Abstract: A hydraulic set packer system includes an outer sleeve and a mandrel extending through the outer sleeve. The mandrel has a setting port extending through a radial wall of the mandrel, and the setting port is configured to provide fluid communication from a central bore of the mandrel to a setting chamber formed between the outer sleeve and the mandrel. The system also includes a piston configured to move axially along the mandrel in response to a setting pressure in the setting chamber. The piston is configured to drive at least one radially actuatable component to actuate in a radial direction to engage a wellbore wall. Further, the system includes a pressure isolation assembly disposed in the setting chamber. The pressure isolation assembly is configured to move axially with respect to the mandrel from a first position to a second position to seal the setting port.

Abstract: This disclosure relates to an inflow control system having an apparatus configured to form or plug openings in a blank pipe. The apparatus includes a housing and a milling sub-system. The housing has a cylindrical wall with an outer surface. The milling sub-system is mounted to a first side of the wall and is configured to mill an opening in the blank pipe. The milling sub-system includes a bit configured to form an opening in the blank pipe and at least one brace attached to a second side of the wall opposite the first side of the wall. The at least one brace is configured to extend radially from the second side of the wall to press the bit to the inner surface of the blank pipe.

Abstract: An apparatus for selectably injecting materials into a well comprises an elongate inner casing having first and second sets of selectably closable passages therethrough and an outer casing extending between the first and second ends surrounding the inner casing so as to form an annular cavity therebetween. The first end of the outer casing is sealably connected to the inner casing and the second end of the outer casing has a free edge proximate to the second set of passages. The first set of passages extends through the inner casing into the annular cavity such that fluid passing through either of the first or second sets of passages enters an exterior of the apparatus at a common location.

Abstract: A system includes a tubular member, a sleeve disposed inside the tubular member, and a service tool. A dimension of the sleeve bridges a gap between an outer diameter of the service tool and an inner diameter of the tubular member.

Abstract: Toe valves comprising a bore, a first sub, a second sub, and a housing. The bore extends through the valve. The first sub has separable elements. The separable elements comprise a first sub element and a sleeve element. The first sub element and sleeve element are joined by a relatively weak bridging portion adapted to break in a controlled manner in response to fluid pressure between the first sub element and the sleeve element. They thereby form an integral component comprised of the separable elements. The housing has a port and couples the first sub element and second sub.

Abstract: A motor bypass valve diverts drilling fluid away from a downhole motor when the motor is off bit. Bypassing the downhole motor reduces the shock and vibration on the BHA caused by the downhole motor, thereby reducing the damage to the BHA. The motor bypass valve may divert fluid out of a housing or into a bore through the rotor of the downhole motor.

Abstract: A tubular assembly for a well system includes a drill pipe joint including a first pair of couplers disposed at ends thereof and a central passage, a flow sub configured to couple with the drill pipe joint, wherein the flow sub includes a second pair of couplers disposed at each end thereof and a first receptacle disposed therein, a first inner tubular member configured to be suspended from the first receptacle of the flow sub, wherein the first inner tubular member extends through the passage of the drill pipe joint forming an annulus therein when the drill pipe joint is coupled to the flow sub and the first inner tubular member is suspended from the first receptacle of the flow sub.

Abstract: A flow control assembly having a body defining a central flow passage and one or more lateral flow openings that facilitate fluid communication between the central flow passage and an exterior of the body, and a flow trim positioned within the central flow passage and defining one or more flow orifices aligned with the lateral flow openings. A flow closure member is positioned within the central flow passage and movable between a closed position, where the lateral flow openings and the flow orifices are occluded to prevent fluid flow through the lateral flow openings, and an open position, where the lateral flow openings and the flow orifices are at least partially exposed to facilitate fluid flow through the lateral flow openings. A sacrificial nose radially interposes the flow closure member and the flow trim to mitigate erosion of the flow closure member.

Abstract: A bypass tool has a piston movable within the bore of a central housing. A control slot on an exterior wall of the piston engages a slot pin in the housing. Longitudinal movement of the piston is downward, in response to fluid pressure exerted on a ball seated on a ball seat on the piston; and spring biased upward. The control slot and slot pin rotate the piston as it moves longitudinally between a first, upper position in which bypass ports in the housing are closed, and a second, lower position in which the bypass ports are open. An intermediate longitudinal position has the ports closed, and permits pressuring up on a ball to force it through the ball seat and reset the tool in the flow through position. The ball and/or ball seat may be of resilient material to permit passage of the ball through the seat.

