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

Abstract: A subsurface safety valve system for a wellbore within a subterranean formation is described. The system can include a power source that generates power, and a delivery system disposed within the wellbore and electrically coupled to the power source. The system can also include at least one safety valve disposed within the wellbore and electrically coupled to the delivery system, where the at least one safety valve remains open while the at least one safety valve receives the power from the delivery system, and where the at least one safety valve closes when the at least one safety valve stops receiving power from the delivery system. The system can further include production tubing mechanically coupled to a distal end of the at least one safety valve, where the at least one safety valve shuts in a cavity within production tubing when the at least one safety valve closes.

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 wireless actuation system comprises a transmitter, an actuation system comprising a receiving antenna, and one or more sliding members transitional from a first position to a second position. The transmitter is configured to transmit an electromagnetic signal, and the sliding member prevents a route of fluid communication via one or more ports of a housing when the sliding member is in the first position. The sliding member allows fluid communication via the one or more ports of the housing when the sliding member is in the second position, and the actuation system is configured to allow the sliding member to transition from the first position to the second position in response to recognition of the electromagnetic signal by the receiving antenna.

Abstract: A method of producing liquid hydrocarbons from a subterranean formation can include flowing the liquid hydrocarbons from the formation through at least one valve, and increasingly restricting flow through the valve in response to pressure and temperature in the formation approaching a bubble point curve from a liquid phase side thereof. A method of producing gaseous hydrocarbons from a subterranean formation can include flowing the gaseous hydrocarbons from the formation through at least one valve, and increasingly restricting flow through the valve in response to pressure and temperature in the formation approaching a hydrocarbon gas condensate saturation curve from a gaseous phase side thereof.

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

Abstract: A containment valve assembly using the upcoming pressures to control the flow of oil/gas through a riser pipe with a stop flow plug positioned within the valve housing that has an outer surface shaped to fit within and against the riser pipe, and an inner socket cavity having a conical nose receiver portion with a relief vent allowing the oil/gas to escape through the valve assembly, when desired. The stop flow plug is shaped to fit within the inner socket cavity and moves between an open position and a closed position, wherein the stop flow plug fits securely against the conical nose receiver portion, sealing the relief vent. At the top of the valve, a nut will lock the stop flow plug to the close out plate for additional stoppage. A second embodiment adds a heavy duty insert to supplement the sealing pressure, when needed. Electronic monitors convey data remotely.

Abstract: A valve system for use in a wellbore includes a side pocket mandrel and one or more well tools, where the side pocket mandrel includes an elongated body section provided with a connector at its ends, the elongated body section being provided with a substantially fully open main bore for alignment with the well tubing and an offset side pocket bore. At least one through opening is provided in the side pocket mandrel, leading into the side pocket bore, and at least one through opening is provided in the internal wall, leading into the main bore, where the at least two openings are in fluid communication through the side pocket bore, in which side pocket bore at least two valves are arranged in series to form a double fluid barrier between the main bore and an outside of the pocket mandrel, the at least two valves being independently retrievable through at least one installation opening arranged in the internal wall of the side pocket mandrel.

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: A downhole circulation sub or valve includes a tubular housing with an outer port and a valve piston slidably disposed in the housing. A primary fluid flow path extends through an inner flow bore of the housing and valve piston. In a first position, the valve piston isolates the outer port to prevent fluid communication between the inner flow bore and a well bore annulus. In a second position, the valve piston is moved to obstruct the inner flow bore and expose the outer port to the inner flow bore and allow fluid communication between the inner flow bore and the well bore annulus. An indexing mechanism is coupled between the housing and the valve piston to guide the valve piston between the first and second positions. The indexing mechanism may include a rotatable component.

Abstract: Apparatus and methods are described for autonomously controlling fluid flow in a tubular in a wellbore. A fluid is flowed through an inlet passageway into a biasing mechanism. A fluid flow distribution is established across the biasing mechanism. The fluid flow distribution is altered in response to a change in the fluid characteristic over time. In response, fluid flow through a downstream sticky switch assembly is altered, thereby altering fluid flow patterns in a downstream vortex assembly. The method “selects” based on a fluid characteristic, such as viscosity, density, velocity, flow rate, etc. The biasing mechanism can take various forms such as a widening passageway, contour elements along the biasing mechanism, or a curved section of the biasing mechanism passageway. The biasing mechanism can include hollows formed in the passageway wall, obstructions extending from the passageway wall, fluid diodes, Tesla fluid diodes, a chicane, or abrupt changes in passageway cross-section.

