubular body to form an annular area therebetween. The valve further includes a flapper movable between an open position and a closed position in response to the movement of the flow tube. Additionally, the valve includes a sealing system constructed and arranged to substantially isolate the annular area from the bore, thereby substantially eliminating the potential of contaminants in the bore from entering into the annular area. In another aspect, a method of controlling fluid in a wellbore is provided.

Abstract: A tool for shifting a sleeve into at least one intermediate position between stops has a shifting key that only can move the sleeve a finite amount before it is forced out of contact with the sleeve. An overpull key is released for engagement with the sleeve before the shifting key is forced out. The overpull key resists movement until a noticeable predetermined force is applied at which point the overpull key is freed from the sliding sleeve for a normal release. If any key fails to release, an emergency release is provided that independently displaces the key so that the tool can be removed. The tool can be operated in either an uphole or a downhole direction to shift the sleeve depending on the orientation of the keys. Embodiments using a single key type are contemplated.

Abstract: A step ratchet mechanism that allows for the incremental movement of an assembly that may be adapted to incrementally open or close an adjustable orifice. The step ratchet mechanism may be comprised of a modified body lock ring that permits incremental movement along a mandrel in either direction along the mandrel. The step ratchet mechanism may be actuated a designated distance by the application of pressure to the mechanism. The step ratchet mechanism may be ideal for using pressure to drive a downhole multi-position device. The modified body lock ring is adapted to both secure the mechanism at each set position as the mandrel is pumped down as well as allowing the mechanism to ratchet when the mandrel is pumped back.

Abstract: There is disclosed a safety valve for use in well bore operations, for example, in cooperation with a progressive cavity pump or rodpump. In one embodiment of the invention, a safety valve (1) disclosed which is designed for use with upper and lower conduits in the form of upper and lower pump rod strings (16, 18) located in wellbore production tubing (50). The safety valve comprises a housing (2) having a longitudinal bore (3) extending therethrough; a coupling member (14) for coupling the upper rod string to the lower rod string, the coupling member sealably mounted within the longitudinal bore; an annular flow passage (8) bypassing the coupling member; and valve means comprising a valve sleeve (23) located in the annular flow passage. In use, the valve sleeve is utilised to control flow of fluid through the flow passage bypassing the coupling member.

Abstract: A mechanical flow control device is provided that allows flow of production fluids along an annular path and across an valve body. A sliding sealing member can be mechanically transitioned between an opened flow position and a closed flow position as desired. The mechanical flow control device may be combined with one or more interventionless flow control devices.

Abstract: A wellbore valve includes a valve operator arranged to move axially along an interior of the wellbore, the valve operator arranged to operate a valve. A valve actuator is disposed proximate the valve operator. The valve actuator is arranged to move from one longitudinal position to another. A linear magnetic gear is coupled at an input element thereof to the valve actuator. The gear is coupled at an output element thereof to the valve operator such that motion of the valve actuator is transferred to the valve operator.

Abstract: An annular choke mechanism is incorporated into a flow path within the outer housing of the sleeve valve to the interior flow ports of the sliding sleeve member. As the sliding sleeve member is moved axially within the housing, the lateral fluid ports of the sliding sleeve member are aligned within particular bore portions so that the size of the annular space between the fluid ports in the housing and the fluid ports in the sleeve is varied. The annular flow area through the annular space governs the rate of fluid flow through the valve.

Abstract: A material that reacts to produced hydrocarbons acts as a latch to retain a stored potential energy force. In a specific application, a sliding sleeve valve is held away from a circulating port to allow drilling mud to be circulated out. Later, when the well is put on production, the lock that holds collets in a groove releases as exposure to produced hydrocarbons at a retaining sleeve makes it get soft. This, in turn, allows a spring force to run the collets out of their groove and straddle the circulation port between two o-rings on the shifting sleeve to close the port. The closure of the port directs produced hydrocarbons to screens that had been bypassed when mud was circulated out due to ports being the path of least resistance.

Abstract: A flow control apparatus (100) for controlling the inflow of production fluids (134, 140) from a subterranean well includes a tubular member (118) having at least one opening (138) that allows fluid flow between an exterior of the tubular member (118) and an interior flow path of the tubular member (118) and a flow restricting device (120) operably positioned in a fluid flow path between a fluid source and the at least one opening (138). The flow restricting device (120) includes a valve (128, 130) and an actuator (126). The actuator (126) includes a material that swells in response to contact with an undesired fluid (140), such as water or gas. The flow restricting device (120) is operable to autonomously reduce the fluid flow through the flow control apparatus (100) in response to contact between the material and the undesired fluid (140).

Abstract: A step ratchet mechanism that allows for the incremental movement of an assembly that may be adapted to incrementally open or close an adjustable orifice. The step ratchet mechanism may be comprised of a modified body lock ring that permits incremental movement along a mandrel in either direction along the mandrel. The step ratchet mechanism may be actuated a designated distance by the application of pressure to the mechanism. The step ratchet mechanism may be ideal for using pressure to drive a downhole multi-position device. The modified body lock ring is adapted to both secure the mechanism at each set position as the mandrel is pumped down as well as allowing the mechanism to ratchet when the mandrel is pumped back.

Abstract: A wellbore control device (10) for sealing a wellbore is described. The device has, in a preferred arrangement, two opposed cutting rams (16, 18) which are coupled to respective linkage mechanisms (26, 28). The linkage mechanisms translate axial movement of a piston into radial movement to move the rams towards each other in the device throughbore. This results in an effective wellbore control device having a compact size and shape which can be encompassed within a wellbore.

Abstract: It is provided a tool and its operating procedure, to protect any device while lowering into a well, and especially hydraulic devices such as sensors with expandable arms or inflatable elements such as packers. The protection is mainly important in the open hole of highly deviated or horizontal wells, for any device equipped with external seal element, delicate sensor or articulated parts. This tool features an automatic sequence controlled by a single dart or a single ball launched into the running string from the surface: when the dart or the ball lands on its seat, the pressure build-up is initially applied to a piston to extract the device from the protector without exposing it to any differential pressure, then it is automatically applied to the device itself for actuation as soon as the device is entirely pulled out of the protector.

Abstract: A system for controlling zones of fluid flow in and out of a wellbore. The wellbore has a top of a well and a bottom of a well. The system has a control line connected to a power source, and a control system; wherein the control line is disposed within the wellbore. The system also has a single fluid line sliding sleeve downhole tool assembly connected to the control line disposed within the wellbore.

Abstract: A circulating sub is run in with the circulating port closed. A dart blocks a central passage and moves two concentric pistons in tandem to open the circulation port while retaining the dart. The outer piston shoulders out in the circulation port open position. A second dart lands on the first and with applied pressure moves the inner piston relative to the shouldered outer piston to close the circulation port and only then discharge both darts. Subs can be used in tandem as long as higher located subs accept larger darts than lower subs and preferably the two darts for each sub are the same size. The ejected darts can be used to pressure actuate a downhole tool like a packer.