Abstract: The present invention relates to a downhole packer assembly for expansion of a metal sleeve, such as a metal patch, in a well downhole in a well tubular metal structure, comprising a body part and an expandable tubular element surrounding the body part and each end of the expandable tubular element being connected with the body part, providing an expandable space therebetween, the expandable space being fillable with liquid during expansion, the expandable tubular element having an outer face and an inner face, the expandable tubular element comprising an elastomeric or rubber material having a friction coefficient, wherein the expandable tubular element comprises a friction-enhancing material providing a higher friction coefficient of the outer face than the friction coefficient of the elastomeric or rubber material. The invention also relates to a downhole system comprising the downhole packer assembly and a positive displacement pump for expanding the expandable tubular element.

Abstract: An inflatable packer assembly may include a housing and a shifting sleeve disposed within the housing. The shifting sleeve may have one or more sleeve ports formed therein. An actuator may be coupled with the shifting sleeve. The actuator may be electrically actuated between a plurality of positions. One or more inflatable packers may be coupled with the housing, the housing having one or more ports formed therein. Actuation of the actuator may shift the shifting sleeve in order for the one or more sleeve ports to enter into fluid communication with the one or more ports of the housing in order to inflate or deflate the inflatable packers.

Abstract: A pressure equalization apparatus can include separate longitudinal bores which form a continuous flowpath, the flowpath alternating direction between the bores, and the bores being interconnected at opposite ends thereof. A well system can include a well tool with a chamber therein containing an assembly in a dielectric fluid, and a pressure equalization apparatus including a flowpath having one end connected to the chamber, and the other end connected to a source of a another fluid, the flowpath extending in opposite directions between the flowpath ends through multiple separate bores. A method of installing a well tool can include attaching a mandrel to the well tool, then lowering the well tool at least partially into the well suspended from the mandrel, and then securing a pressure equalization apparatus to the mandrel, a flowpath of the apparatus being connected to a chamber of the well tool containing an assembly.

Abstract: An annular barrier for being expanded in an annulus includes a tubular part mounted as part of the well tubular structure, the tubular part including an opening and an inside having an inside pressure, an expandable metal sleeve surrounding the tubular part and having an inner face facing the tubular part and an outer face facing the wall of the borehole, each end of the expandable metal sleeve being connected with the tubular part, an annular space between the inner face of the expandable metal sleeve and the tubular part, and a valve system having a first valve and a second valve, the second valve allowing pressurised fluid into the annular space to expand the expandable metal sleeve and preventing fluid from flowing from the annular space to the inside of the tubular part.

Abstract: Embodiments of the present disclosure include a test dart for wellbore pressure isolation. The test dart includes a body extending from a first end to a second end, the body having a bore extending therethrough, a diameter of the bore being greater at a first end than the second end. The test dart also includes a groove formed proximate the first end and extending radially outward from the bore and into the body. Additionally, the test dart includes an anti-rotation pin positioned between the groove and the second end, the anti-rotation pin extending radially outward from the body. The test dart further includes a check valve positioned in the bore, the check valve enabling flow in a single direction and being moveable between an open position to enable the flow and a closed position to block the flow.

Abstract: A technique facilitates the anchoring and use of a downhole tool. The technique may be utilized with operations in which fluid is pumped or otherwise flowed through a tubular to the downhole tool. The operations are performed after the downhole tool has been fixed relative to the wellbore and while the tubular remains connected to the downhole tool. In some operations, the downhole tool is manipulated from the surface via the tubular to control placement of the fluid flowing down through the tubular.

Abstract: An annular barrier to be expanded in an annulus between a well tubular structure and a wall of a borehole downhole, includes a tubular metal part for mounting as part of the well tubular structure having an outer face; an expandable sleeve surrounding the tubular metal part and having an inner face facing the tubular metal part and an outer face facing the wall of the borehole, each end of the expandable sleeve being connected with the tubular metal part; and an annular space between the inner face of the expandable sleeve and the tubular metal part, the annular space having a space pressure. The annular barrier has an anti-collapsing unit with an element movable at least between a first position and a second position, the anti-collapsing unit having first and second inlets and an outlet arranged to allow equalization.

