Abstract: A tool for selectively treating a wellbore with fluid that includes a tubing string having a sidewall defining an inner bore, the sidewall comprising a flow area having at least one fluid flow port that permits fluid flow through the sidewall. Fluid is prevented from flowing through the flow area when a closure is in a closed position. When in the open position, fluid flows through the flow area. An axial seal is connected to the closure to selectively close the inner bore against fluid pressure to apply the predetermined opening force to move the closure to the open position. A releasable connector connects the axial seal to the closure and a retrieval tool attachment releases the axial seal from the closure upon application of a predetermined release force by a retrieval tool.

Abstract: A control mechanism for use with a safety valve adapted to seal a wellbore is described. The control mechanism comprises at least one valve actuator for engaging with the safety valve, the at least one actuator being moveable, in use, between a valve open position in which the safety valve is open and a valve closed position, in which the safety valve is closed. The control mechanism further comprises biasing apparatus adapted to bias the at least one valve actuator to the valve closed position, wherein, in use, the at least one valve actuator extends from the safety valve up to a wellbore wellhead. In one described embodiment, the safety valve is moved between the open and closed positions by movement of the at least one valve actuator with respect to the wellbore.

Abstract: The present disclosure relates to a sleeve fracturing assembly including a composite sleeve and an opening tool. The composite sleeve and the opening tool can automatically engage with each other via teeth-shaped members arranged thereon so as to open the composite sleeve. The present disclosure further relates to a sleeve fracturing device, which includes a plurality of composite sleeves and opening tools, wherein each composite sleeve and opening tool can achieve unique engagement. The present disclosure still further relates to a method of using the sleeve fracturing device.

Abstract: A flapper valve includes a housing, a seat movably disposed at the housing at least between a first position and a second position, a flapper movably disposed at the seat at least between a seated position and an unseated position and at least one biasing member.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

Abstract: A tubular string testing system for use with a tubular string having a longitudinally extending flow passage can include a valve which selectively permits and prevents fluid communication between sections of the flow passage, a bypass passage which provides fluid communication between the sections of the flow passage when the valve is closed, and a filter which filters fluid that flows through the bypass passage. A method of testing a tubular string can include permitting fluid to flow through a bypass passage which connects sections of a flow passage extending longitudinally through the tubular string, a filter filtering the fluid which flows through the bypass passage, a valve of a tubular string testing system preventing flow of the fluid between the sections of the flow passage through the valve, and flow through the bypass passage being prevented in response to a predetermined pressure differential being created across the filter.

Abstract: The present invention regards a valve device for use with a down hole tool comprising at least a first fluid line and a return fluid line, the valve device comprises a first inlet and a first outlet forming a first flow path between them, and a second inlet and a second outlet forming a second flow path between them, at least one closure element for closing and or opening at least one of the flow paths. According to the invention there is at least one closure element together with the respective flow paths forms a first and second check valves, which in a first state prevents a fluid from flowing from the first outlet to the first inlet and a fluid from flowing from the second inlet to the second outlet. The invention also regards a method for operating a down hole valve device.

Abstract: A downhole tool comprising a nested sleeve moveable from a closed position to an open position following actuation of a fluid control device. The fluid control device may selectively permit fluid flow, and thus pressure communication, into the annular space to cause a differential pressure across the shifting sleeve, and thereby moving the shifting sleeve to an open position. A static plug seat is positioned in the tubing or casing upwell of the downhole tool. When the shifting sleeve is opened, fluid flow is established through the static plug seat, allowing a dissolvable or disintegrable ball or other plug to engage the plug seat, preventing fluid flow past the plug seat to the opened downhole tool, thereby permitting pressurization of the tubing or casing, such as for a pressure test. Disintegration of the ball allows fluid communication to be re-established with the downhole tool, permitting fluid to flow through the tubing for subsequent operations.

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: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density. A fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. The diverter can control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve. The fluid diverter can move in response to a change in the fluid to affect fluid flow patterns in a tubular, the change in flow pattern operating a valve assembly.

Abstract: A packer that includes a mandrel, primary and secondary opening seats attached to an interior of the mandrel, a landing seat attached to the interior of the mandrel, a packer element attached to an exterior of the mandrel, and a closing seat attached to the interior of the mandrel. The secondary opening seat may be between the primary opening seat and the landing seat, and the primary opening seat may be between the closing seat and the secondary opening seat. The primary opening seat engages an opening plug and moves from a first position covering an opening to a second position not covering the opening, and the secondary opening seat engages the primary opening seat and moves from a first position covering a port to a second position not covering the port.

