Abstract: An apparatus for use in a fluid conduit comprises a plurality of segments arranged along a longitudinal axis, each segment comprising an extendable structure configured for extension in a lateral direction relative to the longitudinal axis, wherein the apparatus is configured for the sequential initiation of lateral extension of the extendable structures of at least two segments. At least two segments may be configured to define different maximum extended dimensions in the lateral direction and may include adjacent support surfaces which provide mutual support for one another when the at least two segments are laterally extended. The apparatus may be configured to form a seal, an anchor, a supporting structure and/or a flow restriction in a fluid conduit.

Abstract: Certain aspects and embodiments of the present invention are directed an inflow control device tube that can be disposed in a wellbore through a fluid-producing formation. The inflow control device tube can include a body, such as a tubular body, and an inlet portion at a first end of the body. The inlet portion can be integrally formed with the body. The inlet portion can be adapted to provide a fluid bypass for a fluid flowing from the inlet portion to an outlet portion at a second end of the body. The fluid bypass can be shaped to allow fluid to bypass one or more objects causing a blockage at an opening of the inlet portion.

Abstract: An apparatus for controlling the flow of downhole fluids comprises a body having a throughbore and at least one port extending through a sidewall of the body to enable fluid communication between the throughbore and an exterior of the body. The apparatus comprises a flow control device for controlling the flow of fluids through the port. The flow control device is arranged to change configuration between a closed configuration in which fluid flow through the port is restricted and an open configuration in which fluid flow through the port is permitted. The apparatus further comprises an actuator mechanism associated with the flow control device for selective actuation of the flow control device to change the configuration of the flow control device between the closed and open configurations.

Abstract: A downhole valve assembly including at least one membrane permeable to a flow of a downhole fluid, the at least one membrane defining a passage through a chamber. A quantity of particles is disposed in the chamber and the at least one membrane is impermeable to the particles. The particles are responsive to a magnetic field. At least one magnetic element is operatively arranged to produce the magnetic field for enabling the at least one magnetic element to selectively move the particles between a first position at which the particles impede the flow of the downhole fluid through the at least one membrane and a second position at which the particles do not impede the flow of the downhole fluid through the at least one membrane. A method of controlling a flow of fluid is also included.

Abstract: A downhole tool and method of operation thereof is provided. The downhole tool may be configured to permit fluid communication between a combined flowbore of the casing string and the downhole tool and the subterranean formation or wellbore, or both, after a pressure test has been completed, a second threshold pressure is reached or applied, and a third threshold pressure has been applied to the downhole tool.

Abstract: A method for servicing a subterranean formation comprising providing a wellbore penetrating the subterranean formation, and placing a wellbore servicing tool in the wellbore, wherein the wellbore servicing tool comprises a baffle, wherein the baffle comprises a seat contoured to match a spherical zone of an obturator.

Abstract: The present invention relates to an inflow control device for controlling the flow of fluid into a tubular deployed in a wellbore comprising coupling between joints of tubulars. The inflow control device is mounted transversely through the coupling in any inflow can control devices the initial condition fluid flow between the exterior and interior of the tubular is prevented. As sufficient pressure is exerted upon the inflow control device from the interior of the tubular the inflow control device is actuated to allow fluid flow between the interior and exterior the tubular. A nozzle in the inflow control device allows fluid to pass at a preset rate.

Abstract: A flow control assembly can be mechanically adjusted, rotationally or translationally, inside a tubing downhole between multiple positions by an intervening tool from the surface to change resistivity to flow through the flow control assembly. The positions among which the flow control assembly can be adjusted can include a closed position, a fully open position, and positions at which fluid experiences various resistances prior to flowing to an inner area of the tubing.

Abstract: A downhole equalization assembly permits selective and remote opening of at least one downhole port or pathway to allow communication of pressure and/or fluid flow from inside a pressure containing system (such as, for example, a tubular pipe or other pressure containment system) to the outside of the containment system, or vice versa. A control device generating a magnetic field is inserted into a well and conveyed to a downhole equalization assembly. When the control device passes through an equalization assembly, an electrical current is generated that triggers an electronic counter. When a predetermined counter number is reached, a sliding sleeve is shifted, thereby exposing ports and/or pathways extending between the inside and outside of the equalization assembly. No physical contact or mechanical interference is required between the control device and any other components in order to actuate the equalization assembly.