Abstract: A process for plugging a wellbore, e.g. an oil or gas well, comprises installing a choke device (1) into the wellbore in order to increase the back pressure to allow better control when introducing cement to plug the wellbore. The device (1) has a cylindrical shape with a central through bore (6). On the external profile is a shoulder (4) which, when the device is installed in a wellbore, comes to rest against a nipple in the wellbore. The device (1) may free fall for all or part of the way down but would normally be pumped down at least for the last part of its delivery. In the bore (6) is a pump out ball (10) which blocks the through bore until the device reaches the nipple and stops, at which point pressure increases and the ball is ejected. Cement and other liquid may then be pumped through the choke device to the distal region of the well.

Abstract: A bottom hole assembly to enable reperforation and refracturing a cased hole has a bottom end anchor seal to allow a larger drift dimension in the zones to be perforated and fractured between spaced external seals that preferably set by swelling. A separable section has a seal bore to protect lower pressure rated casing in the upper annulus from overpressure during the refracturing operations. Either existing perforations can be refractured or new perforations made and fractured. With a multiple shot perforating gun all the zones can be perforated and fractured in a single trip with a service string that supports a releasable plug, a gun and frac ports. The BHA can be remove with a line cut above the anchor seal at the bottom and a pull on the tubular sting that takes all the swelling packers out. Location devices can be employed for proper gun placement before firing.

Abstract: An assembly that is usable with a well includes a base pipe, a shroud that is disposed radially outside of the base pipe and tubes. The tubes are disposed radially outside of the base pipe and are radially inside the shroud. The tubes longitudinally extend along the base pipe and radially expand to radially expand the shroud in response to pressurization of the tubes.

Abstract: Methods of controlling flow into a formation through the use of a stimulation valve in a tubular assembly installed in a well. Fluid is pumped into the formation through one or more ports in the stimulation valve. The stimulation valve defines a conduit for flow of fluids through the stimulation valve. The ports are adapted to allow flow of fluids between the conduit and the exterior of the stimulation valve and to receive a ball sealer for shutting off flow of fluids through the ports. The ports then are closed by introducing a plurality of ball sealers into the fluid. The fluid carries the ball sealers into the valve where they seat on and shut off flow of the fluid through the ports.

Abstract: The present disclosure introduces pressure-equalized packaging for electronic sensors utilized in conjunction with downhole tools and/or other extreme environments. Such sensors may be operable to detect, sense, and/or measure a parameter, such as may be associated with the downhole tool, or pressurized fluid in which the downhole tool is at least partially submerged, or a subterranean formation adjacent the downhole tool. A housing couples the sensor to a component of the downhole tool. The housing includes an equalizer operable to substantially equalize a first pressure internal to the housing with a second pressure external to the housing.

Abstract: An actuating apparatus for a downhole valve including a tubular body. The tubular body includes an axial bore that extends through the body. An inlet port extends radially and at least partially through the tubular body. When open, the inlet port is arranged to be in fluid communication with a region uphole of the actuating apparatus. The actuating apparatus also includes an actuating member that is operable by application of fluid pressure from a region uphole of the actuating apparatus via an open inlet port to actuate the valve.

Abstract: A downhole pumping system in production tubing having a seal between the intake and discharge of a through tubing downhole pump that automatically deploys when the pump initiates operation. The seal automatically disengages when the pump suspends operating and redeploys when the pump starts operating again. The pumping system can be set at a different depth before restarting the pump. The seal can include a bladder like member that has an opening facing towards the pump discharge, so that discharged fluid expands the bladder radially outward into sealing contact with the tubing.