Abstract: A technique enables protection of subsea wells. The technique employs a subsea test tree and associated control system to ensure control over the well in a variety of situations. The subsea test tree may be formed with an upper portion releasably coupled to a lower portion. The upper portion employs at least one upper shut-off valve, and the lower portion employs at least one lower shut-off valve to protect against unwanted release of fluids from either above or below the subsea test tree. The subsea test tree also is coupled with the control system in a manner which allows control to be exercised over the at least one upper shut-often valve and the at least one lower shut-off valve.

Abstract: Methods and devices for mixing a first fluid with a second fluid downhole include a chamber having a first end, a second end and an opening for fluid to flow there through. A top surface of a perforated piston is capable of contacting the second end and a top surface of a piston is capable of contacting a bottom surface of the perforated piston. The perforated piston is located at a first position within the chamber based upon characteristics of a first fluid. A first fluid delivery system supplies the first fluid and a second fluid delivery system supplies a second fluid to the chamber, wherein the second fluid is at a pressure that moves the piston approximate to the first end. An actuating device applies a force against the bottom surface of the piston to inject the fluids through channels of the perforated piston to produce spray droplets.

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 flapper for use as a component of a safety valve designed for deployment in a well bore having well bore fluids. The flapper includes a flapper body forming a flapper valve bore therethrough. The flapper body forms a groove proximate to the flapper bore. The flapper also includes a plunger member sized and configured to be received in the flapper valve bore. The plunger member includes a first end portion and a second end portion. Additionally, the flapper includes a leaf spring including a primary end portion and a secondary end portion, the primary end portion of the leaf spring detachably attached to the second end portion of the plunger member and unattached to the flapper body and the secondary end portion of the leaf spring being sized and configured to be received and retained in the groove and to bias the plunger member into the flapper valve bore.

Abstract: A mechanical counting device for actuating a plurality of output devices, the device comprising: linear indexing means adapted to count a plurality of actuating signals and to cause actuation of the output devices when a predetermined number of actuating signals for each output device has been received, wherein the mechanical counting device is adapted to cause actuation of a particular output device when a different predetermined number of actuating signals has been received such that the output devices are sequentially actuable.

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: A down-hole jet pumping apparatus and method for removing accumulated water in a small diameter well bore are described. Chosen fluids are pumped under high pressure from a surface pump through a 3-way valve into a tube disposed in a well bore. The jet pumping apparatus includes a down-hole accumulator connected to an eductor. The high-pressure fluid is stored in the accumulator and may be released to the surface reservoir by the control valve through the tube along with the fluid to be pumped drawn into the eductor. When the accumulator is exhausted, the control valve again directs high-pressure fluid from the surface pump to the accumulator until a chosen pressure is achieved in the accumulator. The fluid pressure in the accumulator is maintained using a gas-charged metal bellows. Hydraulically driven jet boosters are described for increasing the fluid pressure along the tube in deep wells.

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 method of servicing a subterranean formation comprising providing a first sleeve system comprising a first one or more ports and being transitionable from a first mode to a second mode and from the second mode to a third mode, and a second sleeve system comprising a second one or more ports and being transitionable from a first mode to a second mode and from the second mode to a third mode, wherein, in the first mode and the second mode, fluid communication via the one or more ports of the first or second sleeve system is restricted, and wherein, in the third mode, fluid may be communicated via the one or more ports of the first or second sleeve system, transitioning the first and second sleeve systems to the second mode, and allowing the first sleeve system to transition from the second mode to the third mode.

Abstract: A well tool having an actuator sleeve in a housing. The actuator sleeve has an internal shifting tool engaging profile. The tool has an actuator in the housing that is responsive to a remote signal to change from an unactuated state to an actuated state and shift the actuator sleeve from a first position to a second position. A collet in the housing is supported to couple the actuator sleeve to the actuator while the actuator changes from the unactuated state to the actuated state and is unsupported to allow the actuator sleeve to move relative to the actuator when the actuator is in the actuated state.

Abstract: A gate valve has a body, the body having a cavity and a flow passage intersecting the cavity. A seat is mounted to the body at the intersection of the flow passage and the cavity. A gate is installed at the cavity and has an engaging face that slidingly engages the seat while the gate is being moved between open and closed positions. The end faces between a seat pocket and the seat are hard-coated and smooth-finished to provide sealing when mated. The hardcoated pocket and seat sealing surfaces extend the life of the valve by eliminating the need for an elastomeric seal of limited life.