Abstract: A method for producing fluid from a subterranean formation includes configuring a body to at least partially fill with a selected fluid; and actuating a flow restriction element using the body. The selected fluid may be water. An apparatus for controlling flow of a fluid into a wellbore tubular may include a selectively buoyant body, and a flow restriction element responsive to a movement of the selectively buoyant body. The selectively buoyant body includes a membrane configured to block a flow of hydrocarbons into the selectively buoyant body. The flow restriction element may include a flapper, a sliding sleeve, and a poppet valve. The body may be at least partially filled with a permeable material, which includes, but is not limited to, open-cell foam, reticulated metal foam, shaped sintered powder and capillary tubes.

Abstract: A technique enables protection of subsea wells. The technique employs a subsea test tree designed to ensure control over the well in a variety of situations. The subsea test tree is formed with at least one shut-off valve to protect against unwanted release of fluids from the subsea test tree. The subsea test tree also is coupled with and controlled by a control system having a subsea control module mounted to an interior mandrel.

Abstract: A downhole bypass valve utilizes a stationary sleeve defining an interior ball-seat. When a dropped ball is seated, fluid differential pressure is diverted to an annular area adjacent a first sliding sleeve. The sleeve slides in response to the pressure differential upon shearing of a shear pin, or similar, and opens ports to the wellbore annulus. Treatment or maintenance operations can then occur through the ports, which can be fitted with nozzles. A second sliding sleeve, independent from the first, is operated in response to dropping a second ball into the device. The second ball diverts fluid differential pressure to an annular area adjacent the second sleeve and movement occurs when a shear pin shears. The second sleeve covers the ports to the wellbore annulus and closes the valve. After a sliding sleeve shifts, pressure across the sleeve is equalized, allowing reverse flow without risk of accidental sleeve actuation.

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: A wireless actuation system comprises a transmitter, an actuation system comprising a receiving antenna, and one or more sliding members transitional from a first position to a second position. The transmitter is configured to transmit an electromagnetic signal, and the sliding member prevents a route of fluid communication via one or more ports of a housing when the sliding member is in the first position. The sliding member allows fluid communication via the one or more ports of the housing when the sliding member is in the second position, and the actuation system is configured to allow the sliding member to transition from the first position to the second position in response to recognition of the electromagnetic signal by the receiving antenna.

Abstract: A completion joint 100 has two sand control jackets 120A-B connected on each end of an intermediately-mounted inflow control device 130. Both jackets 120A-B communicate with a housing chamber 155 through dedicated open end-rings 140A-B. The basepipe's flow openings 118 are isolated from this housing chamber 155 by a sleeve 160 fitted with flow ports 170. The housing 150 is removable to allow access to the flow ports 170 for pinning to configure the ports 170 open or closed for a given implementation.

Abstract: A wellbore servicing system comprising one or more wellbore tool nodes disposed within a wellbore, wherein each of the one or more wellbore tool nodes is configurable from a first configuration to a second configuration, and a controller node, wherein the controller node communicates with the wellbore tool node via a near field communication (NFC) signal.

Abstract: A wellbore servicing tool comprising a body, a near field communication (NFC) system disposed within the body and comprising a processor configured to communicate via NFC, one or more antennas each in signal communication with the processor, at least one input/output (I/O) device in signal communication with the processor, and a power supply in electrical communication with the processor. A wellbore servicing method comprising positioning a first node within a wellbore, moving a second node through the wellbore such that the second node comes into communication with the first node, wherein the first node and the second node establish signal communication via a near field communication (NFC) signal, wherein data is communicated from the first node to the second node via NFC, from the second node to the first node via NFC, or combinations thereof.

Abstract: A method of controlling standpipe pressure in a drilling operation can include comparing a measured standpipe pressure to a desired standpipe pressure, and automatically adjusting a choke in response to the comparing, thereby reducing a difference between the measured standpipe pressure and the desired standpipe pressure. A standpipe pressure control system for use in a drilling operation can include a controller which outputs an annulus pressure setpoint based on a comparison of a measured standpipe pressure to a desired standpipe pressure, and a choke which is automatically adjusted in response to the annulus pressure setpoint. A well system can include a standpipe line connected to a drill string in a wellbore, a sensor which measures pressure in the standpipe line, and a controller which outputs an annulus pressure setpoint based at least in part on a difference between the measured pressure and a desired standpipe pressure.