Abstract: A mechanically activated bypass valve apparatus for allowing fluid being pumped through the pipe or coiled tubing string to be bypassed around a tool string and into the wellbore. Activation of the bypass valve is accomplished by applying weight-on-bit to the apparatus to shear a set of shear screws, allowing the mandrel to move axially relative to the tubular housing. Lowering the pipe string and setting down weigh on bit misaligns fluid bypass ports in the mandrel and housing, thus forcing fluid to continue to flow through the bore of the tool and to the toolstring below the bypass tool. Picking up on the pipe string aligns corresponding ports in the mandrel and housing and allows fluid to flow from the bore of the tool to the wellbore annulus, thus bypassing other tools downhole of the apparatus.

Abstract: A fill-up and circulation tool includes a central assembly including a mandrel, a nose assembly disposed at a terminal end of the mandrel, an outer assembly coupled to the central assembly, and a valve configured to change position between a closed position and an open position, wherein changing position between the closed position and the open position includes movement of the outer assembly relative to the central assembly.

Abstract: A downhole tool in a drill string for mitigating hazards of a blockage in an annulus of the drill string. The downhole tool can sense blockages and selectively recirculate flow from within the annulus back to surface. Further, the downhole tool is made up of segments that are selectively detachable from one another, so that the segments above the point of detachment are removable from a wellbore. The bypass assembly includes a sleeve in the downhole tool with openings in its side; when the annulus reaches a set pressure, the sleeve slides to a position so the openings register with ports formed through a side of the tool to allow bypass flow. A processor in the downhole tool senses movement of the string, and when the string is axially stationary more than a designated period of time, the processor emits signals to detach the segments.

Abstract: A well tool can include a chamber having a volume that changes when a member displaces, and a valve device that selectively opens and permits displacement of the member, and that selectively closes and prevents displacement of the member. A method of operating a well tool can include displacing a member, thereby changing a chamber volume, and then closing a valve device, thereby preventing displacement of the member. A well system can include a well tool connected in a tubular string, a flow passage of the tubular string extending longitudinally through the well tool, the well tool including a chamber having a volume that changes when a member displaces, and a shifting tool, a valve device opening and member displacement being permitted when the shifting tool engages the well tool, and the valve device closing and member displacement being prevented when the shifting tool disengages from the well tool.

Abstract: An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation. The controller time delay enables casing integrity testing before fluid is passed through the ports. This time delay also allows multiple valves to be used in the same well casing and provide a focused jetting action to better penetrate a concrete casing lining.

Abstract: An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention is a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation. The controlled time delay enables casing integrity testing before fluid is passed through the ports. This time delay also allows multiple valves to be used in the same well casing and provide a focused jetting action to better penetrate a concrete casing lining.

Abstract: A tubing string assembly is disclosed for fluid treatment of a wellbore The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off The tubing string can also be used where a ported tubing string is required to be run-m in a pressure tight condition and later is needed to be in an open-port condition A sliding sleeve in a tubular has a driver selected to be acted upon by an inner bore conveyed actuating device, the driver drives the generation of a ball stop on the sleeve.

Abstract: A downhole tool that selectively opens and closes an axial/lateral bore of a tubular string positioned in a wellbore used to produce hydrocarbons or other fluids. When integrated into a tubular string, the downhole tool allows individual producing zones within a wellbore to be isolated between stimulation stages while simultaneously allowing a selected formation to be accessed. The downhole tools and methods can be used in vertical or directional wells, and additionally in cased or open-hole wellbores.

Abstract: A sliding sleeve has an associated shock absorber to limit shock loading to the shifting apparatus when the end of travel is reached. An adjacent sleeve defined an annular cavity in a manner that does not reduce the drift dimension of the shifting sleeve. The cavity has a fluid in it and the movement of the shifted sleeve causes the movement of the shock absorber sleeve to reduce the fluid volume in the annular cavity. The volume reduction forces fluid through a restriction to regulate the speed of the sliding sleeve as a travel stop is reached. The fluid can be a gas, an incompressible fluid or grease. The restriction can be temporarily covered such as with a rupture disc. Room to compensate for thermal expansion can be provided in the annular space.