Abstract: A method for wellbore treatment includes running a liner into a wellbore, the liner including a wall, an inner bore defined by the wall, a first port through the wall, a second port though the wall spaced axially from the first port, a first removable closure for the first port and a second removable closure for the second port; positioning the liner in an open hole section of the wellbore to create an annulus between the liner and a portion of the wellbore wall and with the second port downhole of the first port; inserting a treatment string assembly into the liner, the treatment string assembly including a tubing string and an annular seal about the tubing string and being insertable into the inner bore of the liner; setting the annular seal to create a seal between the tubing string and the liner downhole of the second port; and while the first port is closed to fluid flow therethrough, pumping wellbore treatment fluid into an annular area between the tubing string and the liner such that the fluid passes

Abstract: System, devices, and methods are described relating to the treatment (e.g., perforating, fracturing, foam stimulation, acid treatment, cement treatment, etc.) of well-bores (e.g., cased oil and/or gas wells). In at least one example, a method is provided for treatment of a region in a well, the method comprising: positioning, in a well-bore, a packer above the region of the well-bore, fixing, below the region, an expansion packer, treating the region, the treatment fixing the packer, moving the expansion packer, and moving the packer after the moving of the expansion packer.

Abstract: A tool includes an integrated hydraulic setting and hydrostatic setting mechanism that has a first part responsive to hydraulic pressure applied through a conduit, and a second part responsive to hydrostatic pressure. An activatable element can be activated by the integrated hydraulic setting and hydrostatic setting mechanism.

Abstract: A fluid isolating pressure equalization in a subterranean well. A well system includes a well tool including a chamber therein containing an electrical assembly in a dielectric fluid, and a pressure equalization apparatus including a flowpath having opposite ends. One end is connected to the chamber, and the other end is connected to a source of another fluid. The flowpath extends alternately upward and downward between the opposite ends. A pressure equalization apparatus for use with a well tool in a subterranean well includes multiple spiral wraps of a tube. A flowpath in the tube extends in opposite directions in respective successive wraps of the tube.

Abstract: A method and apparatus for controlling inflation and deflation of spaced inflatable packer elements of a straddle stimulation tool within a well casing of a well. A straddle stimulation tool is positioned by tubing at a desired location within the well casing. Fluid is pumped through the tubing and tool at a rate inflating the spaced inflatable packer elements within the well casing and establishing an annulus interval. The inflation control retains pressure within the inflated packer elements and permits the flow of stimulation fluid into the annulus interval for stimulation of the formation. After completion of well stimulation, the packer element pressure control is moved to a packer equalizing position by tension applied via the tubing to equalize packer pressure with casing annulus pressure, deflating the packer elements and permitting conveyance of the straddle stimulation tool within the well casing by the tubing string.

Abstract: Subterranean reservoir monitoring method, computer system with programming code for implementing the method, and computer readable media and data signal embodying such programming code, the method including one or more of: (a) reservoir screening; (b) reservoir modeling; (c) generating model seismic data from a model; (d) model modification based on current VSP data; (e) repeating step (c) and step (d) until differences between the model and VSP data are as desired; (f) obtaining model production data from a reservoir model, and if necessary modifying the model and returning to step (c); (g) generating seismic model data for time t; and (h) comparing seismic model data with actual seismic data for time t, and if necessary modify the reservoir model and return to step (f) or modify the model of the subteranean and return to step (c).

Abstract: The present invention relates to bypass valves for use in wellbores, particularly but not exclusively to bypass valves used during the setting of hydraulic anchor packers. A bypass valve (2) is provided with a piston (30) slidably mounted adjacent a body member (4) having at least one opening (20) extending therethrough. The piston (30) is moveable between a first position establishing a passage from the interior of the body (4) to the exterior thereof via the at least one opening (20) and a second position isolating the interior of the body (4) from the exterior thereof. A second piston may be provided for increasing, in response to a predetermined fluid pressure differential across the length of the piston (30), the force exerted on the piston (30) by a given flow of fluid through the bypass valve (2) such that the resultant force on the piston (30) is insufficient to move the piston (30) to the second position.