Abstract: The disclosure relates to purging a RCD including a bearing of contaminants with a fluid circuit, the fluid circuit having at least one housing adjacent to the RCD, a first plurality of valves within the bearing, a second plurality of valves within the housing, at least one inlet port located on the RCD, each inlet port being connected to the housing, at least one outlet port located on the RCD, each outlet port being connected to the housing, and a purge outlet in fluid communication with the fluid circuit.

Abstract: A valve and valve assembly are provided to allow opening of flow channels through the wall of a tubular by increasing and then decreasing pressure in the tubular. Slidable seals having different areas are used to apply an axial force to a shuttle in the valve in response to differential pressure across the valve when in the closed position. The axial force shears a pin, releasing the shuttle. A decrease of pressure in the tubular can allow the valve to open in response to a spring force. Multiple valves may be placed along a tubular string and the valves may be opened all at substantially the same time or at time intervals determined by pressures applied inside the tubular.

Abstract: A downhole tool has a housing, a mandrel, a seat, and a piston. The housing defines a first bore, and the mandrel is movably disposed in the first bore and defines a second bore. The mandrel has first and second mandrel sections or upper and lower cones, and the first mandrel section defines a cross-port communicating the second bore with an annular space between the mandrel and the housing. The seat is disposed in the first bore of the housing between the first and second mandrel sections. The seat is movable to a constricted state in the first bore to catch a dropped ball and is movable to an expanded state in the first bore to pass a dropped ball. The piston is disposed in the annular space and at least temporality supports the seat in its constricted state.

Abstract: A flow control assembly can be mechanically adjusted, rotationally or translationally, inside a tubing downhole between multiple positions by an intervening tool from the surface to change resistivity to flow through the flow control assembly. The positions among which the flow control assembly can be adjusted can include a closed position, a fully open position, and positions at which fluid experiences various resistances prior to flowing to an inner area of the tubing.

Abstract: Disclosed are autonomous inflow control devices and methods of use thereof. One flow control device includes a body having an inlet and an outlet and a flow chamber extending therebetween, the flow chamber being configured to convey a fluid composition comprising one of a desired and undesired fluid from the inlet to the outlet, a nozzle arranged at the outlet and in fluid communication with the flow chamber, and at least one helical groove defined along at least a portion of an axial length of the flow chamber, the at least one helical groove being configured to impart rotational motion to the fluid composition and thereby force at least some of the undesired fluid into the at least one helical groove and slow its progress along the axial length of the flow chamber.

Abstract: This invention relates to controlling production fluids downhole in an oil well. More specifically, this invention relates to control of water and pressure downhole. Provided are apparatus for controlling production fluids and pressures and methods of using the apparatus to control production fluids and pressures.

Abstract: A valve assembly includes a main housing having a central bore therethrough, an upper valve subassembly disposed within the main housing, the upper valve subassembly including an upper seat configured to contact a corresponding lower seat of a lower valve subassembly, and a flow diverter ring disposed proximate the upper seat of the upper valve subassembly, wherein the flow diverter ring is configured to direct a fluid flow radially away from the upper seat of the upper valve subassembly.

Abstract: A stage tool apparatus and components for same are described. In several exemplary embodiments, the stage tool apparatus is part of tubular string or casing positioned within a preexisting structure such as, for example, a wellbore.

Abstract: A method, system and apparatus is provided for a partially retrievable safety valve to control a well. The method includes securing a normally closed valve in the well. The valve may be a self-equalizing flapper valve. Following this, an actuator system operable to open the valve is run into the well. The actuator system is removable from the well while the valve remains closed and secured in the well. A submersible pump and motor may be secured to the actuator system before the actuator system is run into the well. The submersible pump and motor are also removable from the well while the valve remains closed and secured in the well. Therefore the actuator system, submersible pump and motor can be replaced or redressed, while the valve remains closed, keeping the well under control at all times.