Abstract: An isolation valve can include a pivot connecting a closure member to an actuator member which displaces when the isolation valve is actuated between open and closed configurations, whereby the pivot displaces with the actuator member. Another isolation valve can include a pivot connecting a closure member to an actuator member which displaces when the isolation valve is actuated between open and closed configurations, and a profile formed in the isolation valve. The profile biases the closure member from an open position to a closed position when the isolation valve is actuated from the open configuration to the closed configuration. A method of actuating an isolation valve includes actuating the isolation valve between open and closed configurations, and wherein actuating the isolation valve comprises simultaneously displacing an actuator member, a closure member, and a pivot which pivotably connects the closure member to the actuator member.

Abstract: A mud pulser tool to be positioned into a downhole environment is disclosed. The mud pulser tool includes a control valve that is selectively opened to allow fluid to flow through the mud pulser tool or selectively closed to restrict the fluid flow, wherein the control valve is selectively opened or closed to produce a mud pulse signal transmitted through the fluid. The mud pulser tool also includes a sensor system to measure a pressure drop across the control valve. In one example, the mud pulser tool includes a control system to selectively open or close the control valve to adjust the pressure drop to produce a selected pressure drop across the control valve.

Abstract: A flow control assembly can be disposed in a wellbore and can include a membrane that can be perforated in response to a pressure, such as a setting pressure, from an inner area of a tubing. Subsequent to the membrane being perforated, fluid can be allowed to flow from an area external to the tubing to an area internal to the tubing. The membrane may remain closed during a packer setting operation and be perforated subsequent to the packer setting operation.

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: Disclosed are systems and methods of producing from multiple production zones with a single trip multi-zone completion system. One method includes arranging an outer completion string within an open hole section of a wellbore, the outer completion string having at least one sand screen disposed thereabout, extending a production tubing within the outer completion string, the production tubing having at least one interval control valve disposed thereon, communicably coupling the production tubing to the completion string at a crossover coupling having one or more control lines coupled thereto, actuating the at least one interval control valve to initiate production into the production tubing at the at least one interval control valve, and measuring one or more fluid and/or well environmental parameters external to the outer completion string with a surveillance line communicably coupled to one or more control lines at the crossover coupling.

Abstract: A completion assembly for operation in a subterranean well having multiple production zones. The completion assembly includes a lower completion assembly operably positionable in the well. The lower completion assembly includes first and second zonal isolation subassemblies. An upper completion assembly is operably positionable at least partially within the lower completion assembly to establish fluid communication between first and second fluid flow control modules, respectively, with the first and second zonal isolation subassemblies. A first communication medium having a connection between the upper and lower completion assemblies extends through the first and second zonal isolation subassemblies. A second communication medium is operably associated with the first and second fluid flow control modules. Data obtained by monitoring fluid from the production zones is carried by the first and second communication media and is used to control production through the first and second fluid flow control modules.

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 an interval control valve coupled to the at least one sand screen, a production tubing communicably coupled to the outer completion string at a crossover coupling, a control line extending external to the production tubing and being communicably coupled to the crossover coupling, and a surveillance line extending from the crossover coupling external to the outer completion string and interposing the at least one formation zone and the at least one sand screen, the surveillance line being communicably coupled to the interval control valve.

Abstract: A method of actuating multiple valves in a well can include applying a pressure cycle to the valves without causing actuation of any of the valves, and then simultaneously reducing pressure applied to the valves, thereby actuating the valves. Another method can include releasing a locking device of each valve which prevents actuation, and then reducing pressure applied to the valves, thereby actuating the valves. A valve can include a port which provides for fluid communication between an exterior and an interior of the valve, a closure member which selectively permits and prevents fluid flow through the port, the closure member permits flow through the port in response to a decrease in a pressure differential from the interior to the exterior of the valve, and a locking device which prevents displacement of the closure member, the locking device being released in response to mechanical force applied to the locking device.