Abstract: A valve system for providing fluid flow through radial openings disposed along an axial length of a tubular. The tubular comprises at least one valve group containing at least two valves operable by one drop ball. An inset 302 e.g. of standard grade steel provided in a harder liner 301 in the opening provides an intermediate small opening for at least the time required to open all the remaining valves in the group. The small opening limits the pressure drop over the valve. When all valves are open, the insets 302 are eroded away by an abrasive material, e.g. a slurry used for hydraulic fracturing, and permanent full openings are created.

Abstract: A circulation sub is provided that has a ball seat and a circulation port that is closed when a ball is landed on the seat. An axial passage directs the pressure surge created with the landing of the ball on the seat to the port with the actuation piston for the tool. The surge in pressure operates the actuation piston to set the tool, which is preferably a packer. Raising the circulation rate through a constriction in a circulation sub breaks a shear device and allows the restriction to shift to cover a circulation port. The pressure surge that ensues continues through the restriction to the actuating piston for the tool to set the tool.

Abstract: A differential pressure release sub includes a sub housing having a housing bore, a piston chamber communicating with the housing bore and at least one fluid port communicating with the piston chamber. A piston having a piston bore is disposed for axial displacement in the piston chamber from a first position wherein the at least one fluid port is fluidly sealed from the piston bore to a second position wherein the at least one fluid port is disposed in fluid communication with the piston bore. A first surface having a first surface area is on the piston. A second surface having a second surface area less than the first surface area of the first surface is on the piston.

Abstract: Gas injection control devices are provided, particularly for deployment in a well-bore to control injection of a gas into a tube or pipe to lift a liquid up the tube, such as crude oil for example. A gas control device is described which comprises a housing, and at least two control valve arrangements within the housing. Each arrangement has an inlet for receiving gas from a pressurized supply, an outlet for supplying pressurized gas for injection into the tube, an inlet valve in a fluid path between the inlet and outlet, and an actuator associated with the inlet valve. Each actuator is independently controllable to switch the respective inlet valve between its open and closed configurations. This allows the gas injection to be switched on and off, and facilitates control of the injection gas flow rate.

Abstract: A valve includes: a housing; a mandrel disposed in the housing; a rupture disk disposed in a passageway of the mandrel; a sliding sleeve disposed between the housing and the mandrel; and a ball seat disposed in the mandrel. A method for actuating a valve includes: flowing a fluid through the valve; dropping a ball; seating the ball in the ball seat and blocking fluid flow through the mandrel; flowing fluid through the passageway to the sliding sleeve; moving the sliding sleeve axially within the valve; and exiting fluid through the openings of the housing and mandrel. A valve includes: a housing having an opening; a mandrel disposed in the housing; a sliding sleeve disposed between the housing and the mandrel; and a ball seat disposed in the mandrel blocking fluid communication between the mandrel and the passageway.

Abstract: A downhole bypass valve comprises a tubular body including a side port and a sleeve axially movably mounted in the body and normally biased to a closed position to close the side port. An activating device is configured to be pumped or dropped into the body to engage the sleeve and permit movement of the sleeve to an open position and open the side port. A latch has a part in the body and a part in the activating device, the parts of the latch configured to engage and retain the sleeve in the open position. The activating device is further operable to disengage from and translate through the sleeve and the parts of the latch are further operable to disengage and permit the sleeve to return to the closed position.

Abstract: Systems and methods for producing from multiple zones in a subterranean formation are provided. The system can include a liner including a first frac valve, a second frac valve, and a formation isolation valve. The second frac valve can be positioned above the first frac valve, and the formation isolation valve can be positioned above the second frac valve. A completion assembly can be disposed at least partially within the liner. The completion assembly can include a valve shifting tool adapted to actuate the formation isolation valve between an open position and a closed position. The completion assembly can also include a first flow control valve in fluid communication with the first frac valve and a second flow control valve in fluid communication with the second frac valve.

Abstract: For wellbore fluid treatment, sliding sleeves deploy on tubing in a wellbore annulus. Operators deploy a plug down the tubing to a first sleeve. The plug seats in this first sleeve, and pumped fluid pressure opens the first sleeve and communicates from the tubing to the wellbore annulus. In the annulus, the fluid pressure creates a pressure differential between the wellbore annulus pressure and a pressure chamber on second sleeves on the tubing. The resulting pressure differential opens the second sleeves so that fluid pressure from the tubing can communicate through the second open sleeves. Using this arrangement, one sleeve can be opened in a cluster of sleeves without opening all of them at the same time. The deployed plug is only required to open the fluid pressure to the annulus by opening the first sleeve. The pressure chambers actuate the second sleeves to open up the tubing to the annulus.

