Abstract: An expansion and cementing assembly is run into the well as the expandable liner is made up. A work string is tagged into the expansion assembly and run to depth. Pressure drives the swage to initially expand and move uphole with the attached work string until the liner is expanded above the location of the subsequent cement placement. The assembly is then lowered to engage the guide/float shoe to perform the cementing step. The swage assembly is then released from the guide/float shoe and the balance of the expansion is performed without further expansion against the recently placed cement. The expansion assembly can start at the guide/float shoe or higher, in which case expansion can occur initially in a downhole direction and later be completed in an uphole direction. Variations without cementing are also contemplated.

Abstract: An expansion assembly is run into the well as the expandable liner is made up. A work string is tagged into the expansion assembly and run to depth. Pressure drives the swage to initially expand and move uphole with the attached work string until the liner is expanded to set at least one external packer. The balance of the expansion in the uphole direction is continued until the string is expanded into sealing support of a higher string in the wellbore and the variable swage comes out of the hole with the work string. A shoe is milled out and the process can be repeated.

Abstract: An expansion and cementing assembly is run into the well as the expandable liner is made up. A work string is tagged into the expansion assembly and run to depth. Pressure drives the swage to initially expand and move uphole with the attached work string until the liner is expanded above the location of the subsequent cement placement. The assembly is then lowered to engage the guide/float shoe to perform the cementing step. The swage assembly is then released from the guide/float shoe and the balance of the expansion is performed without further expansion against the recently placed cement. The expansion assembly can start at the guide/float shoe or higher, in which case expansion can occur initially in a downhole direction and later be completed in an uphole direction. Variations without cementing are also contemplated.

Abstract: A well having a minimum drift between or among strings is provided using strings that have a recessed segment and a hanging segment. The length of the recessed segment in the lower end of the upper string is substantially longer than the hanging segment of the lower string that is passed through it. The hanging segments define the drift dimension. In the event the lower string gets stuck in the open hole before it is fully advanced, the hanging segment of the lower string may still be in the recess of the upper string so that the drift dimension can be preserved. Preferably the recess segment is the substantial length of the tubular string apart from its hanging segment near its top end. One or more laterals can be extended through the recessed segments while retaining the drift dimension.

Abstract: An expansion assembly is run into the well as the expandable liner is made up. A work string is tagged into the expansion assembly and run to depth. Pressure drives the swage to initially expand and move uphole with the attached work string until the liner is expanded to set at least one external packer. The balance of the expansion in the uphole direction is continued until the string is expanded into sealing support of a higher string in the wellbore and the variable swage comes out of the hole with the work string. A shoe is milled out and the process can be repeated.

Abstract: A compliant, integrated, fastening and sealing system located on either end of cladding or on a liner hanger. It features protrusions in opposed directions whose contact edges are preferably hardened. The protrusions penetrate the surrounding tubular on expansion of the smaller tubular. Seals are included adjacent the protrusions so that seals between adjacent protrusions get forced toward each other upon flexing of the projections that penetrate the surrounding tubular. The attachment configuration is particularly suited for use with fixed swages or variable swages with limited dimensional adjustability when precise ID of host casing or open hole is unknown.

Abstract: In one variation, a tool is disclosed that can run cladding into casing where the cladding interior is closed off by opposed cup seals and access to the volume between the cup seals exists through the tool body. “Cladding” comprises sleeves, scrolls, casing, tubing and liner strings. Pressure is applied to the interior of the cladding to expand it into gripping and sealed contact with the casing. An exterior gripping surface can be provided on the cladding to enhance grip upon expansion. The tool can be repositioned to expand lengths of cladding including tubing or casing.

Abstract: A separation barrier for placement in an open well bore or casing, to prevent migration of cement slurry downwardly into the drilling fluid, facilitating the placement of a cement plug to segregate a well bore into uphole and downhole portions. The barrier has an annular seal which facilitates pumping the barrier downhole through a work string to a desired location. The separation barrier also has a plurality of flexible elongated elements which expand outwardly when the barrier exits the work string. The elongated elements are closely spaced to prevent migration or contamination of cement slurry therebetween. The barrier can also have a shearable landing ring for providing positive indication of placement of the barrier at the desired location.

Abstract: In one variation, a tool is disclosed that can run cladding into casing where the cladding interior is closed off by opposed cup seals and access to the volume between the cup seals exists through the tool body. “Cladding” comprises sleeves, scrolls, casing, tubing and liner strings. Pressure is applied to the interior of the cladding to expand it into gripping and sealed contact with the casing. An exterior gripping surface can be provided on the cladding to enhance grip upon expansion. The tool can be repositioned to expand lengths of cladding including tubing or casing.

Abstract: A separation barrier for placement in an open well bore or casing, to prevent migration of cement slurry downwardly into the drilling fluid, facilitating the placement of a cement plug to segregate a well bore into uphole and downhole portions. The barrier has an annular seal which facilitates pumping the barrier downhole through a work string to a desired location. The separation barrier also has a plurality of flexible elongated elements which expand outwardly when the barrier exits the work string. The elongated elements are closely spaced to prevent migration or contamination of cement slurry therebetween. The barrier can also have a shearable landing ring for providing positive indication of placement of the barrier at the desired location.