Abstract: Disclosed are systems and methods for mechanically reclosing a hydraulically actuated sliding side door of a sleeve assembly. One sleeve assembly includes a housing defining one or more flow ports, a sliding sleeve arranged within the housing and movable between a closed position and an open position and back to the closed position, wherein, when in the closed position, the outer sleeve occludes the one or more flow ports, and, when in the open position, the one or more flow ports are exposed. A piston is movably arranged within a piston bore defined in the housing, and a locking mechanism is arranged within the piston bore and configured to engage the piston with the sliding sleeve, thereby allowing the piston to move the sliding sleeve to the open position.

Abstract: A technique includes deploying an untethered object though a passageway of a string in a well; and sensing a property of an environment of the string, an electromagnetic coupling or a pressure as the object is being communicated through the passageway. The technique includes selectively autonomously operating the untethered object in response to the sensing.

Abstract: A downhole tool comprising an inner sleeve with a plurality of sleeve ports and a housing positioned radially outwardly of the inner sleeve and having a plurality of housing ports, with the housing and inner sleeve partially defining a space radially therebetween. The space is occupied by a shifting sleeve. A fluid path extends between the interior flowpath of the tool and the space. A fluid control device, such as a burst disk, occupies at least portion of the fluid path. In one state, the shifting sleeve is in a first position between the housing ports and the sleeve ports to prevent fluid flow between the interior flowpath and exterior of the tool. The fluid control device may selectively permit fluid flow, and thus pressure communication, into the annular space to cause a differential pressure across the shifting sleeve.

Abstract: Presented herein is a system, method, and assembly for reducing pressure fluctuations in an oilfield pumping system. The pressure fluctuation dampening assembly includes a junction, a dampening chamber, and a supply of a compressible medium. The compressible medium is supplied so as to form an interface between the fluid and the compressible medium such that a pressure fluctuation of fluid passing through the junction is reduced.

Abstract: A circulation valve includes: an outer tubular sleeve telescopically mounted at its end over a tubular mandrel; a fluid passage between sleeve and the mandrel, the fluid passage providing fluid communication between the inner bore of the valve and its outer surface; a dual knife seal assembly to control flow out of the fluid flow path through the fluid passage, the dual knife seal assembly including a first annular knife seal edge and land that seal up when the sleeve and mandrel are in a fully axially compressed position and a second annular knife seal edge and land that seal up when the sleeve and mandrel are pulled into a fully in tension position; and, a J-slot position indexing mechanism including a slot and a key to guide movement of the sleeve and the mandrel between the fully in tension position and the fully compressed position. The circulation valve is employed in a wellbore treatment assembly and methods.

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

Abstract: A method can include selecting a ratio of a first effective cross-sectional area of a first component of a gas lift valve to a second effective cross-sectional area of a second component of the gas lift valve; charging a chamber of the gas lift valve; and positioning the gas lift valve in a pocket to expose the gas lift valve to a tubing pressure and a casing pressure, where transitioning of the gas lift valve from a closed state to an open state depends at least in part on the selected ratio. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: Disclosed herein is a wellbore servicing system, comprising a tubular string, a first sleeve system incorporated within the tubular string, the first sleeve system comprising a first sliding sleeve at least partially carried within a first ported case, the first sleeve system being selectively restricted from movement relative to the first ported case by a first restrictor while the first restrictor is enabled, and a first delay system configured to selectively restrict movement of the first sliding sleeve relative to the first ported case while the first restrictor is disabled; a second sleeve system incorporated within the tubular string, the second sleeve system comprising a second sliding sleeve at least partially carried within a second ported case, the second sleeve system being selectively restricted from movement relative to the second ported case by a second restrictor while the second restrictor is enabled.

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

Abstract: Plug element systems comprise a tubular member having at least two seats. An eccentrically-shaped plug member comprises an upper end portion and a lower end portion. The upper end portion comprises an upper end diameter can be less than, greater than, or equal to a lower end portion diameter of the lower end portion. The eccentric shape of the plug member permits it to pass through a first seat and land on a second seat comprising a second seat length where both the first seat and the second seat comprise substantially equal inner seat diameters.

Abstract: A wellbore system comprising a casing, and a pressure testing valve incorporated within the casing and comprising a sleeve positioned within a housing and transitional from a first to a second position, and from the second to a third position, wherein, when the sleeve is in the first and second positions, the sleeve blocks a route of fluid communication via one or more housing ports and, when the sleeve is in the third position the sleeve does not block fluid communication, wherein the pressure testing valve is configured such that a force in the direction of the second position to the sleeve causes the sleeve to transition to the second position, and wherein the pressure testing valve is configured such that a reduction of the force in the direction of the second position to the sleeve causes the sleeve to transition to the third position.

