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: A flapper valve assembly (120) for controlling fluid flow therethrough is disclosed. The flapper valve assembly (120) comprises a tubular valve housing having a valve chamber. A valve seat (124) is mounted within the housing. The valve seat (124) has a valve seat sealing surface (126). The valve seat (124) also has an internal load bearing shoulder (134). A flapper closure plate (122) is rotatably disposed within the valve chamber. The flapper closure plate (122) is rotatable between a valve open position in which the flapper closure plate (122) is removed from the valve seat (124) and a valve closed position in which the sealing surface (128) of the flapper closure plate (122) sealingly engages the valve seat sealing surface (126) for preventing flow through the flapper valve assembly (120). The maximum travel of the flapper closure plate (122) in the closed position is defined by the internal load bearing shoulder (134) of the valve seat (124).

Abstract: The invention relates to a method for controlling a device for transporting hydrocarbons in the form of a mixture of liquid and gas between production means (1) and a treatment plant (10). The method according to the invention for controlling a device comprising a hydrocarbons transport pipe (6) fitted with an adjustable-aperture outlet choke (9) to which a gas-injection pipe (16) fitted with a control valve (15) is connected, is characterized in that it includes a start-up phase which consists in performing the following sequence of steps: a step of initiating the transport of hydrocarbons, a step of ramping up to transport speed, then a production phase, during which phases the outlet choke (9) and the control valve (15) are operated in such a way as to maintain the stability of the pressure in the pipe (6) for transporting the hydrocarbons produced. The invention finds an application in the operation of off-shore oil production installations.

Abstract: A tubular wellhead member has an inner seal surface. A hydraulic passage extends through the wellhead member and terminates at a port at the seal surface. A tubing hanger having an outer mating surface lands in the wellhead member. A hydraulic line extends from a hydraulically operated downhole safety valve to a passage in the tubing hanger and terminates at a tubing hanger port. A seal is located at the tubing hanger port for sealing the junction with the tubular member port. A check valve is located within the seal to maintain the tubing hanger fluid passage closed until the tubing hanger lands in the wellhead. An adapter is employed to apply a running-in hydraulic fluid pressure to the tubing hanger hydraulic fluid passage with the check valve open. Then, the adapter closes the check valve to trap hydraulic fluid pressure in the line leading to the downhole safety valve. This pressure is sufficient to maintain the downhole safety valve in an open position during running in.

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: A connector permits separation of a submergible pumping system from its deployment system. The connector includes an upper assembly and a lower assembly that are connected by shear screws. A hydraulic separation mechanism is used to shear the shear screws and separate the upper and lower assemblies from a remote location.

Abstract: A connector is disclosed to facilitate the testing of a control line or lines adjacent a bottomhole assembly. A running tool is connected to a lower portion of the connector which is, in turn, connected to the bottomhole assembly. The running tool allows testing of the control line adjacent the bottomhole assembly and thereafter, the operation of components of the bottomhole assembly. The running tool is removed and the upper portion of the string, including the mating portion of the connector at its lower end, is inserted into the wellbore. The connector components are self-aligning and lock to each other downhole to complete the production tubing and the control line tubing to the surface. Multiple control lines are envisioned between the surface and the bottomhole assembly. Multiple connectors can be used in a given production string, and provisions can be made for operation of a multiplicity of downhole components from the control line system which extends along the production tubing.

Abstract: A system for transmitting hydraulic control signals and hydraulic power to downhole well tools while reducing the number of hydraulic lines installed in the wellbore. Hydraulic control signals can be furnished at relatively lower pressures, and the hydraulic pressure within the line can be selectively increased over a threshold level to provide hydraulic actuation power. The system can provide multiple control paths through a few number of hydraulic lines to provide flexibility and verification of well tool operation. Closed loop hydraulic operation monitors well tool operation, and a combination of pressurized hydraulic lines can provide an operating code for selective downhole well tool control. Four hydraulic lines can provide independent control and actuation of seven well tools, and additional combinations can be constructed.

