Abstract: A valve for use in a tool positioned in a well that includes a body having a bore and a port connected to permit fluid communication between the well and the bore. A piston is supported in the body for movement between an open position to open the port and a closed position to close the port. A rupture disc is responsive to fluid pressure in the well and ruptures when a predetermined pressure is applied so that fluid pressure is communicated to the piston to move it from the closed position to the open position. A lock member secures the piston in the closed position after the piston moves from the open position to the closed position.

Abstract: A hydraulic control system and associated methods provides selective control of operation of multiple well tool assemblies. In a described embodiment, a hydraulic control system includes multiple control modules, each of which has a member that is displaceable to multiple predetermined positions to thereby select a corresponding one of multiple well tool assemblies for operation thereof. When the member of a certain control module is in a selected position, an actuator of a corresponding one of the well tool assemblies is placed in fluid communication with a flowpath connected to the control module. The members of the multiple control modules are displaced simultaneously in response to pressure on a line connected to each of the control modules.

Abstract: A downhole drilling method comprises producing pressure pulses in drilling fluid using measurement-while-drilling (MWD) apparatus (18) and allowing the pressure pulses to act upon a pressure responsive device (16) to create an impulse force on a portion of the drill string.

Abstract: A downhole tool (20) comprises a body (22), a tool function member (28, 30) axially movable relative to the body (22) from an initial position to an operative position, a first spring (32) responsive to a first fluid pressure force for permitting movement of the tool function member (28) from the initial position to an intermediate position; and a second spring (33) responsive to a higher second fluid pressure force for selectively permitting movement of the tool function member (30) to the operative position. The tool function member may be in one or two parts and may include a bypass sleeve (30).

Abstract: In one aspect of the invention, a locking assembly for a wellbore valve is provided comprising a cylindrical sleeve insertable into an interior of the valve. After insertion into the valve, the body is expanded into interference with a closing mechanism of the valve, thereby locking the valve in an open position.

Abstract: A downhole valve that may be opened and closed by alternatingly pressurizing/bleeding a first control line, which is in fluid communication with a first surface of an activating member, and a second control line, which is in fluid communication with a second surface of the activating member. The fluid within the control lines is the same density as the fluid found in the annulus of the wellbore. The development of a leak in the control lines therefore does not by itself result in the actuation or movement of the activating member or valve member.

Abstract: An isolation system and method for use in a wellbore that passes through a formation includes a flow conduit capable of receiving a fluid flow from the formation and an isolation system coupled to the flow conduit and including one or more uni-directional flow control devices. Each uni-directional flow control device may be ball-type check valve, plate-type check valve, and flapper-type check valve. The one or more uni-directional flow control devices are adapted to be opened by fluid flow from the formation and to be closed by pressure from a fluid column in the flow conduit when the fluid flow is shut off. In another arrangement, an isolation system and method includes a valve, a string having a flow conduit (e.g., tubing, flow tube, etc.) and a lower end, and an actuation tool (e.g., a shifting tool) attached to the lower end of the string and adapted to operate the valve if the string is lowered into or raised out of the wellbore.

Abstract: The invention is a downhole valve that includes a body, a flow tube assembly that includes an upper tube member and a lower tube member, and a flapper valve. The flapper valve is pivotally attached to the body and is positioned between the upper tube member and the lower tube member when the flapper valve is in a closed position that blocks fluid flow in an internal bore of the body. The flapper valve is moved from the closed position to an open position in response to an upward movement of the upper tube member and the lower tube member. When the flapper valve pivots to the open position, the lower tube member moves adjacent to and forms a seal with the upper tube member, forming an unobstructed internal bore.

Abstract: An in-line flow control device for a well chokes flow through a conduit while allowing access therethrough.

Abstract: An apparatus usable in a subterranean well includes a valve, a first mechanism and a second mechanism. The valve controls communication between an annular region that surrounds the valve and an inner passageway of the valve. The first mechanism causes the valve to transition from a first state to a second state in response to pressure in the annular region. The second mechanism causes the valve to transition between the first state and the second state in response to a pressure differential between the annular region and the inner passageway.

Abstract: A mud saver valve is described that features an outer housing that retains upper and lower valve pistons therewithin. The pistons coordinate to provide a check valve so that fluid, such as drilling mud, is permitted to flow in one direction while under pump pressure and works as a relief valve in the event of excessive wellbore pressure when the pump is turned off. Both pistons are provided with apertured plates that selectively define fluid passages through the valve. In the described embodiment, the valve also includes a frangible vent cap that is self-securing and easily replaceable. The cap permits venting of excessive downhole pressures.