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: Disclosed herein is a valve. The valve includes a first member having a first port therethrough, a second member in operable communication with the first member having a sealing surface thereon and a second port therethrough that is movable relative to the first member. The valve also has a seal sealingly engaged with the first member and slidably sealingly engagable with the second member, and a support member movably disposed relative to the first member and the second member. The support member has a support surface dimensioned similarly to the sealing surface, and is movable with the second member relative to the first member so that upon such movement the seal is continuously supported by at least one of the sealing surface and the support surface.

Abstract: A production string employable in a multi-zone completion system, the production string includes a passageway enabling passage of production fluids therethrough; a shifting tool including a shifting profile engageable with a production sleeve of the completion system to open a closed production sleeve, the shifting tool sharing the passageway of the production string; and, a remotely controlled hydraulic production valve which controls fluid flow between the passageway and the production sleeve. Also included is a production method useable in a borehole.

Abstract: A pressure actuated valve is disclosed which includes a plurality of flow openings, and first and second pistons. The first and second pistons are independently actuatable relative to one another, and are releasable coupled to one another by a release sleeve. The pressure actuated valve also includes a closing sleeve that is operatively coupled to the second piston. In an initial position of the second piston, the closing sleeve covers or blocks the plurality of flow openings. The pressure actuated valve includes a ratchet mechanism coupling the release sleeve to the first piston, the ratchet mechanism being adapted to allow movement of the first piston between its initial position and an intermediate position and back to its initial position while allowing the release sleeve to release the second piston after a predetermined number of cycles of movement of the first piston between its initial position and the intermediate position and back to its initial position.

Abstract: System and method for circulating fluid within a well bore. A circulation sub configured with communication elements on its ends to link the sub to a downhole communication network. A slideable piston in the sub isolates or exposes an outer port on the sub to an inner fluid flow along the sub depending on a signal transmitted along the communication network. Methods for activating the circulation sub via signals transmitted along the downhole communication network.

Abstract: A system and method for maintaining continuous flow through a drill string during drill pipe connection includes establishing drilling fluid flow axially through the length of a tubular sub attached to the top of a drill string. The sub is then engaged with a collar disposed at least partially around the perimeter of the sub so as to define an exterior flow path along the exterior of the sub. Radial flow is then initiated into the sub through said collar and along said exterior flow path. Axial flow is then terminated through the length of the tubular sub while maintaining radial flow into the sub. A pipe joint is then attached to the top of the tubular sub, axial flow is reestablished through the length of the tubular sub, radial flow is terminated into the sub, and the collar is disengaged from the sub.

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 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 sliding sleeve device features a first sleeve that can be shifted with a dropped object on a seat and applied pressure to open a housing port. A second sleeve is in line with the first sleeve and be shifted to straddle the housing ports that we exposed when the opening sleeve was shifted initially. Snap rings or other locking devices can be used to hold the closing sleeve in the shifted position with the housing ports closed. The closing sleeve can also be shifted with a shifting tool that is run for example on coiled tubing. The opening sleeve can also optionally be shifted with a tool in an uphole direction to open the housing ports.

Abstract: Frac valves used in completing oil and gas wells are provided. The valves comprise a cylindrical housing adapted for assembly into a liner for a well. The valve housing defines a conduit for the passage of fluids through the housing. Preferably the conduit has a substantially uniform diameter. The housing has a port which can allow fluids to pass from the conduit to the exterior of the valve. The port may be shut off or left open by a valve body mounted on the housing. Preferably, the valve body is mounted between inner and outer walls provided in the housing. An actuator is provided to move the valve body between its open and closed positions. It comprises a receiver that is adapted to receive an activation signal. Thus, the valve may be actuated by introducing a transmitter into the housing conduit which transmits an activation signal.

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: 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 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: A downhole tool provided within a casing string for use in cement staging operations. The tool includes an inflatable packer that is integral to the body of the tool and ports in sides of the tool. The ports are selectively opened and closed for circulating cement from within the tool so that cement can flow between the casing string and a wellbore. The ports are actuated by sliding the casing string upward or downward within the wellbore. The packer can be pressure tested after being set to ensure its efficacy.