Abstract: A control system for a subsurface safety valve (SSV) comprising of a control line from the surface in fluid communication with the top side of an actuating piston which moves a flow tube downwardly to open the SSV. A balance line runs from the surface to the bottom side of the same actuating piston to put the actuating piston in pressure balance. A buildup of pressure in the control line overcomes a return spring to open the valve, while removal of pressure from the control line allows the return spring to close the valve. Seals and leakpaths are provided through the actuating piston so that, depending on the hydrostatic pressure in the control line and the size of the return spring, the various failure modes of the actuating piston seals and control line or balance line will preferentially result in a fail-closed situation in the SSV.

Abstract: A pressure equalizing subsurface safety valve with a fluid injection system is provided. A fluid injection conduit is connected from a source of injection fluid, such as at the earth's surface, to the subsurface safety valve. A fluid flowpath is provided in the safety valve to transmit injection fluid from the fluid injection conduit to a longitudinal bore of the safety valve. The injection fluids are introduced into the longitudinal bore to resist corrosion of or other damage to the safety valve. The fluid may be injected into the longitudinal bore through a single port, or through a plurality of ports. The fluid injection conduit may also be used to equalize pressure above and below a closure member disposed within the safety valve prior to the opening of the closure member.

Abstract: A controlled release method for a submergible completion is disclosed wherein upper and lower interface assemblies are separated from one another in a predictable manner. A separation or release assembly is actuated remotely for forcing the interface assemblies apart. The release assembly may shear pins extending between portions of the interface assemblies. The interface assemblies may include multi-conductor electrical plugs or connectors which are separated during release.

Abstract: A tubular wellhead member has an inner seal surface. A hydraulic passage extends through the wellhead member and terminates at a port at the seal surface. A tubing hanger having an outer mating surface lands in the wellhead member. A hydraulic line extends from a hydraulically operated downhole safety valve to a passage in the tubing hanger and terminates at a tubing hanger port. A seal is located at the tubing hanger port for sealing the junction with the tubular member port. A check valve is located within the seal to maintain the tubing hanger fluid passage closed until the tubing hanger lands in the wellhead. An adapter is employed to apply a running-in hydraulic fluid pressure to the tubing hanger hydraulic fluid passage with the check valve open. Then, the adapter closes the check valve to trap hydraulic fluid pressure in the line leading to the downhole safety valve. This pressure is sufficient to maintain the downhole safety valve in an open position during running in.

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: The present invention is a combination wireline retrievable, side pocket locatable, fluid measurement and control assembly, which permits measurement and control of fluid from a first downhole production zone while maintaining fluid flow through the tubing from other downhole production zones. The various components of the fluid measurement and control assembly may be separately installed in or retrieved from by either wireline or coiled tubing intervention methods and can remain installed in the production tubing while installing or retrieving other downhole tools through wireline or coiled tubing intervention methods.

Abstract: A tubing retrievable surface controlled subsurface safety valve 106 is adapted to be positioned in a well tubing string 102 to control the flow through the tubing string. The safety valve includes an annular housing or body 200 defining a fluid passageway through which fluids and/or gasses may flow to the surface. The safety valve is equipped with a valve closure member such as flapper 252, positioned in the fluid passageway which is moveable between an open and closed position. The valve closure member is engaged and actuated by a longitudinally extending operator 242 that engages the valve closure member 252. In one embodiment, the longitudinally extending operator 242 may be a tubular member longitudinally moveable within the valve body. The longitudinally extending member 242 is operatively coupled to a spring guide 226. A biasing spring 222 is positioned in a spring chamber 120 defined by a spring housing 228 and the spring guide 226. A spring 256 biases the closure member 252 in the closed position.