Abstract: A formation isolation valve assembly for use in a well includes first and second fluid paths that are coupled to at least first and second completion zones. A first valve controls fluid flow from the first zone to the first fluid path, and a second valve controls fluid flow from a second zone to the second fluid path. The valves may include ball valves and sleeve valves.

Abstract: A method and apparatus of performing fluid loss, well isolation control, and flow control in a well having multiple zones. A multi-valve system having a plurality of valve assemblies is installed into the well. The multi-valve system provides fluid loss and well isolation control during running of the upper completion and provides flow control during production or other operation of the well. A control line carrying fluid pressure is run from the surface to the plurality of valve assemblies, with the control line capable of selectively actuating more than one valve assembly. In one example arrangement, the control line carries nitrogen gas to the multi-valve system. A fast bleed and slow bleed device at the well surface is connected to the control line. One of the fast bleed and slow bleed devices may be employed to open or close a selected one of the valve assemblies. In another arrangement, the control line and activating mechanism may be used for other types of pressure-actuated devices.

Abstract: A subsurface safety valve has a tubular valve housing, a valve closure member movable between an open and a closed position, an axially shiftable flow tube for opening the valve closure member. Hydraulic pressure from the control line is used to move a piston, which in turn moves an axially shiftable opening prong through the closure member. A balance line, or second hydraulic line is also used to make the valve well insensitive. An isolation valve is placed in the flow path of the second hydraulic line. The isolation valve prevents gas migration into the balance line. It also provides volume control for the fluid displaced when the piston is moved by pressure from the control line. Further, the valve can be closed by the application of sufficient pressure through the second hydraulic line.

Abstract: A system usable with a subterranean well includes a tubing and a lubricator. The tubing is adapted to receive a drill string in a passageway of the tubing, and the lubricator is located downhole and is connected to the tubing. The lubricator is adapted to be remotely operable from a surface of the well to control fluid communication between the passageway located above the lubricator and a formation located beneath the lubricator. The lubricator may include a sleeve and controller. The controller selectively moves the sleeve into a passageway of a valve of the lubricator to protect the valve from a downhole fluid.

Abstract: A system usable with a subterranean well includes a tubing and a lubricator. The tubing is adapted to receive a drill string in a passageway of the tubing, and the lubricator is located downhole and is connected to the tubing. The lubricator is adapted to be remotely operable from a surface of the well to control fluid communication between the passageway located above the lubricator and a formation located beneath the lubricator. The lubricator may include a sleeve and controller. The controller selectively moves the sleeve into a passageway of a valve of the lubricator to protect the valve from a downhole fluid.

Abstract: An apparatus for retaining fluid in a pipe includes an elongated body adapted to be positioned within a subsea wellhead assembly. The elongated body has an end adapted for connection to the pipe, a flow passage for fluid communication with the pipe, and an outer surface for engagement with a sealing member in the subsea wellhead assembly. A first chamber is defined within the elongated body and connected to receive pressure from above the subsea wellhead assembly. A second chamber is defined within the elongated body and connected to receive pressure from below the subsea wellhead assembly. A valve is supported in the elongated body for movement in response to pressure differential between the first and the second chambers. The valve is movable between an open position to permit fluid flow through the flow passage and a closed position to prevent fluid flow through the flow passage.

Abstract: A device for regulating fluid flow in a well is provided. The device may include: a body member having a central bore extending therethrough, at least one flow port, and a first valve seat; a sleeve member movably disposed within the central bore of the body member, and having a second valve seat adapted for cooperable sealing engagement with the first valve seat; means for selectively controlling movement of the sleeve member to regulate fluid flow through the at least one flow port; and conduit means for transmitting energy to the movement means. The conduit means may include a first and a second hydraulic control line, a single hydraulic control line, or a single electrical conductor. The movement means may include: a piston connected to the sleeve member and movable in response to a combination of hydraulic fluid, pressurized gas, spring force, and/or annulus pressure; or an electric motor connected to the sleeve member.

Abstract: A bypass sub which will automatically bypass fluid flow in excess of a selected optimal flow rate for a downhole mud motor. A spring biased mandrel within a housing is driven downwardly by increased fluid flow, and driven upwardly by spring force upon decreased fluid flow, to control the alignment of a port in the mandrel with a bypass port in the housing, thereby maintaining a desired rate of fluid flow to the downhole motor.

