Abstract: An apparatus and method for selectably opening a valve body having a central passage and a plurality of apertures therethrough. The apparatus comprises a sleeve slidably located within the central passage of the valve body adapted to selectably cover or uncover the apertures. The apparatus further comprises a shifting tool slidably locatable within the sleeve having at least one sleeve engaging member selectably extendable therefrom in parallel to a central axis thereto engagable upon the sleeve wherein the shifting tool is moveable. The method comprises positioning the shifting tool within the sleeve in a first or second position, extending the sleeve engaging members from the shifting tool in parallel to a central axis of the shifting tool into engagement upon the sleeve, and axially moving the shifting tool and the sleeve to the other of the first or second positions.

Abstract: A technique provides a system and methodology for detecting and monitoring erosion in various environments, including downhole environments. A tracer element is located in a component such that sufficient erosion of the component due to fluid flow exposes the tracer element. A monitoring system is disposed for cooperation with the tracer element such that exposure of the tracer element is detected by the monitoring system. The monitoring system outputs appropriate data indicative of the erosion to enable adjustments to the fluid flow.

Abstract: A borehole cutting assembly for directional cutting in a borehole, the assembly comprising an input pipe and a cutting head rotatably mounted on the input pipe such that the orientation of the cutting head relative to the input pipe can be altered to determine the direction of cutting of the borehole. A cutting tool and cutting tool motor are mounted on the cutting head to enable the cutting tool to be rotatably driven relative to the cutting head so that when the cutting tool is loaded in use the cutting head is subject to a tool reaction torque that acts to rotate the cutting head to change the orientation of the cutting head. The cutting head is rotatably mounted on the input pipe by a controlled torque coupling comprising a progressive cavity pump having a rotor and a stator each provided with drive formations arranged to define a fluid flow cavity therebetween. Rotation of the rotor relative to the stator forces fluid flow through the cavity to counteract the tool reaction torque.

Abstract: A method of stimulating a subterranean formation using a tubular member with one or more burst disks therein.

Abstract: A single trip multizone time progressive well treating method and apparatus that provides a means to progressively stimulate individual zones through a cased or open hole well bore. This system allows the operator to use pre-set timing devices to progressively treat each zone up the hole. At each zone the system automatically opens a sliding sleeve and closes a frangible flapper, at a pre-selected point in time. An adjustable preset timing device is installed in each zone to allow preplanned continual frac operations for all zones. The apparatus is present as a “Frac Module” that can consist of three major components, a packer, a timing pressure device, and a sliding sleeve/isolation device. A hydraulic packer may be removed or replaced with a swellable type packer.

Abstract: A fluid actuated downhole tool for inducing movement of a downhole apparatus is described. The tool comprises a body for coupling to downhole apparatus, the body being adapted to accommodate now of fluid therethrough and including a flow-modifying arrangement for modifying the flow of fluid through the body. The flow-modifying arrangement is configurable in an inactive configuration and in an active configuration. The fluid activated tool is selectively operated from the surface by varying an operating condition which causes the flow through the tool to either bypass or flow through the flow-modifying arrangement to induce movement of the downhole apparatus.

Abstract: A wellbore completion is disclosed. The wellbore completion comprises a casing assembly comprising a plurality of casing lengths. At least one collar is positioned so as to couple the casing lengths. The at least one collar comprises a tubular body having an inner flow path and at least one fracture port configured to provide fluid communication between an outer surface of the collar and the inner flow path. A length of coiled tubing can be positioned in the casing assembly. The coiled tubing comprises an inner flow path, wherein an annulus is formed between the coiled tubing and the casing assembly. A bottom hole assembly is coupled to the coiled tubing. The bottom hole assembly comprises a fracturing aperture configured to provide fluid communication between the inner flow path of the coiled tubing and the annulus. A packer can be positioned to allow contact with the at least one collar when the packer is expanded.