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: A retainer valve provides increased safety in wellsite operations. In a preferred embodiment, operation of the retainer valve may be responsive to control line pressure or to tubing pressure. The retainer valve response is controlled by several factors, among which are relative tubing and balance line pressures, and axial positions of a number of pistons relative to a tubular J-slot member. If the control and balance lines are disconnected, or otherwise unavailable for operation of the valve, it may still be operated by manipulation of the tubing pressure at the earth's surface. Thus, the valve may be opened in emergency situations in which the control and balance lines are unavailable, but operation of the valve is still needed in order to safely relieve trapped pressure in the tubing string and/or to kill the well, unlatch a subsea test tree, etc. The retainer valve is also useful as a lubricator valve.

Abstract: A retainer valve provides increased safety in wellsite operations. In a preferred embodiment, operation of the retainer valve may be responsive to control line pressure or to tubing pressure. The retainer valve response is controlled by several factors, among which are relative tubing and balance line pressures, and axial positions of a number of pistons relative to a tubular J-slot member. If the control and balance lines are disconnected, or otherwise unavailable for operation of the valve, it may still be operated by manipulation of the tubing pressure at the earth's surface. Thus, the valve may be opened in emergency situations in which the control and balance lines are unavailable, but operation of the valve is still needed in order to safely relieve trapped pressure in the tubing string and/or to kill the well, unlatch a subsea test tree, etc. The retainer valve is also useful as a lubricator valve.

Abstract: A retainer valve provides increased safety in wellsite operations. In a preferred embodiment, operation of the retainer valve may be responsive to control line pressure or to tubing pressure. The retainer valve response is controlled by several factors, among which are relative tubing and balance line pressures, and axial positions of a number of pistons relative to a tubular J-slot member. If the control and balance lines are disconnected, or otherwise unavailable for operation of the valve, it may still be operated by manipulation of the tubing pressure at the earth's surface. Thus, the valve may be opened in emergency situations in which the control and balance lines are unavailable, but operation of the valve is still needed in order to safely relieve trapped pressure in the tubing string and/or to kill the well, unlatch a subsea test tree, etc. The retainer valve is also useful as a lubricator valve.

Abstract: A retainer valve provides increased safety in wellsite operations. In a preferred embodiment, operation of the retainer valve may be responsive to control line pressure or to tubing pressure. The retainer valve response is controlled by several factors, among which are relative tubing and balance line pressures, and axial positions of a number of pistons relative to a tubular J-slot member. If the control and balance lines are disconnected, or otherwise unavailable for operation of the valve, it may still be operated by manipulation of the tubing pressure at the earth's surface. Thus, the valve may be opened in emergency situations in which the control and balance lines are unavailable, but operation of the valve is still needed in order to safely relieve trapped pressure in the tubing string and/or to kill the well, unlatch a subsea test tree, etc. The retainer valve is also useful as a lubricator valve.

Abstract: A tubular wellhead member has an inner seal surface. A hydraulic passage extends through the wellhead member and terminates at a port at the seal surface. A tubing hanger having an outer mating surface lands in the wellhead member. A hydraulic line extends from a hydraulically operated downhole safety valve to a passage in the tubing hanger and terminates at a tubing hanger port. A seal is located at the tubing hanger port for sealing the junction with the tubular member port. A check valve is located within the seal to maintain the tubing hanger fluid passage closed until the tubing hanger lands in the wellhead. An adapter is employed to apply a running-in hydraulic fluid pressure to the tubing hanger hydraulic fluid passage with the check valve open. Then, the adapter closes the check valve to trap hydraulic fluid pressure in the line leading to the downhole safety valve. This pressure is sufficient to maintain the downhole safety valve in an open position during running in.

Abstract: A method and apparatus for selectively producing fluids from multiple lateral wellbores that extend from a central wellbore. The apparatus comprises a fluid flow assembly with a selectively openable and adjustable flow control valve in communication with a production tubing, located in the central wellbore between packers, and a lateral wellbore, and a selectively openable access door located adjacent the lateral wellbore allowing and preventing service tool entry into the lateral wellbore. The valve and door are individually controlled from the earth's surface.