Abstract: Apparatus and corresponding methods are disclosed for controlling operation of well tools within a subterranean well. In a described embodiment, a remotely controllable actuator includes a pressurized fluid source and a chamber containing gas at a relatively low pressure. The actuator is operated by alternately connecting each of two chambers of the actuator to one of the low pressure chamber and the pressurized fluid source. In another described embodiment, a fluid containing chamber is connected to a low pressure chamber of an actuator to thereby bias one member to displace relative to another member.

Abstract: A subsurface well safety valve having a flow tube telescopically movable in a housing for controlling the movement of a valve closure member. A piston and cylinder assembly actuates the flow tube and is in communication with hydraulic control fluid from the well surface on one side and a gas biasing chamber on the second side and includes a spring acting on the flow tube to close the valve. An equalizing system equalizes fluid pressure on opposite sides of the piston and cylinder assembly in the event of a failure in the seal between the piston and cylinder thereby allowing the spring to close the valve. The equalizing system uses fewer components than previous designs and utilizes a new reference chamber design that allows the reference chamber and the piston to be positioned within the same axial length reducing the overall length of the safety valve over previous designs.

Abstract: Apparatus and method for operating a valve positioned in a wellbore. The apparatus includes a tubing having a bore and a piston operably coupled to the valve. The piston is moveable from a first position to the second position by predetermined pressure applied from fluid in the tubing bore. A counter mechanism coupled to the piston prevents movement of the piston to the second position until the predetermined pressure has been applied a first number of times.

Abstract: A formation isolation valve assembly for use in a well includes first and second fluid paths that are coupled to at least first and second completion zones. A first valve controls fluid flow from the first zone to the first fluid path, and a second valve controls fluid flow from a second zone to the second fluid path. The valves may include ball valves and sleeve valves.

Abstract: A downhole tool having selectively openable ports therein, the tool being actuable between a closed configuration in which the ports are closed, a primed configuration in which the ports are primed for opening, and an open configuration in which the ports are opened.

Abstract: A method for optimizing production from a gas lift well includes the steps of: obtaining a statistical model of production behavior of a gas lift well, the production behavior including known patterns of at least one production characteristic and corresponding operating parameters; operating the gas lift well at initial operating parameters; obtaining a real time value of the production characteristic from the gas lift well at the initial operating parameters; comparing the real time value of the production characteristic to the model to determine whether a known pattern is detected; and if a known pattern is detected, adjusting the operating parameters to the corresponding operating parameters. An apparatus is also provided.

Abstract: A multi-cycle circulating sub apparatus having a control member for controlling the movement of a sleeve between a first or closed position and a second or open position. The control member is slidably mounted in a body and is moveable by fluid pressure in the body in a first axial direction relative to the body. The control member also has a spring biasing the control member in an opposite axial direction of the body. A pin is secured to either the body or the control member. A central groove, in which a portion of the pin is received, is formed in the other of the body or control member. The central groove is shaped to limit axial displacement of the control member in response to pressure variations in the body such that only after a predetermined number of movements of the control member to a first limit position is the control member able to move to a second limit position to displace the sleeve into the second position. The apparatus may also be reset many times while remaining in a downhole position.

Abstract: Hydrocarbons are produced from a well having a bottomhole and a wellhead and communicating with a formation, by producing a flow of hydrocarbon-containing formation fluid from the formation at the bottomhole of the well, transforming the flow of the formation fluid from the formation at the location of transformation into a finely-dispersed gas-liquid flow with a liberated gas forming a part of the gas-liquid flow, so that a column of the formation fluid is formed in the well from the depth of the formation to the location of transformation, and a column of the finely-dispersed gas-liquid flow with a liberated gas is formed in the well between the location of the transformation and the wellhead, and automatically maintaining a pressure of the formation fluid at the bottomhole in the well higher than saturation pressure, substantially independently from changes in properties of formation and formation fluid.

Abstract: A dual in-line ball valve assembly for a subsea tree intervention tool has a pair of axially-movable pistons and a rotatable linkage member pinned between each of the pistons and the independently operable ball valves. The linkage members have eccentric hubs which rotate the ball valves between open and closed positions when the pistons are axially actuated. A recess is formed in each ball valve adjacent to the central flow passage of the assembly for accommodating a lower side of tubing or wireline. The recesses prevent shearing of the tubing or wireline in two places when one of the valves moves to the closed position.