Abstract: Systems and methods for the production of hydrocarbons from a wellbore. One or more combination tools can be disposed along a casing string inserted into a wellbore. Each combination tool can contain a body having a bore formed therethrough; a sliding sleeve at least partially disposed in the body; one or more openings disposed about the body at a first end thereof; and a valve assembly and a valve seat assembly at least partially disposed within the bore at a second end thereof. While initially permitting free bi-directional flow of fluids within the casing string, the sliding sleeve within each combination tool can be manipulated to close the valve within the tool, thus permitting pressure testing of the casing string. The sliding sleeve can be further manipulated to open the one or more openings thereby permitting hydraulic fracturing and production of a hydrocarbon zone surrounding the combination tool.

Abstract: The present invention relates to a method for regulating a pressure in a hydraulic system for operating at least one actuator in a subsea installation, having a fluid supply line (102) connected to a source of pressurized fluid (101) at a remote location delivering fluid at a constant pressure to the subsea installation, comprising first and second control valves (103, 105) controlled by an electronic control unit (107), and at least one pressure sensor (106) and an accumulator (104) arranged between the first and second control valve (103, 105), where the pressure in the fluid supply line (102?) to the actuator is regulated by regulating the pressure in the accumulator (104) by adding fluid from the source of pressurized fluid (101) through the first control valve (103) if the pressure is too low or releasing pressure through the second control valve (105) to a fluid return line (120) if the pressure is too high and thereby establishing the desired pressure for operating the actuator.

Abstract: A lubricator valve assembly adapted for connection in a pipe string for use in a well includes a tubular valve body having a bore formed longitudinally therethrough; a valve seat connected to the valve body and in communication with the bore; a valve element mounted in the bore and rotatable with respect to the valve seat between positions opening and closing the bore; an operator in connection between the valve element and a hydraulic control system, the operator moving the valve element between the open and close bore positions in response to the hydraulic control system; and a system for opening the valve element upon failure of the hydraulic system.

Abstract: A hydraulic control system for a sub-surface safety valve has control lines in hydraulic communication with the valve. A first control line communicates hydraulic pressure to actuate the valve, while the other control line communicates hydraulic pressure to compensate for hydrostatic pressure associated with the first control line. A regulator regulates hydraulic communication between the two control lines. The regulator prevents fluid communication from the first to the balance control line as long as integrity of the second line is maintained. When the second line fails, the safety valve can fail in the open position. In this case, the regulator permits hydraulic pressure to bleed from the first line to the second line. This allows the safety valve to then fail in a closed condition and allows the second line to potentially be recharged if its integrity is regained.

Abstract: A fill-up and circulation tool includes a mandrel; a packer assembly is disposed around the mandrel; and a valve assembly connected to the mandrel, wherein the valve assembly is configured to selectively control fluid flow into the tool and out of the tool.

Abstract: A technique utilizes a simplified valve system structure to facilitate actuation of tools, such as actuating pads in a steering section of a wellbore drilling assembly. A valve system may comprise a bi-stable actuator which controls two double-stage valves. Each of the double-stage valves is able to perform both charging and dumping functions which facilitate use of the valve system in a variety of downhole applications. In drilling applications, a single valve system is able to operate a plurality of actuating pads.

Abstract: An apparatus controls flow of a fluid between a wellbore tubular and a wellbore using a particulate control device configured to be disposed in the wellbore and at least two parallel and directionally opposing flow paths in fluid communication with the particulate control device.

Abstract: A blowout preventer for use in the oil and gas industry having a single modified, dual-acting hydraulic operator per door, comprising a reconfigured adapter. The reconfigured adapter comprises a body having a longitudinal bore, a plurality of hydraulic fluid passageways therethrough, and is slidably received by the blowout preventer.

Abstract: A crossover tool has an internal sleeve rotatably positioned within an external sleeve, and each of the sleeves has ports alignable with ports on the other sleeve. After deploying the crossover tool downhole and diverting fluid flow below the tool, fluid flow communicated into the internal sleeve tends to rotate it relative to the external sleeve until the ports are substantially aligned so that wear to the components is substantially reduced. The ports themselves may facilitate the rotation and alignment. For example, ports on the internal sleeve may produce tangentially exiting fluid flow. Alternatively, an additional outlet may be defined in the internal sleeve and eccentrically located to its rotation axis. Furthermore, an internal sleeve or insert may partially block fluid flow through the ports to allow greater fluid flow through the additional outlet to enhance rotation of the internal sleeve.