Abstract: The present invention generally provides a system and method for selectively sealing a drill string or other tubular member. In one aspect, a sealing member, such as a valve, allows a certain level of flow of drilling fluids and/or other fluids through one or more flow channels when the valve is open. To close the valve, the flow rate is increased so that a backpressure develops and urges the valve to a closed position. The valve can remain in position in the drill string and alternately open and close depending on the flow rate and/or the pressure drop through the valve. The valve also comprises a removable plug disposed in the valve to provide access with, for example, wireline tools to a region below the valve in a wellbore.

Abstract: Downhole apparatus (10) for mounting on a string (12) for location in a drilled hole is provided, the apparatus comprising: a tubular body (14) defining a bore; a packer (16) mounted on the body (14) for sealing the annulus between the body (14) and the wall of the hole; a plug or valve (18) for closing the body bore (14) below the packer (16); a fluid actuated valve (20) in the body between the bore closing valve (18) and the packer (16) for permitting selective fluid communication between the body bore and the exterior of the body, and an arrangement (22) for transferring fluid pressure from above the packer (16) to the valve (20), whereby fluid pressure applied to the annulus above the packer (16) may be used to operate the valve (20).

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 release mechanism for use with setting wellbore isolation tools, such as packers or bridge plugs. The release mechanism typically includes a release piston which selectively isolates equalization ports extending from the interior to the exterior of a setting tool body. The release piston may be activated to allow equalization of pressure across the sealing elements of a set isolation tool, typically by applying pressure to the annular space above the isolation tool. The release mechanism may be used to allow a tool body (such as a setting or retrieving tool) to be removed from a set isolation tool under conditions in which high pressure differential exists across the isolation tool.

Abstract: Apparatus for use in setting packers and other fluid actuated devices includes a tubular body (222), a valve (228) for controlling the flow of well fluid through a port (234) in the body (222) and a valve actuator (224) mounted on the body (222) and movable relative thereto, to open the valve (228) by application of well fluid pressure. The well fluid may flow through the open valve (228) to set a packer or actuate a device.

Abstract: An oil well tool for installation in a production tubing string to provide valved gas communication between the interior of the tubing string and the annulus between the tubing string and casing for improving production from the well. The tool includes a thick walled tubular body for in-line threaded connection in a tubing string and includes valved passageways for the automatic transfer of gas from the annulus into the interior of the tubing string when the pressure in the annulus exceeds the pressure in the tubing string by a designed differential. The tool can be installed in the well in various arrangements for improving production of the well.

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: A gas diverter tool is disclosed for use in improving the operation of an oil and gas well that has cracks, holes or leaks in the casing. The tool includes a thick walled tubular body for in-line threaded connection within a tubing string below a packer carried by the tubing string. The thick wall of the tubular body includes four circumferentially spaced passageways extending longitudinally therethrough to provide gas inlet openings. The upper ends of the passageways are removably closed, and the lower ends are diametrically reduced to provide valve seats. Spherical check valves are loosely received within the passageways above to seat downwardly against the valve seats. Elongated wiper rods are loosely slidable in the passageways and downwardly abut against the ball valves to hold the check valves closes.

Abstract: A packer is disclosed which uses applied pressure to set the slips and initiate a compressive force on the sealing elements. The compressive force applied to the sealing elements moves components above the sealing elements and allows the available hydrostatic pressure in the wellbore to create an opposing force on the sealing elements to ensure that they properly set. The sealing elements are mounted directly to the packer body, thus eliminating a leakpath from the fluid pressure application port which is located below the sealing elements on the packer body. Various lock rings hold the set of the packer to avoid the creation of boost forces on the sealing elements from applied or induced pressures from above or below the sealing elements. Movement of the body is not required to accomplish setting of this packer. In applications with low hydrostatic pressure, the annulus can be pressurized to assist in obtaining the necessary pack-off pressure.