Abstract: A retainer valve provides increased safety in wellsite operations. In a preferred embodiment, operation of the retainer valve may be responsive to control line pressure or to tubing pressure. The retainer valve response is controlled by several factors, among which are relative tubing and balance line pressures, and axial positions of a number of pistons relative to a tubular J-slot member. If the control and balance lines are disconnected, or otherwise unavailable for operation of the valve, it may still be operated by manipulation of the tubing pressure at the earth's surface. Thus, the valve may be opened in emergency situations in which the control and balance lines are unavailable, but operation of the valve is still needed in order to safely relieve trapped pressure in the tubing string and/or to kill the well, unlatch a subsea test tree, etc. The retainer valve is also useful as a lubricator valve.

Abstract: The artificial lift control system utilizes a piggy back line, flow computer, pressure transmitter, and software control to control artificial lift of wellbore fluids. The piggy back line is a medium to high pressure line strapped to the outside of the tubing. Supply, make-up gas or other fluids are pumped down the piggy back line at the lowest flow rate possible. Extremely low flow rates are utilized to minimize friction of flow in the piggy back line. A pressure or differential pressure transmitter is installed to monitor pressure on the piggy back line or to measure the differential pressure between the piggy back line and the casing pressure. The flow computer monitors pressures or differential pressures, utilizes software instruction sets to calculate fluid levels in the casing tubing annulus, and cycles artificial lift on and off based on parameters set in the flow computer software.

Abstract: The invention relates to a control system for a subsurface safety valve (SSV). A pressure-balance feature is introduced such that the control system components are unaffected by the depth of placement of the SSV. Through the use of this feature, the standard hydraulic control system used for surface components can also be used for an SSV regardless of its depth of installation. In another feature of the invention, a shuttle valve is provided so that each time the SSV is stroked, a volume of control fluid is purged into the annulus. One embodiment of the shuttle valve may or may not be sensitive to annulus pressure and employs annulus pressure as an aid to stroking the shuttle valve upon application of surface control pressure to assist in actuation of the SSV, while at the same time providing for a purge of a controlled volume of fluid.

Abstract: An annular wellhead member has an inner mating surface. The wellhead member has a auxiliary fluid passage with an inboard opening at the inner mating surface. A tubing hanger is landed concentrically within the wellhead member. The tubing hanger has an outer mating surface which mates with the inner mating surface of the wellhead member. A production fluid passage through the tubing hanger places the production tubing string in communication with a production line. A hydraulic line extends from a hydraulically operated downhole safety valve to the tubing hanger. A tubing hanger auxiliary fluid passage has a first opening and an outboard opening. The first opening is connected to the hydraulic line. The outboard opening is located on the outer mating surface of the tubing hanger and registers with the inboard opening of the wellhead member auxiliary fluid passage. The wellhead member auxiliary fluid passage is connected to a hydraulic supply line.

Abstract: A well control system for providing surface control of downhole production tools in a well. The well control system is capable of detecting well conditions and of generating command signals for operating one or more well tools. An electric conductor transmits electric signals, and a hydraulic line containing pressurized hydraulic fluid provides the power necessary to operate downhole tools. The invention provides a unique system for providing redundant conductors and redundant hydraulic lines to the well tool to continue operation if an electric conductor or hydraulic line becomes disabled. The well control tool also permits the selective operation of multiple production zones in a producing well.

Abstract: An integrated oilfield tubing string is provided with two continuous fluid-isolated interior passageways extending longitudinally therethrough, wherein the first interior passageway serves as a production or injection tube and the smaller second interior passageway serves as a service line. The second passageway has a crescentic cross section and is formed by affixing the longitudinal edges of an elongated arcuate band to the inside or outside of the tube while maintaining a space between the band and the tube wall. The internally and externally exposed surfaces of the tube and band define relatively smooth convex outside and concave inside surfaces of the integrated tubing string. The present invention further provides a method of constructing the integrated tubing string.