Abstract: A completion apparatus (4) for completing a wellbore comprises a) a tool to alternatively open and close a throughbore (15) of the completion; b) a tool (13) to alternatively open and close an annulus defined between the outer surface of the completion and the inner surface of the wellbore; c) a tool to alternatively provide and prevent a fluid circulation route from the throughbore of the completion to the said annulus (11); and d) at least one signal receiver and processing tool (9) capable of decoding signals received relating to the operation of tools a) to c).

Abstract: A method of controlling flow between a flow passage of a tubular string and an annulus includes: constructing a valve having an opening for flow between the passage and annulus; permitting flow through the opening; then preventing flow through the opening in response to applying pressure to the valve; and then mechanically displacing a closure device, thereby allowing flow through the opening. Another method includes applying a pressure differential across a piston of a valve, thereby displacing a closure device; and then displacing the closure device relative to the piston, thereby allowing flow between the passage and the annulus. A valve includes an opening for flow between an interior and exterior of the valve, a closure device for permitting and preventing flow through the opening, and a piston which biases the closure device to displace, the closure device being mechanically displaceable relative to the piston.

Abstract: The present disclosure relates to downhole tools, including downhole valves, which actuate via a pressure differential created across a shifting element having one or more pressure surfaces isolated from fluid, and fluid pressure, flowing through the interior flowpath. Embodiment downhole tools of the present disclosure may actuate in response to, among other signals, fluid pressure in the interior flowpath of the tool and fluid pressure communicated to a pressure surface of the shifting sleeve from the exterior of the tool. Certain embodiments may also have an outlet connector whereby fluid pressure from the downhole tool may be communicated to its exterior, including to additional tools in the tubing strings via flowlines connecting the two tools.

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 method of installing a wellbore junction assembly in a well can include connecting at least two tubular strings to one opposite end of a tubular string connector with similarly dimensioned oriented connections, whereby the tubular strings are interchangeably connectable to the connector by the oriented connections. A wellbore junction assembly can include at least two tubular strings and a tubular string connector having opposite ends. Each of the tubular strings may be secured to one opposite end of the connector by oriented connections, whereby each of the tubular strings has a fixed rotational orientation relative to the connector. A well system can include a tubular string connector, each of first and second tubular strings being secured to the connector, and a support which reduces bending of the second tubular string which results from deflection of the second tubular string from one wellbore section into another wellbore section.

Abstract: A downhole oilfield tool assembly comprises a mandrel, a ball valve oriented to block downwards flow through the mandrel in a closed position, a first piston located above the ball valve and at least partly around an outside of the mandrel. The first piston is configured to develop motive force from a pressure differential between an interior of the mandrel and an exterior of the downhole oilfield tool assembly.

Abstract: A system and method comprising at least one ported sleeve assembly and a flapper assembly positioned downwell of the ported sleeve assembly. The system provides for the use of multiple ported sleeve assemblies for each stage of a hydrocarbon producing well that can be opened with a single element, and multiple stages, each have thFracturinge ability to be opened with a single element size.

Abstract: Actuation assemblies include a valve assembly comprising a valve sleeve configured to rotate to selectively enable fluid flow through at least one aperture in the valve sleeve and into at least one port of an outer sleeve and a ball retention feature configured to selectively retain a ball dropped through a fluid passageway of the valve assembly in order to rotate the valve sleeve. Downhole tools include actuation assemblies. Methods for actuating a downhole tool include receiving a ball in an actuation assembly, rotating a valve sleeve of the actuation assembly to enable fluid to flow through a portion of the actuation assembly, and actuating a portion of the downhole tool with the fluid.

Abstract: Certain aspects and features of the present invention are directed to an actuation assembly that can be disposed in a wellbore through a fluid-producing formation. The actuation assembly can include a body, a potential force in the body, and a device in the body. The device can cause the potential force to be released from the body in response to receiving a signal identifying a target device disposed in the wellbore.