Abstract: According to one embodiment, a rotationally activated downhole well valve for connection in a tubing string is disclosed that can be repeatedly opened and closed selectively to place the tubing string in communication with the annulus. The valve is moved between the closed position and the open position by rotating the string in the first direction. In another embodiment, the valve is opened and closed by rotating the string in the first direction and is reset in the closed position by lifting and lowering the tubing string.

Abstract: A method of actuating multiple valves in a well can include applying a pressure cycle to the valves without causing actuation of any of the valves, and then simultaneously reducing pressure applied to the valves, thereby actuating the valves. Another method can include releasing a locking device of each valve which prevents actuation, and then reducing pressure applied to the valves, thereby actuating the valves. A valve can include a port which provides for fluid communication between an exterior and an interior of the valve, a closure member which selectively permits and prevents fluid flow through the port, the closure member permits flow through the port in response to a decrease in a pressure differential from the interior to the exterior of the valve, and a locking device which prevents displacement of the closure member, the locking device being released in response to mechanical force applied to the locking device.

Abstract: A linear motor activator for a downhole safety valve including a permanent magnet carrier; a plurality of permanent magnets mounted to the permanent magnet carrier; a coil carrier disposed in magnetic field proximity to the permanent magnet carrier; and a plurality of coils mounted to the coil carrier, one of the permanent magnet carrier and the coil carrier being movable relative to the other of the permanent magnet carrier and coil carrier, and being connected to a component of a downhole safety valve and method.

Abstract: A method for fracturing a wellbore in a formation, including positioning one or more bidirectional rotary sleeves on tubular members into the wellbore; engaging a unidirectional rotary source in a first position with a first bidirectional rotary sleeve of the one or more bidirectional rotary sleeves; operating the unidirectional rotary source to rotate the first bidirectional rotary sleeve in a first rotational direction to open at least one port in the first bidirectional rotary sleeve for providing an open fluid pathway between the first bidirectional rotary sleeve and the formation; pumping fluid through the tubular members and through the opened port to fracture the formation; engaging the unidirectional rotary source in a second position with the first bidirectional rotary sleeve; and operating the unidirectional rotary source to rotate first bidirectional rotary sleeve in a second rotational direction to close the at least one port in the first bidirectional rotary sleeve.

Abstract: A method of forming a wellbore is provided that in one embodiment includes conveying an inner string and an outer string downhole; attaching the inner string to the outer string at a first location and forming the wellbore; and attaching the inner string to the outer string at a second location uphole of the first location and cementing an annulus between the outer string and the wellbore, without retrieving the inner string from the wellbore.

Abstract: Apparatus and methods for completing, treating, and/or producing a wellbore are provided. The apparatus can include a tubular body defining an inner bore, one or more injection inflow control devices, and one or more production inflow control devices. The one or more injection inflow control devices can include one or more first check valves in fluid communication with the inner bore, with each first check valve being configured to allow fluid to flow therethrough from the inner bore to a region of the wellbore, and to substantially block a reverse fluid flow therethrough. The one or more production inflow control devices can include one or more second check valves coupled to the tubular body, each second check valve being configured to allow fluid to flow therethrough from the wellbore to the inner bore and to substantially block a reverse fluid flow therethrough.

Abstract: A flow control device comprises a fluid pathway configured to provide fluid communication between an exterior of a wellbore tubular and an interior of the wellbore tubular, a flow restriction disposed in a fluid pathway, a flow blockage disposed in the fluid pathway, and a retaining member configured to maintain the flow blockage within the fluid pathway and allow access to the flow blockage within the fluid pathway. The flow blockage substantially prevents a fluid flow through the fluid pathway.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

Abstract: A downhole flow device has a sliding and ported sleeves. A seal has a first component on the sliding sleeve and a second component on the ported sleeve. These components engage one another to seal flow through the ports in the ported sleeve. The components move apart to allow fluid flow through the ports. The components are protected from abrasion and flow by virtue of the seal's structure and how it is opened. The sliding sleeve moves hydraulically along an axis of the ported sleeve to reveal successive ports defined along the sleeve's axis. Operation of the device and the seal address both erosion and damage from differential pressure problems. Thus, the seal prevent damage when unloading a differential pressure across it, and abrasive flow does not have the opportunity to impinge on the sealing surfaces to cause erosion.