Abstract: A variable flow resistance system for use in a subterranean well can include a flow chamber through which a fluid composition flows, the chamber having at least one inlet, an outlet, and at least one structure spirally oriented relative to the outlet, whereby the structure induces spiral flow of the fluid composition about the outlet. Another variable flow resistance system for use in a subterranean well can include a flow chamber including an outlet, at least one structure which induces spiral flow of a fluid composition about the outlet, and at least one other structure which impedes a change in direction of flow of the fluid composition radially toward the outlet.

Abstract: A safety valve system includes a safety valve having an actuator and a line connected to the actuator. The safety valve is operable by opening the line in the well, with the line being free of any connection to a surface control system. Another safety valve system includes multiple safety valves. An actuator of each safety valve is connected to an actuator of another safety valve via a line. A biasing force in each of the actuators is operative to close the respective one of the safety valves in response to opening of the line. The biasing force is produced at least in part by hydrostatic pressure in a well.

Abstract: A system for regulating the flow of fluid through a progressing cavity motor includes an annulus restriction (22) for restricting flow through the annulus passageway, and an annular biasing member (24) for biasing the annular restriction toward a closed position. Fluid flow in the annulus passageway creates an opening force on the annulus restriction. A central restriction (28) within the motor provides a restricted flow through the motor. A central biasing member (26) biases the central restriction toward an open position, with fluid flow in a central passageway exerting a closing force on the central restriction.

Abstract: An apparatus for controlling the flow of downhole fluids, the apparatus comprising: 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; a flow control device for controlling the flow of fluids through the port and 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; 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; a locking device to lock the configuration of the flow control device; and an unlocking mechanism to unlock the locking device and to permit the actuator mechanism to change the configuration of the flow control device.

Abstract: Phase-controlled well flow control. A well system includes a flow control device which regulates flow of a fluid in the well system, the flow control device being responsive to both pressure and temperature in the well system to regulate flow of the fluid. A flow control device includes a flow regulator for regulating flow of a fluid through the flow control device, and an actuator which is operative to actuate the flow regulator in response to a predetermined relationship between a phase of the fluid and both pressure and temperature exposed to the actuator. A method of controlling a phase change of a fluid in a well system includes the steps of: flowing the fluid through a flow control device in the well system; and adjusting the flow control device in response to both pressure and temperature in the well system.

Abstract: A circulation control valve can include first and second valve devices and at least one opening which provides fluid communication between an interior longitudinal flow passage and an exterior of the valve. Fluid communication can be provided through each of the first and second valve devices in response to application of a respective one of first and second pressure differentials applied across the corresponding valve device via the interior longitudinal flow passage. Fluid communication in any direction through the opening may be permitted in response to application of the first pressure differential to the first valve device. Fluid communication through the opening may be prevented in response to application of the second pressure differential to the second valve device.

Abstract: A method of actuating a well tool utilizing first and second pressure sources includes the steps of: placing an actuator chamber in communication with the first pressure source, thereby displacing a piston from a first position to a second position; and then placing another chamber in communication with the second pressure source, thereby displacing the piston to a third position. A multi-position actuator includes an operating member which displaces to operate a well tool, a first position of the operating member corresponding to a pressure source being in communication with a chamber and another pressure source being in communication with another chamber, a second position of the operating member corresponding to the same pressure source being in communication with both of the chambers, and a third position of the operating member corresponding to the pressure sources being connected to the chambers oppositely to that of the first position.