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

Abstract: A method for flow control and a self-adjusting valve or flow control device, in particular useful in a production pipe for producing oil and/or gas from a well in an oil and/or gas reservoir, which production pipe includes a lower drainage pipe preferably being divided into at least two sections each including one or more inflow control devices which communicates the geological production formation with the flow space of the drainage pipe. The fluid flows through an inlet (10?) and further through a flow path of the control device (2) passing by a non-disc shaped movable body (9?) which is designed to move relative to the opening of the inlet and thereby reduce or increase the flow-through area (A2) by exploiting the Bernoulli effect and stagnation pressure created over the body (9?), whereby the control device, depending on the composition of the fluid and its properties, automatically adjusts the flow of the fluid based on a pre-estimated flow design.

Abstract: A system and method for selectively enabling fluid communication between two volumes includes a tubular having a port housing with at least one port and a member disposed with the tubular and movable between a closed position in which the port is closed and an open position in which the port is open. The system further includes a lock element positively engaged with both the member and the tubular for maintaining the member in the closed position. Further, an actuator is in keyed engagement with the lock element for biasing the lock element for enabling the member to move relative to the tubular to the open position for opening the port.

Abstract: A method can include closing a valve interconnected between sections of a washpipe of a service tool string by displacing the service tool string relative to a completion string, thereby preventing flow through the washpipe. A well system can include a service tool string reciprocably received in a completion string, the service tool string including a washpipe received in a well screen, and a valve which selectively permits and prevents flow through the washpipe. The completion string can include a structure which operates the valve in response to displacement of the service tool string relative to the completion string. Another method can include closing a valve by partially withdrawing a service tool string from a completion string, thereby preventing flow through a washpipe of the service tool string.

Abstract: A multi-barrier system includes a first valve in fluid communication with a lower completion, and a second valve in fluid communication with the lower completion. The first valve and the second valve are positioned proximate an uphole extent of the lower completion, and a packer located proximate the first valve and the second valve is closable in response to retrieving an upper completion.

Abstract: An apparatus and method are described for autonomously controlling flow of fluid in a subterranean well, where fluid flow is controlled based on a fluid characteristic, such as viscosity or density, which changes over time. Fluid flows into a vortex assembly where a centrifugal force is imparted to the fluid. A less viscous fluid will have a relatively greater velocity and centrifugal force than a more viscous fluid. The fluid exits the vortex chamber by both a vortex outlet and a peripheral outlet. An autonomous valve element moves between an open position, in which fluid flows freely through the peripheral outlet, and a closed position, in which fluid flow through the peripheral outlet is restricted. The valve element is moved by the centrifugal force of the fluid, such that a fluid having a higher centrifugal force moves the valve element to the closed position, thereby reducing the total fluid flow through the vortex assembly.

Abstract: An apparatus and method autonomously controls fluid flow in a subterranean well, as the fluid changes in a characteristic, such as viscosity, over time. An autonomous reciprocating member has a fluid flow passageway there through and a primary outlet and at least one secondary outlet. A flow restrictor, such as a viscosity dependent choke or screen, is positioned to restrict fluid flow through the primary outlet. A vortex chamber is positioned adjacent the reciprocating member. The reciprocating member moves between a first position where fluid flow is directed primarily through the primary outlet of the reciprocating member and into the primary inlet of the vortex assembly, and a second position where fluid flow is directed primarily through the at least one secondary outlet of the reciprocating member and into the at least one secondary inlet of the vortex assembly. The movement of the reciprocating member alters the fluid flow pattern in the adjacent vortex chamber.

Abstract: A modified casing coupling houses a pressure relief valve body having a through bore with opposing end openings. The through bore communicates with the interior of the modified casing coupling at one end opening thereof and with an area surrounding the modified casing coupling at an opposite end opening. The through bore includes a ball seat adjacent one end opening thereof which receives a sealing ball. The ball is urged in the direction of the ball seat by a tensioning element. The ball is exposed to annular pressure trapped between successive lengths of well casing located in the well borehole. The amount of tension exerted on the ball by the tensioning element is selected to allow the ball to move off the ball seat to release trapped annular pressure between the selected casing strings once a certain annulus pressure is reached.

Abstract: An apparatus for pressure-testing a tubular body may be installed in the tubular-body interior. The apparatus comprises an activation-device seat, one or more bypass ports, a J-slot with an indexing pin and a spring. When an activation device, for example a ball, lands in the activation-device seat, fluid communication through the tubular body is blocked, allowing pressurization. During pressurization, the activation-device seat moves downward, causing the spring to compress and the indexing pin in the J-slot to move to the bottom position. Upon depressurization after the test, the activation-device seat moves upward, causing to spring to decompress and the indexing pin the J-slot to move to the top position. Upward movement of the activation-device seat unblocks the bypass ports, thereby reestablishing fluid communication through the tubular body. The tubular body may be drillpipe, casing or coiled tubing that is installed in the borehole of a subterranean well.