Abstract: An annular wellhead member has an inner mating surface. The wellhead member has a hydraulic fluid passage with an inboard opening at the inner mating surface. A tubing hanger is landed concentrically within the wellhead member. The tubing hanger has an outer mating surface which mates with the inner mating surface of the wellhead member. A production fluid passage through the tubing hanger places the production tubing string in communication with a production line. A hydraulic line extends from a hydraulically operated downhole safety valve to the tubing hanger. A tubing hanger hydraulic fluid passage has a first opening and an outboard opening. The first opening is connected to the hydraulic line. The outboard opening is located on the outer mating surface of the tubing hanger and registers with the inboard opening of the wellhead member hydraulic fluid passage. The wellhead member hydraulic fluid passage is connected to a hydraulic supply line.

Abstract: The specification discloses a system for recovering groundwater from a subterranean aquifer through an extraction well having a perforated casing extending down to the water table and a drop-tube within the casing to define an annular area between the casing and the drop-tube. A vacuum pump is connected to the drop-tube for inducing a flow of liquid up the tube. An aperture is provided through the wall of the drop-tube to enable gas from the annular area to enter the drop tube to mix with liquids flowing upwardly through the tube and reduce the density of the flowing fluid column so that it is more easily lifted to the surface. The aperture also provides a self-priming feature which avoids start-up problems associated with known vacuum dewatering methods.

Abstract: A well completion system comprises production tubing (5) extending downhole from wellhead equipment (2) to a plurality of completion systems (7, 8, 9). A well testing facility comprising a test loop (26) with flow metering equipement (27) is included in the wellhead equipment. Each of a plurality of independently adjustable flow control means (57) is operable to stop the flow of fluid from a respective one of the completion assemblies into the production tubing. The downhole completion assemblies (7, 8, 9) are mounted on a common fluid and electrical supply means (4) comprising tubular electrical conductor means (42) and tubing (41, 45, 46) defining fluid paths.

Abstract: The invention relates to a control system for a subsurface safety valve (SSV). A pressure-balance feature is introduced such that the control system components are unaffected by the depth of placement of the SSV. Through the use of this feature, the standard hydraulic control system used for surface components can also be used for an SSV regardless of its depth of installation. In another feature of the invention, a shuttle valve is provided so that each time the SSV is stroked, a volume of control fluid is purged into the annulus. One embodiment of the shuttle valve may or may not be sensitive to annulus pressure and employs annulus pressure as an aid to stroking the shuttle valve upon application of surface control pressure to assist in actuation of the SSV, while at the same time providing for a purge of a controlled volume of fluid.

Abstract: The specification discloses a system for recovering groundwater from a subterranean aquifer through an extraction well having a perforated casing extending down to the water table and a drop-tube within the casing to define an annular area between the casing and the drop-tube. A vacuum pump is connected to the drop-tube for inducing a flow of liquid up the tube. An aperture is provided through the wall of the drop-tube to enable gas from the annular area to enter the drop tube to mix with liquids flowing upwardly through the tube and reduce the density of the flowing fluid column so that it is more easily lifted to the surface. The aperture also provides a self-priming feature which avoids start-up problems associated with known vacuum dewatering methods.

Abstract: A tandem safety valve for use in a tubing string in a wellbore has a pair of identical valves disposed in a valve housing. Each valve has a flow tube for selectively opening and closing each valve. Each valve is provided with an hydraulic normal-operation actuator and an hydraulic looking actuator. The normal-operation actuator and locking actuator are selectively engaged with the flow tube disposed within the valve housing. Each flow tube is provided with a latch to releasably engage the normal-operation actuator, and a a locking dog to selectively engage the flow tube in a locked-open position. The locking actuator engages the latch to release the normal-operation actuator from engagement with the latch and to permit the locking dog to engage the valve housing to maintain the flow tube and valve in a locked-open position.