Abstract: A downhole circulating valve includes a generally tubular outer housing having a generally axially extending internal passageway. At least one generally longitudinally extending circulating passageway is formed through at least a portion of the housing. At least one exterior port and at least one interior port are in fluid communication with the circulating passageway. At least one seal plug is disposed within the circulating passageway. The seal plug has a first position relative to the housing wherein the seal plug is remote from the exterior port and the interior port, thereby allowing fluid flow between the exterior port and the interior port through the circulating passageway. The seal plug has a second position relative to the housing wherein the seal plug is between the exterior port and the interior port and wherein the seal plug forms at least one metal-to-metal seal with the circulating passageway, thereby preventing fluid flow between the exterior port and the interior port.

Abstract: The segmented ball seat valve is an annular communication valve normally installed in a string of pipe that is to be deployed to a depth within a well. The segmented ball seat valve provides communication between the inside of the pipe and the well bore or casing through open ports. The segmented ball seat valve can be closed to shut off communication by dropping/pumping a ball to the segmented ball seat valve and applying pressure to close the valve. The application of pressure causes the ball seat assembly to move downward into an enlarged portion of the bore. The segments of the seat assembly move outward in the enlarged area to permit passage of the ball.

Abstract: The present invention is to an internal sleeve slidably received within a tubular housing. The sleeve and outer housing have windows that selectively align. Movement of the sleeve within the housing is controlled by a ball passing through the interior of the sleeve to activate a ratchet that allows the sleeve to move a set amount under the influence of a spring. A split seat at a lower end of the housing traps after a set number of balls have passed through the housing. A number of similar tools can be used to provide openings at various points that include coordinated ratchet steps so that only one tool at a time opens for fracturing or other purposes. A reverse flow causes a ball to impinge upon the next higher ball seat and thereby opening the seat to provide a full bore flow passage through the tool.

Abstract: A method of variably restricting flow in a subterranean well can include resisting the flow through a sidewall of a tubular string, and then selectively opening a device in response to a predetermined pressure signal being transmitted. The opening of the device can substantially reduce a resistance to the flow through the tubular string sidewall. A flow restrictor system for use with a subterranean well can include a flow restrictor which resists flow through system, a pressure sensor, and an initially closed device which opens and thereby permits the flow to bypass the flow restrictor, in response to a predetermined pressure signal being detected by the sensor.

Abstract: A downhole tool and method for performing to provide a flow path from an inner bore thereof to a wellbore annulus, wherein the flow path is provided upon the application of pressure.

Abstract: A well system can include a flow control device which regulates flow of a fluid from an interior of the device outwardly through an exit port, and a deflector which outwardly overlies the exit port and provides fluid communication between the exit port and an annulus formed radially between the deflector and a wellbore lining. The deflector can diffuse the flow of the fluid prior to impingement on the wellbore lining. A flow control assembly can include a flow control device which regulates flow of a fluid from an interior of the device outwardly through an exit port, and a deflector which outwardly overlies the exit port, the deflector including at least one opening, and the opening being circumferentially offset relative to the exit port. A form of an interior surface of the deflector and/or an exterior surface of the flow control device can diffuse the flow of the fluid.

Abstract: A tubing pressure operated sliding sleeve is used in cementing a tubular string. The sleeve is configured to hold closed as pressure builds to a predetermined value. When pressure is further raised a rupture disc blows and provides access to an integral piston disposed outside the sleeve. The back side of the piston is exposed to a low pressure or atmospheric chamber located between upper and lower seals. The sleeve thickness near the chamber can be made relatively thick to avoid flexing or bending under differential pressure because the net force to shift the sleeve is from differential pressure on the piston rather than the piston areas created by the upper and lower seals.

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

Abstract: A completion assembly with a valve assembly for regulating fluid flow in a wellbore is disclosed. The completion assembly can include a base pipe with a sand screen. A flow control housing is disposed on one end of the sand screen. A first tubular port in the base pipe leads into the flow control housing, and a second tubular port is also formed in the base pipe. A flow path is formed within the flow control housing and communicates with both the base pipe and the inner annulus of the screen assembly. A valve assembly is located in the flow control housing and is in fluid communication with both the inner annulus and the base pipe. The valve assembly is positionable between multiple positions for controlling the flow through the flow control flowpath in response to fluid pressure applied to the second tubular port.

Abstract: A bypass valve for use in tubing string which can be repeatedly opened and closed to selectively provide bypass fluid flow between the interior of the tubing string and the annulus to assist in flowing debris. The valve uses hardened valve elements which can be opened and closed while flowing fluids under pressure through the tubing string. The valve is actuated by placing the tubing string in a sufficient weight down condition to operate the valve. A trigger is provided to prevent unintended actuation of the bypass valve during use.