Abstract: The disclosed hydrocarbon lift system and method prohibits water-coning in production of oil from a subterranean reservoir to the earth's surface. The system comprises a well bore with a first and a second section. The first section has perforations which draw a first fluid into and up the well bore based on a negative pump pressure applied thereto. The second section has perforations which draw a second fluid into the well bore based on a differential pressure between the pump pressure and a lower induced pressure therein. The system also comprises a venturi structure fixtured into the well bore. The venturi structure has flaring ends connected by a constricting throat defining perforations therein. The constricting throat perforations draw the second fluid through the second section perforations into the venturi throat in response to the lower induced pressure in the second section created by an increased first fluid velocity there through.

Abstract: Apparatus and methods for conducting well-related fluids are disclosed. The apparatus and methods may be used to mitigate erosion of fluid handling equipment by fluids associated with hydrocarbon wells. An exemplary apparatus comprises: an upstream conduit including an upstream fluid passage for receiving and conducting well-related fluid; a choke member including a choke fluid passage; and a downstream conduit including a downstream fluid passage in fluid communication with the upstream fluid passage via the choke fluid passage. A cross-sectional area of the downstream passage may be greater than a cross-sectional area of the upstream passage to allow expansion of the fluids passing through the choke such that the average velocity of such fluids may not exceed a threshold velocity selected to mitigate erosion of the downstream conduit.

Abstract: A well is drilled and casing installed utilizing a casing drilling technique. A bottom hole assembly having a drill bit and a fluid diverter is secured to a string of drill pipe and installed within a casing string. Drilling fluid is pumped down the drill pipe string to cause the drill bit to rotate and drill the well while the fluid diverter is in a drilling mode position. At the total depth for the casing string, the operator moves the fluid diverter to a cementing position and pumps cement down the drill pipe and up the casing string annulus. After cementing, the operator moves the fluid diverter to a packer set position and again pumps drilling fluid down the drill string to set the packer.

Abstract: A wellbore ball valve includes a ball-type valve closure having an interior, central bore. A lower ball carrying assembly defines a first annular, sealing seat surface in contact with and adapted to seal with the exterior of the valve closure. The first seat surface defines a first through hole. An upper assembly defines a second annular seat surface in contact with the exterior of the valve closure. The second seat surface defines a second through hole. The second through hole is shaped differently from the first through hole in that it at least partially overlaps with the central bore while the first through hole is sealed from the central bore.

Abstract: A well system can include an inflow control device which resists flow into a tubular string. A selection from among multiple different flow resistances through the inflow control device can be performed in response to pressure manipulation. An inflow control device can include a piston which is displaceable to at least two positions. Flow through the inflow control device is permitted at a certain flow resistance when the piston is at one position, and flow through the inflow control device is permitted at a greater flow resistance when the piston is at another position. Fluid which flows through the inflow control device can be constrained to flow through an increased number of flow restrictors in response to displacement of the piston from the first to the second position.

Abstract: An apparatus for engaging and moving a ram block. In some embodiments, the apparatus, or ram block changer, includes a support bracket coupled to a blowout preventer and an articulated arm releasably coupled to the ram block. The ram block changer may further include a pivot coupling assembly having a first axis of rotation. The pivot coupling assembly extends through the support bracket and the articulated arm, wherein the articulated arm is rotatable about the first axis of rotation relative to the support bracket. The articulated arm may include a first member receiving the pivot coupling assembly therethrough, a second member coupled to the ram block, and a second pivot coupling assembly having a second axis of rotation spaced apart from the first axis of rotation and extending through the first and second members. The second member is rotatable about the second axis of rotation relative to the first member.

Abstract: A system and methodology facilitates utilization of a valve and a cutter both of which may be used in a subsea test tree. The valve comprises a ball element pivotably mounted in a housing and having an exterior surface and a passageway sized to receive a conveyance therethrough. The cutter also is located in the housing but at a position spaced from the ball element. The cutter is oriented for selective severing of the conveyance. Additionally, a seal system is positioned to act against a surface of the ball element.

Abstract: An sleeve valve for a well assembly includes at least one set of passages extending through a tubular body between the central passage and an exterior of the tubular body and a sleeve slidably located within the central passage of the valve body adapted to selectably sealably cover or uncover the at least one sets of passages. A shifting tool for actuating the sleeve valve is connectable to a tool string and includes a shifting bore with an actuating piston extending from a central bore through the shifting tool and first and second key bores extending radially inwards from the outer surface each having a piston keys located therein. Each of the first and second piston keys is operably connected to the actuating piston so as to be extended from the outer surface when the central bore is supplied with a pressurized fluid.