Abstract: Apparatus including a releasable lock is provided. In a described embodiment, a valve assembly includes a ball valve, a piston, and a releasable lock. The releasable lock prevents operation of the ball valve until a predetermined fluid pressure is applied to the exterior of the apparatus.

Abstract: Methods and apparatus provide desired levels of continuous fluid pressure in a portion of a wellbore during completion operations. In a described embodiment, a method permits continuous fluid communication between a tubular string extending to the earth's surface and a portion of a wellbore below a packer during testing of the packer. This fluid communication enables a desired fluid pressure to be continually applied to a filter cake lining the portion of the wellbore, to aid in preventing compromise of the filter cake and possible collapse of the wellbore portion. A packer test device included in the apparatus permits such fluid communication during testing of the packer.

Abstract: A circulating valve and associated methods of servicing a well provide reliable operation, economical manufacture, and convenient maintenance in the circulating valve which is responsive to flow of fluid therethrough, and increased versatility in well servicing operations utilizing the valve. In a preferred embodiment, a circulating valve includes an upper case having a reverse circulating port formed radially therethrough, a circulating case having a circulating port formed radially therethrough, a lower adapter, a mandrel having a flow port formed radially therethrough, a biasing member, a ratchet, an inner sleeve, and a one-way flow restrictor carried on the mandrel. In an open configuration, fluid communication is permitted between the flow and circulating ports, and between the reverse circulating port and the flow restrictor. In a closed configuration, fluid communication is not permitted radially through the valve.

Abstract: An improved control system, particularly useful for SSVs, is disclosed. The control system has an operating piston which acts on a flow tube to move a flapper to an open position. The flapper is spring-loaded to close when the flow tube moves up. A return spring acts on the piston to lift the flow tube to allow the flapper to close. The operating piston is exposed to a control line from the surface as well as to a bypass piston. Opposing the hydrostatic forces of the control line is a pressurized chamber with a pressure in excess of the hydrostatic pressure. A secondary chamber acts on one side of the equalizing piston and is pressurized to a pressure less than the anticipated hydrostatic pressure in the control line. The system, including the operating piston, is configured so that when leakage occurs into or out of the control system in many places, the SSV will fail toward its failsafe closed position.

Abstract: An improved fluid actuator is provided. The fluid actuator (25) comprises a variable volume fluid chamber (124). A first tube (162) is fixed within the variable volume fluid chamber (124). The first tube (162) has a first sealing surface (142) and a second sealing surface (144). A piston (100) is slidably disposed within the variable volume fluid chamber (124) and slidably movable over the first tube (162) between a first position and a second position. The piston (100) comprises a first sealing surface (140) and a second sealing surface (146). The piston first sealing surface (140) and the first tube first sealing surface (142) cooperate to form a seal between the piston (100) and the first tube (162) when the piston (100) is in the first position. The piston second sealing surface (146) and the first tube second sealing surface (144) cooperate to form a seal between the piston (100) and the first tube (162) when the piston (100) is in the second position.

Abstract: A remedially deployable subsurface valve assembly is provided including a first tubing string, a first safety valve positioned in the first tubing string, a second tubing string, and a second safety valve positioned in the second tubing string. The first tubing string is a rigid production tubing string deployed in a hydrocarbon production wellbore extending beneath an earthen surface. The second tubing string is a flexible coiled tubing string remedially deployed in the interior of the first tubing string when the first safety valve fails. The second safety valve, which is located at the end of the second tubing string, is nested within the first safety valve to render the first safety valve inoperably fixed in the opened position. A seal, which is positioned in the annulus formed between the first and second tubing strings, defines a pressurizable segment of the annulus in pressure communication with the second safety valve.

Abstract: A landing collar is disclosed which defines a sealed cavity around its periphery. The landing collar has a seat to accept a sphere. Upon application of pressure on the sphere, the pressure rises on fluid in the chamber which surrounds the landing collar. At a predetermined pressure in the chamber, a rupture disc breaks which allows the fluid in the chamber to escape through a restrictor, thus regulating the rate of movement of the landing collar to expose gradually a bypass opening around the landing collar. Because the movement of the landing collar is regulated by the orifice adjacent the rupture disc, shock to the formation below is eliminated. In the event of sticking of the landing collar, an emergency release is possible since the landing collar is configured in two parts which can be pinned together.