Abstract: A firing head adapted to connected between a coiled tubing and a perforating gun, is sized and shaped to enable it to move freely within a tubing string in the wellbore, may be actuated by fluid pressure within the coiled tubing, and includes a circulation and recirculation feature wherein wellbore fluid may be circulated through the firing head between the coiled tubing and an annulus around the tubing string, the circulation taking place either before or after detonation of the perforating gun. Three firing heads are discussed. One such firing head is a Circulation Direction Firing (CDF) Head. The CDF firing head circulates fluid from the wellbore to the coiled tubing and depresses a piston. Then, fluid pressure from the coiled tubing lifts the piston uncovering locking balls and propelling a firing pin to a booster of a detonating cord detonating the CDF firing head. Fluid circulation from the coiled tubing to the wellbore annulus begins after the CDF firing head detonates.

Abstract: A casing inflation packer for use in a casing string in a well bore. The apparatus includes a housing connected in the casing string. An inflatable packer portion on the housing sealingly engages the well bore when inflated. An inflation passageway is defined between a housing central opening and the packer. A rupture disc is initially disposed between the central opening and the inflation passageway for preventing communication therebetween. The rupture disc ruptures in response to a first predetermined pressure, thereby placing the central opening in communication with the packer through the inflation passageway. A slidable control valve is disposed in the inflation passageway and is initially shearably held in an open position. Upon application of a second predetermined pressure across the valve, the valve is moved to a closed position, thus preventing overinflation of the packer and also preventing deflation thereof.

Abstract: A combination packer/safety valve assembly is connectable to the bottom end of a tubing string and lowerable therewith into the casing string portion of a gas storage well to control the upward flow through the casing string of pressurized gas stored in a subterranean cavern below the casing string. In response to the delivery through the tubing string to the interior of the assembly of control fluid at a first predetermined pressure a normally closed, axially extending interior passage of the assembly is opened to permit upward flow therethrough of pressurized gas for delivery to the well surface through the casing string.

Abstract: Method and means for preventing fluidization or mobilization of a gravel pack in a fluid producing well as a result of increased fluid pressure caused by a well shut-in or other pressure surge. A pressure relief valve in the form of a check valve is provided in a tubing string below a packer surrounding the string and above the top of the gravel pack. The check valve is held in closed position by a biasing force, such as a spring, which is less than the pressure which will cause mobilization or fluidization of the gravel pack. A pressure surge such as a well shut-in or flow rate decrease increases tubing pressure which causes the check valve to open, thereby relieving the pressure in the gravel pack to a point below the critical level.

Abstract: Wellbore fluid flow rates and other fluid properties may be measured by a tool which is insertable in the wellbore on the end of a tubing string and includes an instrument section and an inflatable packer disposed on the tool for inflation by conducting pressure fluid down the tubing string to the packer. A control valve disposed on the tool is hydraulically shiftable between first and second positions for conducting fluid from the tubing string to the packer and from the packer to the exterior of the tool. The valve may be actuated by fluid conducted down the tubing string. The tool includes housing parts having respective cavities for conducting wellbore fluid through a flowmeter and for containing instrument circuit enclosures disposed therein. Pressure fluid bypasses the cavities through elongated passages formed in the tool housing parts along or adjacent to the outer periphery of the housing parts. A frangible coupling is interposed in the tool between the packer and the instrument section.