Abstract: Certain aspects of the present invention are directed to a liquid valve assembly that can be disposed in a wellbore through a fluid-producing formation. The liquid valve assembly can include a housing and a liquid valve. The housing can define an inner chamber and an opening adapted to allow fluid to flow between the inner chamber and a passageway. The liquid valve can be disposed in the inner chamber. The liquid valve can include a yield stress fluid. The yield stress fluid can prevent fluid from flowing between the inner chamber and the passageway.

Abstract: Sneak path elimination in diode multiplexed control of downhole well tools. A system for selectively actuating multiple well tools includes a control device for each tool, a well tool being operable by selecting a respective control device; conductors connected to the control devices, which are selectable by applying a predetermined voltage across a respective predetermined pair of the conductors; and at least one lockout device for each control device, the lockout devices preventing current from flowing through the respective control devices when voltage across the respective predetermined pair of the conductors is less than a predetermined minimum. A method includes selecting a well tools for actuation by applying a predetermined minimum voltage to a set of conductors; and preventing actuation of another well tool when the predetermined minimum voltage is not applied across another set of conductors, at least one conductor being common to the two sets of conductors.

Abstract: Systems and methods for completing a wellbore. The system may include a first outer tubular member having an inflow control device configured to allow fluid to pass radially through the first outer tubular member. A second outer tubular member may be coupled to the first outer tubular member via an axial coupling. The second outer tubular member may have an inflow control device configured to allow fluid to pass radially through the second outer tubular member. An inner tubular defining an inner bore may be disposed at least partially within the first outer tubular member, the second outer tubular member, or a combination thereof such that an annulus is formed radially therebetween. The inner tubular member may include a flow control device configured to allow fluid to pass radially between the inner bore and the annulus.

Abstract: A fluid flow control device disposable in a bore can include channels that can direct fluid flow based on one or more properties of the fluid more robustly. The channels may include a side channel between two other channels. The side channel can allow fluid flow to affect fluid flowing in one of the channels. Devices according to some aspects can differentiate between fluids having close, but different, properties and direct the fluid accordingly. Examples of fluid properties based on which the device can direct fluid include fluid density, fluid velocity, fluid viscosity, and Reynolds number of the fluid flow.

Abstract: A frac sleeve system includes an outer sleeve with openings, an inner sleeve with ports, a pressure seat, a bottom locking device and a spring device. In a closed configuration of the inner sleeve, the openings and ports are not aligned for any fluid connection. In an opened configuration, at least one opening is aligned with at least one port for a fluid connection through the system. The inner sleeve shifts back and forth between configurations according to the pressure seat and the spring. The interaction of a guide pin on the outer sleeve and the guide slot on the inner sleeve controls the rotational and longitudinal movement of the inner sleeve along the common axis of the inner sleeve and outer sleeve so that there is unlimited shifting between configurations. The locking devices and spring device are also reuseable for the multiple shifting.

Abstract: An apparatus for flowing a tool string along a wellbore tubular includes a flow restrictor having a diametrically expanded position and a diametrically retracted position. The flow restrictor sealingly engages the wellbore tubular when in the diametrically expanded position. The apparatus also includes a joint connected to the flow restrictor. The joint actuates the flow restrictor between the expanded position to the retracted position while moving between an open and a closed position.

Abstract: A drillstring combination pressure reducing and signaling valve assembly uses multiple ball valves mounted in parallel, each having a different bore, to meter the flow through a drillstring. The individual ball valves are maintained in either a fully open or a fully closed position, but can be selectively moved between these two positions. The bores of the individual ball valves are sized so that at a given pressure, a first ball valve has a predetermined flow rate, a second ball valve has twice the flow rate of the first ball valve, a third ball valve has twice the flow rate of the second ball valve, and the remaining ball valves each have twice the flow rate of their predecessor in the valve sequence. This arrangement permits the flow rate and flow pressure drop through the assembly of valves to be digitally controlled by varying the combination of open and closed valves.