Abstract: A hydraulic safety pin is interconnected between a device, such as a pressure controlled firing head associated with a perforating gun, and a small diameter tubing in a wellbore. When, the small diameter tubing is filled with fluid under pressure, the hydraulic safety pin allows the fluid to fill the small diameter tubing but prevents the pressure of the fluid in the small diameter tubing from accidentally detonating the firing head when the pin is disposed in a first position; however, when the tubing is already filled with fluid under pressure, the hydraulic safety pin allows the pressure of the fluid in the small diameter tubing to detonate the firing head when the pin is disposed in a second position. The hydraulic safety pin may be installed in a special coupling, and multiple special couplings may be used in a tool string disposed in a wellbore.

Abstract: A surface controlled, subsurface safety valve in which a force due to control pressure fluid from a first source at the surface for opening the valve is opposed in part by a force due to reference pressure fluid from a second source at the surface, whereby the valve closes in response to a fail condition.

Abstract: A safety valve landing nipple selectively provides communication between a surface control line and the internal bore of said landing nipple by use of a rotary member. A rotary shifting tool is used to rotate the rotary member so that a cutting means shears the end of a shearable plug in the wall of the landing nipple, so as to provide communication between the surface control line and the internal bore of the landing nipple. A method of providing communication within a landing nipple between the surface control line and the internal bore of the landing nipple by use of the rotary shifting tool and a rotary shifting tool having a rotatable outer mandrel means, an inner mandrel means, a travel means and a diametrically retractable means.

Abstract: Well tools are provided which although pressure responsive, may be maintained by a hydraulic lockout in a nonresponsive condition until a threshold actuation step is performed. This lockout may be achieved by a hydraulic mechanism which allows pressure to be stored in a fluid spring during periods of increased pressure at the pressure source, and which traps these pressures even when pressure at the pressure source is reduced. When the tool is desired to be responsive to pressure cycles, a valve may be opened communicating the pressure in the fluid spring to a movable member in the well tool. This differential may be established by a differential between the pressure in the fluid spring and the pressure source. Communication of pressure in the fluid spring to a movable mandrel will then allow operation of the well tool in response to pressure cycles at the pressure source in accordance with the established design of the well tool.

Abstract: Locking closed a subsurface safety system in a well production tubing from the well surface by releasably holding the subsurface safety valve in the open position. Thereafter closing the subsurface safety system from the well surface through a control line extending exteriorly of the production tubing. Thereafter preventing the safety system from being opened through the control line.

Abstract: A subsurface well safety valve for controlling the fluid flow through a well conduit which includes an equalizing line and an equalizing valve in the line. The equalizing line includes a passageway through the interior of the power spring which biases the safety valve to the closed position thereby routing the equalizing line through a simpler and less expensive structure. The equalizing valve is connected to the safety valve flow tube and is movable to a closed position in response to the power spring and is movable to an open position in response to the actuating piston and cylinder assembly.

Abstract: A release mechanism for use in a well tool that requires a hydraulic piston area to be equalized with a minimum force. A valve seat and valve element are positioned in a fluid passageway for actuating the assembly. A rod having a first and second section is connected to the assembly and movable for moving the second section into the valve seat. The second section has a smaller cross-sectional area and smaller length than the first section. The area of the valve seat is less than the cross-sectional area of first section but larger than the second section. The release mechanism allows the sealing area to be reduced without reducing the strength of the rod.

Abstract: In a safety valve having an axially shiftable actuating sleeve operable to move a valve head from a closed to an open position, the actuating movement of the actuating sleeve is normally produced by a small diameter piston mounted on an axially extending spindle secured to the valve housing and cooperating with a primary cylinder which is secured to the actuating sleeve by a shiftable latch. A secondary spindle and cooperating cylinder are provided which are supplied with fluid pressure by an entirely separate line. The secondary cylinder, when moved downwardly by fluid pressure, engages the latch to effect a disconnection of the primary cylinder from the actuating sleeve and concurrently effects the connection of the secondary cylinder to the actuating sleeve. The second cylinder may thus release the primary cylinder from the actuating sleeve in any position of the primary cylinder, including the position corresponding to the fully open position of the valve head.