Abstract: A reduced travel operating mechanism for downhole tools is provided. The reduced travel operating mechanism (57) includes a load ratio system (59) which may include compression ring (102) disposed within circumferential guide pocket (123) and a linkage system (61) disposed within mechanism pocket (125). The linkage system (61) may include first link (112), master link (114), and second link (116) coupled between compression ring (102) and connecting member (118). A loading system (63), which may include a hydraulic piston (100), acts on compression ring (102) to move compression ring (102) a first distance. Connecting member (118) moves a second distance in response to the movement of compression ring (102) a first distance. The linkage system (61) may operate such that the second distance is greater than the first distance or operate such that the first distance is greater than the second distance.

Abstract: A downhole wash tool for carrying out cleaning operations in a borehole. The tool has a housing on which a plurality of flow-blocking, diverters (e.g. steel) are mounted. The diverters move between a retracted position and an extended position wherein the diverters effectively block flow around the tool. A retainer normally maintains the diverters in their retracted position when in a first position and releases the diverters when in a second position. A spring normally biases the retainer towards its first position. The retainer is hydraulically-actuated through the housing to move it towards its second position. When the cleaning operation is completed, pressure in the workstring is relaxed whereupon the spring moves the retainer back to its first position to retract the diverters.

Abstract: An activating means for activating a down-hole tool incorporates a magnet, which may include an attracting magnet (12) and a repelling magnet (13), and which may move under hydraulic pressure from an active position at which it causes a trigger, valve (8) or spring to be energised to a non active position at which the tool is not activated, the activating means thereby utilising hydraulic pressure without requiring hydraulic ports in the liner or mandrel.

Abstract: A shifting tool for moving a movable member attached to a device in a downhole tool includes a body having a bore and a feed port connected to the bore. A diaphragm is mounted on the body for radial expansion to engage the movable member. The diaphragm is coupled to the feed port and is configured to radially expand to engage the movable member when fluid is communicated through the feed port at a predetermined inflate pressure. A position locator is used to locate the downhole device such that the body is positioned to permit the diaphragm to radially expand to engage the movable member.

Abstract: The invention is an assembly which is run into the wellbore to straddle pre-existing control line connections used normally for actuation of a sleeve for a single subsurface safety valve. The lower flapper is closed through the use of one of the control lines. It is then tested against formation pressure to make sure that it holds. Upon determination that the lower flapper is holding, the upper flapper is shut off using the other control line. By adding additional pressure to the control line for the lower sleeve, further movement of the lower sleeve is obtained to urge another sleeve into contact with the upper flapper to provide support for it so that it can be tested from above. Once the two flappers have been tested, uphole assembly in the wellbore can begin through the wellhead in the zone above the tested valves once assembled. Coiled tubing or wireline can be advanced sealingly through the wellhead as the assembly is lowered past the flappers which are now allowed to open.

Abstract: A method and apparatus for completing and backside pressure testing petroleum product wells for production, with one or more differential pressure valves being present at spaced intervals within a tubing string and with a well fluid transfer device being located in the tubing string. Either after or preferably before well casing perforation, after setting of the tubing string, casing pressure is elevated to a backside test pressure, above differential pressure causing closure of the differential pressure responsive valves to ensure the integrity of seals and packers. Casing pressure is then increased to a transfer valve opening pressure, above backside test pressure, to open unidirectional flow communication of well fluid from the well casing to the production tubing.

Abstract: A differential pressure operated blanking tool (1) for use in a completion automatically permits logging operations to be carried out in the absence of fluid flow in the tool (1). The tool (1) includes a pair of limbs (3,5) which communicate via a diverter (7) with a production tubing connection (4). In the absence of fluid flow within the tool (1), the diverter remains open to allow access for logging operations but is movable to a closed position occluding one of the limbs (3) as a result of a pressure differential established by fluid movement in the tool (1).

Abstract: A plug for actuating a movable member of a device in a wellbore includes a housing adapted to be lowered into the wellbore and a seal member mounted on the housing. The seal member is arranged to engage the movable member such that a pressure applied to the first end of the housing moves the housing and the movable member. A chamber is provided in the housing, and a pressure responsive member at an inlet end of the chamber permits fluid communication with the chamber when the pressure applied to the first end of the housing reaches a predetermined pressure.

Abstract: Completion method for avoiding formation impairment in the completion of a wellbore by anchoring and activating a plug at a selected position in the wellbore to seal off a selected portion of the wellbore from other portions of the wellbore. The plug is positioned at the selected position in the wellbore and anchored at that position. A seal in the plug is then activated such that fluid cannot pass the plug. Other parts of the wellbore can then be operated at different pressures than the isolated part of the wellbore without impairment of the formation resulting from the loss of well fluids into the formation.