Abstract: A gas lift barrier valve mandrel assembly includes a longitudinally extending tubular member that defines a production conduit and has a central longitudinal axis. A side pocket mandrel has a first pocket for accepting a gas lift barrier valve and has a first central axis. The side pocket mandrel has a second pocket for accepting a gas lift barrier valve and has a second central axis. The central axis of the production conduit, first axis and second axis are non-coaxial and are parallel to one another. A first passage fluidly connects an outside of the mandrel to an inside of the first pocket. A second passage fluidly connects the inside of the first pocket to an inside of the second pocket. A third passage fluidly connects the inside of the second pocket to the production conduit. A fourth passage connects the first pocket to the production conduit and allows insertion of a gas lift barrier into the first pocket.

Abstract: A switching apparatus, system, and method configured to operate at least a dual line downhole tool via a single pressure source are provided. The switching apparatus may comprise a housing configured to contain a switching piston actuated by a fluid pressure source. The apparatus may further contain a switching valve comprising a first and second coupling passageway coupled to a switching valve housing comprising four ports. The switching piston may actuate the switching valve, alternating the coupling between a first configuration in which the four ports are communicatively coupled into two sets of ports and a second configuration in which the four ports are communicatively coupled into an alternate two sets of ports. The first configuration may configure the fluid pressure source to actuate the downhole tool in a first manner and the second configuration may configure the fluid pressure source to actuate the downhole tool in a second manner.

Abstract: A downhole tool for providing a pressure differential between sub-assemblies, the downhole tool including an elongated body, a tubular assembly disposed within the elongated body, the tubular assembly including a central flowbore with an inner diameter and a central longitudinal axis, a camming device, an actuator member located below the tubular assembly, having a dual-bore configuration, the actuator member including a first bore, a second bore, and a concave seating surface formed within the second bore for receiving a obstructing device, wherein the first bore and the second bore are oriented 90 degrees to one another so that fluid may flow through the actuator while it is in either a first or a second position, and a stationary sleeve concentrically disposed between the actuator member and the elongated body is disclosed.

Abstract: A Blowout Preventer comprising a housing, one or more magnets and a magnetic fluid is described. More particularly, a Magnetorheological Blowout Preventer with a Magnetorheological Ram Head that conforms to virtually any cross sectional shape is described with ultra-reliable termination of natural gas and/or oil effluent flow resulting.

Abstract: A down hole pressure isolation tool is placed in a pipe string and includes a pair of pressure discs having one side that is highly resistant to applied pressure and one side that ruptures when much lower pressures are applied to it. The weak sides of the pressure discs face each other. Rather than rupturing the discs by dropping a go-devil into the well, in some embodiments, a first of the discs is ruptured or broken by the application of fluid pressure from the well head or surface. Formation pressure is then used, in different ways according to the different embodiments, to rupture the remaining disc. In another embodiment, a gas generating assembly located between the discs is actuated to produce enough pressure to rupture the discs.

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. In other embodiments, the fluid diverter moves 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 retaining assembly for a cylindrical member and support sleeve in the bore of a component of a DTH. The cylindrical member and support sleeve may, for example, be a foot valve assembly for insertion into a counter bore in a bit. The cylindrical member has a cylindrical member rigidity and at least a portion of the support sleeve has a rigidity greater than the cylindrical member rigidity. A gap is provided between the sleeve and the component bore of the DTH. The cylindrical member deforms in the gap, resulting in the cylindrical member being fixedly sandwiched between the support sleeve and the component bore.

Abstract: A pressurization tool comprises a body for connection to a tubular by box, and pin, and providing for flow of fluid by way of a throughbore of varying cross-section to form chambers. A lower chamber accommodates a spring that contacts a shoulder providing a reaction surface for compression of the spring under applied force. The chamber merges into intermediate chamber that accommodates a movable index sleeve that cooperates with an index pin inserted through the wall of the tool body. Associated with the upper part of the index sleeve is a valve seat assembly, positioned to abut the index sleeve and moveable therewith, said valve seat assembly being configured to receive a plug or ball, and in one unpressurised configuration, is located in a wider chamber that permits fluid flow around the assembly.