Abstract: A process and device for hydraulically and selectively controlling, in two circulation directions, at least two tools or instruments connected to a casing located inside a well. A first hydraulic line is provided which includes branches to a first and a second of the two tools or instruments, with a distribution arrangement being adapted to modify a circulation of fluid in each of the branches and to enable an independent control, and with a hydraulic power generator being connected to the first hydraulic line.

Abstract: A method and apparatus for replacing a defective downhole well safety valve of the full bore type by a wireline valve sealably insertable in the bore of the housing for the defective valve by wireline and operating the wireline inserted safety valve by fluid pressure supplied through an existing control fluid passage provided in the original safety valve housing. An internally projecting integral protuberance is provided in the bore of the original safety valve housing and a connecting fluid conduit is provided between the interior of the protuberance and the existing control fluid passage. A cutting tool is mounted on an axially shiftable sleeve disposed immediately above the protuberance. The axially shiftable sleeve is manipulated by an auxiliary tool temporarily inserted in the bore of the original valve housing and causing the cutting tool to remove the protuberance and thus establish fluid communication for the control fluid with the internal bore of the original safety valve housing.

Abstract: A method and device for carrying out operations and/or manipulations in a well which has a casing with the well being and drilled in geological formations having at least two distinct zones.The device according to the invention is characterized in particular by casing (3) having, in its interior, a first connector (10) usable in a liquid medium, the first connector being connected by lines (40) to at least one instrument and/or tool (11, 14, 16, 18, 34, 35, 36, 37) disposed in each of zones (30, 31, 32, 33), the first connector (10) being designed to cooperate with a second connector (21) connected by a transmission cable (22) to the surface of the ground, casing (3) being designed to permit the second connector to be lowered from the surface and connect with the first connector. The casing has, in an interior thereof, a first connector usable in a liquid medium, with the first connector being connected by lines to at least one instrument and/or two disposed in each of the zones.

Abstract: A well testing tool includes a plurality of valves, a plurality of well tool control systems connected, respectively, to the plurality of valves, and an electronics section connected to the plurality of well tool control systems for energizing one of the control systems thereby opening or closing a valve associated with the one control system when the electronics section of the tool detects the existance of an input stimulus transmitted downhole by an operator at the well surface. The operator need only know the particular input stimulus to transmit for a particular valve and need not know how many well tools are disposed downhole or in which tool a particular valve is disposed. The opening or closing of a particular valve is accomplished independantly of any other valves disposed in the tool.

Abstract: A method and apparatus for recompleting an oil and/gas well inside of an existing well tubing in a well by supporting a coil tubing in the well tubing from a hanger assembly. A hydraulically actuated safety valve is connected in the coil tubing for controlling fluid flow through the coil tubing and is controlled by a hydraulic line connected to the safety valve and extending to the well surface outside of the coil tubing and inside of the well tubing. Packing is provided between the coil tubing and the well tubing and may include a well packer and/or annular safety valve. Gas lift mandrels may be connected to the coil tubing above the packoff.

Abstract: A subsurface well safety valve having two control lines which run from the well surface to first and second piston and cylinder assemblies for controlling the valve. The first of the assemblies is connected to a flow tube for operating the valve but the second assembly is disconnected from the flow tube. When a failure occurs in the primary control system, the first assembly is disconnected from the flow tube and the second piston and cylinder assembly is connected to the flow tube to operate the safety valve.

Abstract: A hydraulic system has a filter that filters only when the fluid is flowing in one direction. The filter is located in a flow passage between a hydraulic fluid source and a valve in a well. The source supplies hydraulic fluid pressure in a forward direction to keep the valve open. A bypass passage allows hydraulic fluid to bypass the filter. A check valve located in the bypass passage prevents forward flowing fluid from flowing through the bypass passage. If hydraulic pressure is lost, hydraulic fluid will return through the bypass passage, rather than flowing through the filter, to allow the valve to quickly close.