Abstract: A downhole hydraulic control tool comprising a substantially tubular body adapted for connection in a tubing string, the body including a throughbore arranged coaxially with a bore of the tubing string and one or more pockets arranged on a wall of the body, the pockets including a hydraulic power source and at least two control lines, wherein the device includes a pump to drive hydraulic fluid through the control lines and a switchable flow mechanism for switching the flow of pumped fluid between the at least two control lines, and a switchable flow mechanism and a method of operating one or more downhole devices from a downhole located hydraulic control tool.

Abstract: In an exemplary embodiment, an apparatus includes a valve assembly, the valve assembly including a tubular member and a valve connected thereto, wherein the valve permits fluid flow through the tubular member in a first direction and prevents fluid flow through the tubular member in a second direction that is opposite the first direction. A plug is adapted to be secured to the valve assembly so that the plug is prevented from moving, relative to the valve assembly, in the first and second directions. In an exemplary embodiment, the apparatus is a cementing plug apparatus, which can plug a tubular string or casing so that fluid flow therethrough is prevented. In an exemplary embodiment, the tubular string or casing may be positioned within a preexisting structure such as, for example, a wellbore.

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: The present invention discloses a method and apparatus for remotely and selectively control fluid flow through tubular string disposed within a wellbore and further control fluid flow between the tubular string inner flow passage and the annular flow passage. The present invention further discloses a method of selectively and remotely receiving and interpreting a form of command or information at a desired apparatus within the wellbore caused by the operator on earth surface.

Abstract: A coiled tubing gas injection mandrel includes a housing assembly capable of attachment to coiled tubing, wherein the housing assembly comprises an up-hole end, a down-hole end, a sleeve longitudinally integrally connected with the up-hole end and the down-hole end, and a slide-through valve receptacle assembly removably connected within the sleeve. In more detail, the slide-through valve receptacle assembly comprises an up-hole pipe with a shoulder, at least one laterally extending projection, at least one laterally extending port, a down-hole pipe integrally connected with the up-hole pipe, and a longitudinal bore within the up-hole pipe and down-hole pipe. The up-hole end and down-hole end are capable of attachment with coiled tubing. The slide-through valve assembly and the sleeve form a gas flow passageway, wherein the gas flow passageway controls the flow of gas through a gas lift valve installed in the slide-through valve receptacle for gas being injected into the coiled tubing.

Abstract: A back pressure valve for sealing a wellbore. The back pressure valve has a cylindrical body with threads designed to engage threads in the opening of a tubing hanger within the wellbore. The back pressure valve also has a metal sealing surface. When the threads of the back pressure valve engage the threads in the opening of the tubing hanger, the metal sealing surface of the valve seals against the metal of the tubing hanger, forming a metal to metal seal.

Abstract: A device and method that, on a command from the surface, a seat in a tubular may be moved into the bore of a tubular so that a ball of the appropriate size may be caught. The seat may also be moved out of the bore on command so that a ball of the appropriate size will not be caught by the seat.

Abstract: A variable flow resistance system for use with a subterranean well can include a structure which displaces in response to a flow of a fluid composition, whereby a resistance to the flow of the fluid composition changes in response to a change in a ratio of desired to undesired fluid in the fluid composition. Another system can include a structure which rotates in response to flow of a fluid composition, and a fluid switch which deflects the fluid composition relative to at least two flow paths. A method of variably resisting flow in a subterranean well can include a structure displacing in response to a flow of a fluid composition, and a resistance to the flow of the fluid composition changing in response to a ratio of desired to undesired fluid in the fluid composition changing. Swellable materials and airfoils may be used in variable flow resistance systems.

Abstract: A safety system for a well having a cable deployed electronic submersible pump includes a barrier valve having a control line for opening and closing the valve, a first flapper safety valve assembly, and a second flapper safety valve assembly. The second flapper safety valve allows the cable for the pump to pass through the second flapper safety valve when the valve is in a closed position. An integral flapper safety valve assembly incorporates the first and second flapper safety valves.