Abstract: A float valve with upper and lower valve bodies having axial flow there through and valve member having angular trailing edges at a swept back angle for providing a seating surface and a stem axially extending from the valve member. The stem having multiple supporting surfaces arranged cylindrically and having a biasing member fitted there about. The upper valve body having an internal annular seat for seating with the valve member seating surface and external seals for engaging oilfield tubulars and threaded on one end. The lower valve body having a central internal support member for support of the valve member stem for axial movement and threaded on one end for joining the upper valve body and compressing the biasing member to engage the seating surfaces of the valve member and internal annular seat of the upper valve body for engagement and disengagement in response to fluid flow pressure.

Abstract: A selectively communicatable hydraulic nipple is provided which includes an upper and lower communications component adapted to communicate with tools landed inside the hydraulic nipple. Each communications component communicates with a control line used by the hydraulic nipple. An operator is allowed to selectively communicate with tools landed inside the nipple via the upper and lower communications components via the nipple control line. As a result, should the TRSCSSV control line loose integrity, the operator has the option of utilizing the nipple control line to continue oil and gas production without the need for well modifications. Alternatively, an operator could land a chemical injection tool, with an injection string suspended therefrom, in the nipple and inject chemicals into the well via the nipple control line.

Abstract: Apparatus and method for a providing a completion assembly for running at an end of a completion string which provides a remotely operable tubing mounted valve used to control the flow of fluids through the tubing in hostile well conditions. The tubing mounted completion assembly has a tubular body for connection in the string below a production packer with a through bore from a first inlet and a first outlet coaxially aligned with the string; a downhole electronic actuating mechanism, a downhole hydraulic pump and a hydraulically operated ball valve member. The actuating mechanism operates the hydraulic pump to provide a hydraulic control line to control movement the valve member from a first position, where the member is open and a through bore is created between the inlet and outlet of the assembly, to a second position, where the valve seals the throughbore and, finally, back to the first position.

Abstract: The present invention relates to a device for transmitting fluid from a subsea producing module (8) to a subsea receiving module (9) comprising a choke valve (3) in a main flowpath (7) of the fluid. A bypass line (2) is arranged in parallel to the choke valve (3) and the bypass line (2) is connected to the main flowpath (7) by a bypass connection (1).

Abstract: A gas lift valve assembly includes a housing that includes a first passageway that is substantially concentric with the central passageway of a string to communicate well fluid and a second passageway that is eccentrically disposed with respect to the central passageway to communicate a second fluid to lift the well fluid. The gas lift valve assembly includes a valve that is disposed in the second passageway and includes a ball valve to regulate communication of the second fluid.

Abstract: An apparatus for use downhole is disclosed that, in one configuration includes a downhole tool configured to operate in an active position and an inactive position and an actuation device, which may include a control unit. The apparatus includes a telemetry unit that sends a first pattern recognition signal to the control unit to move the tool into the active position and a second pattern recognition signal to move the tool into the inactive position. The apparatus may be used for drilling a subterranean formation and include a tubular body and one or more extendable features, each positionally coupled to a track of the tubular body, and a drilling fluid flow path extending through a bore of the tubular body for conducting drilling fluid therethrough. A push sleeve is disposed within the tubular body and coupled to the one or more features.

Abstract: A control mechanism for a downhole tool including a mandrel having a throughbore, at least one activation port, and at least one bypass port, a first sleeve detachably mounted within the throughbore at a first position and moveable to a second position, the first sleeve having a first seat, and a second sleeve detachably mounted within the throughbore at a third position located axially above the first position and moveable to a fourth position, the second sleeve having a second seat. A method of hydraulically actuating and deactuating a downhole tool, the method including disposing the downhole tool and a control mechanism in a well.

Abstract: An apparatus for controlling fluid flow into a tubular includes an in-flow control device having a plurality of flow paths; and a reactive media disposed in each of the flow paths. The reactive media may change permeability by interacting with a selected fluid such as water. Two or more of the flow paths may be hydraulically parallel. The reactive media may include a Relative Permeability Modifier. An associated method may include conveying the fluid via a plurality of flow paths; and controlling a resistance to flow in plurality of flow paths using a reactive media disposed in each of the flow paths. An associated system may include a wellbore tubular; an in-flow control device; a hydraulic circuit formed in the in-flow control device; and a reactive media disposed in the hydraulic circuit, the reactive media may change permeability by interacting with a selected fluid.