Abstract: Methods and apparatus for running a completion string with sand screen assemblies through multiple zones are presented allowing sequential stimulation of zones, and production without multiple trips. An exemplary method includes running a completion string and isolating target zones. If desired, the formation can be produced prior to stimulation. To stimulate the zones, a first tubing valve is closed, for example by ball-drop, forcing fluid through the first screen assembly. After stimulating the zone is complete, a first screen valve is closed by increased tubing pressure. The first work string valve is re-opened by further increasing tubing pressure. A subsequent tubing valve is then closed, for example, by flowing the ball to the next ball seat. The process is repeated until all zones are stimulated. Valves are then opened at each screen assembly to allow production flow through the screen assemblies.

Abstract: The present invention generally relates to a hydraulic communication device that is used in a wellbore for fluid communication during a wellbore operation. In one aspect, a hydraulic communication device is provided. The hydraulic communication device includes a body having a central passageway and a bore formed in a wall of the body. The bore is in fluid communication with the central passageway, and the bore is configured to receive an end of a control line. The hydraulic communication device further includes a plug assembly disposed in the bore formed in the wall of the body. The plug assembly is movable from a first position in which fluid communication through the bore is blocked and a second position in which fluid communication through the bore is unblocked.

Abstract: A diffuser assembly has pairs of split rings rotationally locked to each other in an alternating array with other pairs of split rings where adjacent pairs are responsive to pressure differential to be biased toward a sliding sleeve or the surrounding housing in an alternating pattern. The split rings are made to have an interference initial fit to the sleeve or housing and the splits on adjacent rings are offset while a relation of a projection to a depression between adjacent rings prevents relative rotation to keep the desired circumferential offset in the splits between adjacent rings. End tapers can bias adjacent pairs in opposed directions responsive to applied differential pressure. The rings are preferably metallic and can have a coating to facilitate relative sliding and enhance durability.

Abstract: A downhole tool (10) and method for controlling fluid flow into and/or from a formation zone (FZ), the downhole tool (10) comprising a sliding sleeve device (12) disposed between, and forming a fluid coupling between a first screen (14) and a second screen (16), the sliding sleeve device (12) configured to provide axial fluid communication between the screens (14, 16) and to provide selective lateral passage of fluid through the screens (14, 16) into a throughbore (24,36,42) of the downhole tool (10).

Abstract: In one embodiment, a valve comprising a valve body; an orifice disposed within the valve body; a fluid flow restraining member located at a first location of the orifice, the fluid flow restraining member pivotable between a closed position and an open position; an extending member connected to, and moveable in pivotable synchronization with, the fluid flow restraining member; and a shape memory alloy element attached to the extending member and the valve body, the shape memory alloy element causing a pivotal movement of the extending member between positions corresponding to the open and closed positions responsive to a change in temperature of the shape memory alloy element.

Abstract: An arrangement for directing a fluid flow or a tool transported in a fluid flow in an under water structure includes plural flow line arrangements each including at least one flow line, and at least two distribution devices to be varied between at least two positions. One distribution device connects at least two flow arrangements providing for the selection of the fluid flow pattern directing the fluid through the distribution devices and the flow arrangements depending on the position of each of the distribution devices. A method directs a fluid flow or a tool transported in a fluid flow.

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 present invention relates to an annular barrier to be expanded in an annulus between a well tubular structure and an inside wall of a borehole for providing zone isolation between a first zone and a second zone of the borehole, comprising a tubular part for mounting as part of the well tubular structure and having an expansion opening, an expandable sleeve surrounding the tubular part, each end of the expandable sleeve being connected with the tubular part, and an annular barrier space between the tubular part and the expandable sleeve, wherein the annular barrier further comprises a pressure intensifying means having an inlet in a first end in fluid communication with the expansion opening and having an outlet in a second end in fluid communication with the annular barrier space.

Abstract: An apparatus for controlling a flow of a fluid between a wellbore tubular and a formation may include a frac tool having at least one port in selective fluid communication with the formation, and an inflow control device having a flow control path configured to provide a predetermined pressure drop for a flowing fluid. The inflow control device may have a flow coupler configured to provide selective fluid communication with the at least one port.

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.