Abstract: A method of producing at least a portion of a wellbore isolation device comprising: providing a fusible alloy matrix in a powdered form; placing at least the particles of the fusible alloy matrix powder into a mold; compacting the particles located inside the mold via an application of pressure; and fusing the particles together to form a solid material, wherein the solid material forms the at least a portion of the wellbore isolation device.

Abstract: A downhole tester valve (100) includes a housing assembly (106) and a mandrel assembly (172, 174) that define therebetween an operating fluid chamber (176), a biasing fluid chamber (184) and a power fluid chamber (180). A valve assembly (126) disposed within the housing assembly (106) is operable between open and closed positions. A piston assembly (146) is operably associated with the valve assembly (126) such that annulus pressure entering the power fluid chamber (180) pressurizes operating fluid in the operating fluid chamber (176) which acts on the piston assembly (146) to shift the valve assembly (126) from the closed position to the open position and such that predetermined travel of the piston assembly (146) opens a bypass passageway (162) for the pressurized operating fluid to charge biasing fluid in the biasing fluid chamber (184), thereby enabling closure of the valve assembly (126) upon reducing annulus pressure by a predetermined amount.

Abstract: A downhole fluid flow control system having dynamic response to local well conditions. The system includes a tubing string operably positionable in a wellbore. Annular barriers are positioned between the tubing string and the wellbore to isolate first and second zones. A fluid flow control device is positioned within each zone. A flow tube that is operably associated with the fluid flow control device of the first zone is operable to establish communication between the second zone and the fluid flow control device in the first zone such that a differential pressure between the first zone and the second zone is operable to actuate the fluid flow control device of the first zone from a first operating configuration to a second operating configuration.

Abstract: The invention relates to a valve device that is used in oil and gas wells. The valve device has an external housing (1), where at least one inlet (4) in the housing (1) is connected to an outlet (5) through a longitudinal bore in the housing longitudinal direction. Between the valve device's inlet and outlet there is mounted a valve seat (2) in the bore, where a valve body (3) shuts off the connection between the inlet and outlet. The valve body's position is controlled by a support (20), connected with a pressure-sensitive bellows device (6) comprising an upper and a lower bellows element (7, 71). When the lower bellows element is compressed in the valve device's axial direction, the compression will cause the two bellows elements'impact elements to be moved relative each other in order to lift the valve body out of abutment with the valve seat.

Abstract: Downhole apparatus comprises a base pipe and a plurality of non-concentric pressure deformable chambers mounted externally on the pipe. The chambers may be inflated to increase the diameter of the apparatus and engage and support a surrounding bore wall.

Abstract: A safety valve system for downhole use in a wellbore comprises a safety valve comprising a sealable flow path; an annulus safety valve configured to provide fluid communication between a central flow path and an annular flow path; a landing nipple, wherein the landing nipple comprises ports configured to provide fluid communication between the annular flow path and the central flow path; and a cable passing through the sealable flow path, wherein the cable comprises a sealing mechanism and latch mechanism configured to engage the landing nipple.

Abstract: A bi-stable valve includes a first chamber having a first aperture and a second aperture, and a second chamber having a first aperture and a second aperture. The bi-stable valve also includes a shaft having a first valve member adjacent a first end of the shaft and a second valve member adjacent an opposite second end of the shaft. The shaft is movable between a first position, in which the first valve member closes off the second aperture of the first chamber and the second valve member closes off the second aperture of the second chamber to prevent fluid from passing through the second apertures of the first and second chambers, and a second position, in which the first valve member and the second valve member allow fluid to pass through the second aperture of the first chamber and the second aperture of the second chamber.

Abstract: A stage tool for reverse annular cementing a wellbore, comprising: a main body including a tubular wall with an outer surface and a longitudinal bore extending from a top end to a bottom end; a fluid port through the tubular wall providing fluidic access between the longitudinal bore and the outer surface; and a valve for controlling flow through the fluid port between the outer surface and the inner bore, the valve including a closure for the fluid port and a check valve for permitting one way flow through the fluid port in a direction from the outer surface to the inner bore, the check valve being normally inactive and only acting on fluid flows through the fluid port when activated. The stage tool may be run in closed and opened for cementing by hydraulic actuation of the valve. After sufficient cement has been introduced to the annulus, the stage tool fluid port can be closed to hold the cement in the annulus.