Abstract: An annulus vent valve is provided to vent gas or other production fluids from below a packer set within a well in deep-set applications. The valve may broadly include: a body member having a first end, a second end, an outer surface, a longitudinal bore adjacent the second end, and at least one flow port extending from the longitudinal bore to the outer surface; a closure member mounted within the longitudinal bore to control fluid flow therethrough; a mechanism for biasing the closure member to a normally closed position to prevent fluid flow through the longitudinal bore; a closure member actuator disposed for movement within the longitudinal bore to open and close the closure member; a mechanism for biasing the closure member actuator away from the closure member; a piston connected to the closure member actuator and having a first end and a second end; and a gas chamber disposed within the body member and in communication with the second end of the piston.

Abstract: A well testing system is described which comprises a ball valve (10) having a plurality of fluid lines coupled thereto (20a, 20b, 20 c). The ball valve (10) is located between a process fluid flow line (16) and a vent line (18) with each fluid line (20a, 20b, 20c) being coupled to a respective piece of well-test equipment rated at a certain pressure value. Pressure relief means (22a, 22b, 22c) are located in each fluid line (20a, 20b, 22c) between the piece of equipment and said valve (10) and each pressure relief means (22a, 22b, 22c) is operable when the in-line fluid pressure exceeds a predetermined value to pass said fluid to said ball valve(10).

Abstract: A control system for the operation of the subsurface safety valve is disclosed. The control system uses a pressurized gas chamber, as well as a shuttle valve which connects to the main fluid pressure supply from the surface. The shuttle valve is connected to the gaseous chamber as well as to a barrier piston. As a result of the arrangement, leakages between the downstream side of the operating piston and the shuttle valve result in a reestablishment of the pressure balance on the operating system which allows the subsurface safety valve to close. Additionally, in the event of loss of gaseous pressure, the same pressure-balancing effect occurs on the operating piston, which allows the subsurface safety valve to go to a closed position. The configuration of the control system, which includes a gaseous chamber, allows for disconnection of the hydraulic fluid supply before the predetermined depth is reached to facilitate the connection of a tubing hanger.

Abstract: There is provided a circulating sub apparatus (50) having a tubular outer body member (51, 53, 54, 55, 56, 57) and a tubular inner body member (52, 65). The outer body member (51, 53, 54, 55, 56, 57) and the inner body member (52, 65) each have one or more holes (66, 68) substantially transverse to the longitudinal axis of the outer (51, 53, 54, 55, 56, 57) and inner (52, 65) body members. A displacement mechanism produces relative movement between the outer (51, 53, 54, 55, 56, 57) and inner (52, 65) body members such that the outer (51, 53, 54, 55, 56, 57) and inner (52, 65) body members may be repeatably moved between an aligned position, in which the one or more holes (66, 68) on the inner body member (52, 65) are aligned with the one or more holes (66, 68) on the outer body member (51, 53, 54, 55, 56, 57), and an obturated position, in which the one or more holes (66, 68) on the inner body member (52, 65) are obturated by the outer body member (51, 53, 54, 55, 56, 57).

Abstract: The present invention provides a tool for use in wellbores. The tool is operated by the wellbore hydrostatic pressure. The tool includes one or more devices that operate when a mechanical force is applied to such devices. The tool includes at least one atmospheric chamber. A setting member disposed in the tool is utilized to provide the mechanical force in response to the application of the hydrostatic pressure thereto. Prior to activating the tool, the setting member is locked or restrained in an inoperative position. To operate the device, the tool is placed at a suitable location in the wellbore. The atmospheric chamber is charged with the wellbore fluid, which releases the setting member from its restrained or locked position, subjecting the setting member to the wellbore hydrostatic pressure, thereby providing the mechanical force to operate at least one of the devices.

Abstract: A coiled tubing completion system is provided with a plurality of completion apparatus, all of which is designed flush with the diameter of the coiled tubing outside diameter for avoiding upsets and are flexible, spoolable on a coiled tubing reel and having through bores large enough to pass wireline tools for performing other operations. The spoolable coiled tubing system may use standard coiled tubing well control equipment and can be used in live wells. The flush, flexible, spoolable and through bore completion equipment may include a tubing retrievable safety valve, an annular control valve, concentric gas lift valves, a zone packer, a landing nipple, a sliding sleeve, and may include at the end a non-flexible but flush and open bore production packer and pump out plug. The completion system may be retrieved through a retrieval system.