Abstract: A non-return valve for bore hole sleeves, which are intended for injection of a sealing and/or reinforcing compound into rock cracks and similar cracks and which comprise a rigid case (10), one end (10A) of which is provided with means for detachable connection to the case of a pump hose (12) for the compound to be injected, as well as an expandable device (15) for securing the rigid case in the bore hole (21), comprises an elastic sleeve (22) which is adapted at the other end (10B) of the rigid case (10) in such a way that the rigid case (10) runs into the elastic sleeve (22). The elastic sleeve is adapted for automatical contraction, when no compound is being injected through the elastic sleeve, so that already injected compound can not flow backwards into the rigid case (10). The sleeve (22) is preferably provided with diametrically positioned clamp means (23-26) at its free ends, so that the free end of the sleeve has a flat shape, when no compound is being injected through the elastic sleeve.

Abstract: A lower formation of a multizone well is perforated by a perforating gun lowered by wireline, and then fractured. A packer (modified Pengo packer) with a central bore and a valve seat is positioned within the casing between the lower and upper formations. A plug is set into the packer valve seat by a perforating gun and released by shearing a shear pin. The well is pressurized to maintain the plug in the valve seat, the perforating gun raised, and the casing opposite the upper formation perforated. The gun is removed, and the upper formation fractured. After a suitable flow-back period, another packer is then positioned in the casing above the upper perforated formation. The pressure differential between formations maintains the plug seated, allowing the upper formation to be produced. When a change in pressure differential raises the plug off the valve seat, the lower formation may be produced.

Abstract: Improved apparatus for packing particulates such as sand, gravel, or the like, around a well screen in a well for sand control, the apparatus having provisions for packing the particulates tightly in place without relying on settling due to gravity, thus requiring minimal distance between the packer and the casing perforations. Methods of performing such packing operations are also disclosed.

Abstract: A combination multiple stage cementing tool and casing inflation packer includes an inflatable packer having a packer mandrel and an inflatable packing element disposed about the mandrel. A cementing tool includes a cylindrical outer casing, a cementing port disposed through a side wall of the casing, and a sliding sleeve valve assembly for opening and closing the cementing port. The cylindrical outer casing of the cementing tool is permanently attached to the packer mandrel and has a maximum outer diameter at least as great as a maximum outer diameter of the inflatable packing element when the inflatable packing element is in an uninflated position.

Abstract: A valve system for use in inflating packers mounted on mandrels is disclosed. The valve system uses one or more valves to permit, through the use of seals, the flow of fluid form the interior of a tubular mandrel to the interior of the inflatable packer when pressure applied in the mandrel exceeds at least a minimum pressure. In two embodiments, inflation of the packer beyond a given pressure is prevented. In all embodiments, the differential pressure across reciprocating seals is minimized through exposure of one or both sides, directly or indirectly, to the external pressure of the mandrel and packer.

Abstract: In accordance with an illustrative embodiment of the present invention, a pressure controlled reversing valve includes a housing having a flow passage and ports to communicate the passage with the well annulus outside the housing, valve means for normally closing said ports, valve operator means movable upwardly and downwardly in said housing in response to changes in the pressure of fluids in said annulus, lost-motion coupling means for enabling movement of said operator means independently of said valve means so long as said pressure does not exceed a first predetermined value, and means for converting said lost-motion coupling to a driving connection in response to a second pressure in excess of said first pressure to cause said operator to shift said valve means from closed to open position.

Abstract: Wireline apparatus and method for measuring pressure downhole in well tubing comprising a main plug body which seats in a seating nipple forming part of the tubing, a pressure gauge in communication with the tubing below the main plug body, and means for equalizing the tubing pressure above and below the seated main plug body so that the apparatus may be removed from the well.

Abstract: A valve system for use in inflating packers mounted on mandrels is disclosed. The valve system uses one or more valves to permit, through the use of seals, the flow of fluid from the interior of a tubular mandrel to the interior of the inflatable packer when pressure applied in the mandrel exceeds at least a minimum pressure. In two embodiments, inflation of the packer beyond a given pressure is prevented. In all embodiments, the differential pressure across reciprocating seals is minimized through exposure of one or both sides, directly or indirectly, to the external pressure of the mandrel and packer.