Abstract: A wellbore apparatus includes a connector sub assembly having a body, the body having a first end adapted to couple to a first perforating sub component and a second, axially opposed end adapted to couple to a second perforating sub component. The connector sub body defines a cavity proximate the second end of the connector sub body; and a flow path in fluid communication with the cavity and a location exterior to the wellbore apparatus. The apparatus includes a valve residing in the flow path and actuatable to block or allow fluid flow from the cavity, through the flow path, to the location exterior to the wellbore apparatus.

Abstract: A tubular actuating system includes a tubular, a plurality of same plugs runnable within the tubular, an actuator disposed within the tubular, and a seatable member disposed at the actuator configured to be respositionable relative to the actuator between an unseated position and a seated position upon passage of at least one of the plurality of same plugs.

Abstract: The invention relates to 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. Also provided are a switchable flow mechanism and a method of operating one or more downhole devices from a downhole located hydraulic control tool.

Abstract: A downhole device used to divert fluid flow out of a work string into an annulus. The downhole device is activated by the movement of a plurality of pistons within the downhole device. Fluid flow through a restriction of the downhole device creates an increase in fluid pressure causing the movement of the pistons. The pistons move a flow tube between various locations within the device. In one location, the flow tube prevents fluid flow to the annulus while in another location the flow tube allows fluid flow to be diverted into the annulus. The downhole device may include a locating sleeve having a continuous j-track allowing the flow tube to be selectively retained at the various locations within the downhole device. Fluid flow through the downhole is used to cycle the device between diverting fluid flow to the annulus and forcing fluid flow down the work string.

Abstract: A bypass device for bypassing a hydraulic piston in a wellbore with an outer tubular body. The outer tubular body can have a fluid control manifold. The fluid control manifold can have two control paths, two high pressure fluid paths, and two valves connecting with two high pressure fluid connecting paths. An inner tubular body can be disposed within the outer tubular body, and a piston chamber can be disposed between the inner tubular body and the outer tubular body. The piston chamber can include two piston chamber sections separated by a hydraulic piston.

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: A method for reducing the number of control lines needed to control a plurality of downhole devices including supplying a first control line in operable communication with a plurality of devices, the plurality of devices including at least one group of devices; supplying a second control line in operable communication with said at least one group of devices; and actuating each device of the plurality of devices in said at least one group of devices simultaneously in response to a pressure event.

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: A screen section has a valve assembly to control flow through it. The valve is open and has a closure spring held compressed by a shape memory material that responds to the presence of a specific well fluid or fluids so that its property changes to allow the spring to deliver the stored potential energy to the valve member to close it when the specific well fluid or fluids are detected. The preferred material is a shape memory polymer that, for example, is sensitive to the presence of water or methane and gets softer to release the potential energy source to operate the downhole tool.

Abstract: Casing valves for selective well stimulation and control. A well system includes at least one valve interconnected in a casing string operable via at least one line external to the casing string to selectively control fluid flow between an exterior and interior of the casing string, and the casing string, valve and line being cemented in a wellbore. A method of selectively stimulating a subterranean formation includes: positioning a casing string in a wellbore, the casing string including spaced apart valves operable via a line to selectively control fluid flow between an interior and exterior of the casing string; and for each of multiple intervals of the formation in sequence, stimulating the interval by opening a corresponding one of the valves, closing the remainder of the valves, and flowing a stimulation fluid from the casing string into the interval.

Abstract: An apparatus for performing a wellbore operation, such as a gravel packing, includes a tool body, a flow passage formed in the tool body, the flow passage connecting a first space with a second space; and a flow control device positioned along the flow space. The flow control device may include a valve element configured to allow uni-directional; and a flow control element configured to allow flow in bi-directional flow. The valve element and the flow control element may be arranged to form a split flow path between the first space and the second space.