Abstract: A composite packer or bridge plug includes substantially all nonmetallic components. The design allows the setting tool metallic components to be retrieved after the bridge plug is set. The slips contain flats with mating flats on the cones which extend to one end of the cones and guides for the slips to facilitate proper slip movement into engagement with the wellbore. A lock ring rides on the nonmetallic mandrel and secures the set, using a buttress-type thread to engage into the mandrel body. Alternative designs are revealed for backup to the sealing elements to prevent extrusion. In one design, split rings are axially compressed so that they grow in radial dimension to act as extrusion barriers. In another design, tapered scored rings are rotationally locked against each other and are axially compressed so that they bend into contact with the wellbore to act as extrusion barriers. Axial travel to obtain an extrusion barrier is minimized.

Abstract: A method and apparatus is disclosed for downhole remediation. In the preferred embodiment, a bridge plug and service packer can be run into a well on coiled or rigid tubing. The assembly is capable of being set without rotation. The service packer is locked against setting until it is separated from the bridge plug. Setting of the bridge plug closes a passage within it that had been open to facilitate circulation during run-in. The service packer is set with longitudinal movements using an indexing mechanism. At the conclusion of the procedure, the service packer is released and lowered to recapture the bridge plug. The bridge plug is equalized and released to allow the assembly to be repositioned elsewhere in the wellbore or retrieved. The spacing between the packer and bridge plug can be varied as desired.

Abstract: An above packer perforate, test and sample tool. The tool includes a tester valve which is positioned above a well packer and which has a bypass which provides communication between a well annulus above the packer and a firing mechanism for guns positioned below the packer. When the well annulus pressure is raised, the firing mechanism is triggered. The bypass may be closed prior to firing of the guns, and after perforation, a valve in the tester valve may be opened to flow a sample of well fluid into a sampling chamber located above the tester valve. A method of testing a well formation utilizing the apparatus is also disclosed.

Abstract: A tool for activating the firing head of a perforating gun located below a packer by applying pressure to the upper well annulus while maintaining an unimpeded bore between the perforating gun and the pipe string. The tool is provided with a flow valve to prevent flow through the flow bore when closed, and a circulation valve which permits fluid flow from the upper annulus into the flow bore when open and a means of switching the valves so that when one is open the other is closed. A method of using the tool to complete a well is also disclosed.

Abstract: An annulus pressure responsive downhole tool includes a housing with an operating element disposed in the housing. The operating element is movable from a first element position to a second element position relative to the housing. A hydrostatic well annulus pressure referenced annulus pressure responsive first power piston is disposed in the housing and movable from a first to a second position thereof relative to the housing in response to an increase in well annulus pressure. A lower than hydrostatic well annulus pressure referenced annulus pressure responsive second power piston is disposed in the housing and is operatively associated with the operating element for permitting the operating element to move from its first element position to its second element position in response to movement of the second power piston from a first position to a second position thereof relative to the housing.

Abstract: A recloseable auxiliary valve includes a cylindrical housing having a central flow passage disposed therethrough. A flapper valve is disposed in the housing and is movable between a closed position wherein the central flow passage is closed and an open position wherein the central flow passage is open. An operating mandrel is provided for operating the flapper valve upon telescoping movement of the mandrel relative to the housing. A releasable locking system is provided for locking the mandrel and the flapper valve in their open position. A time-delay system is provided to prevent premature telescopingly collapsing movement of the mandrel relative to the housing as the auxiliary valve is run into the well.

Abstract: A recloseable circulation valve includes a cylindrical housing having a central flow passage disposed therethrough and having a power port and a circulation port disposed through a wall thereof. An operating mandrel is telescopingly received in the upper end of the housing. A valve sleeve is slidably received in the housing and movable to open and close the circulation port. A power mandrel is disposed in the housing and is connected to the valve sleeve for moving the valve sleeve from an initial position toward an open position. A mandrel lock is provided for locking the operating mandrel and power mandrel together after the power mandrel moves the valve sleeve from its initial position. The power mandrel and valve sleeve are initially held in their initial positions by a shear pin assembly.

Abstract: A spherical valve member type having a drill pipe tester valve and a moving apparatus to provide for moving the spherical valve member axially relative to the housing between its said open and closed positions, thereby permitting downward forces exerted upon the spherical valve member in its said closed position due to fluid pressure in the well test string above the spherical valve member, to be transmitted substantially entirely to the housing through the engagement of the downward facing surface of the lower valve seat structure and the upward facing surface of the housing. A latch device is provided for latching the spherical valve member in its closed position as the well test string is lowered into the well and for subsequently releasing the spherical valve member and allowing it to move to its open position when the well test string is finally positioned within the well.

Abstract: A drill pipe tester valve includes a spherical valve member supported from an upward facing surface of a housing so that downward forces exerted on the valve member in its closed position, due to fluid pressure in a string of pipe above the valve member, are transmitted substantially entirely to said housing. A latching device is provided for latching the spherical valve member in its closed position as the string of pipe and tester valve are lowered into a well and for subsequently releasing the spherical valve member and allowing it to move to its open position when the string of pipe and tester valve are finally positioned within the well. Additionally, a spring is utilized to control the closing of the equalization port in the drill pipe tester valve in order to provide a positive indication of the closing of the equilization port and to eliminate the use of a J-slot positioning means and cooperating lug.

Abstract: A drill pipe tester valve includes a spherical valve member supported from an upward facing surface of a housing so that downward forces exerted on the valve member in its closed position, due to fluid pressure in a string of pipe above the valve member, are transmitted substantially entirely to said housing.