Abstract: A packer assembly which incorporates a swellable elastomeric packer element and one or more swellable thermoplastic components. The swellable thermoplastic components are support rings that are located at each axial end of the elastomeric element and provide positive mechanical backups for the elastomeric element to limit extrusion of the packer element.

Abstract: Preformed ribs are held closely to the swelling element and then are allowed to assume an expanded position to capture the ends of the swelling element. Many variations are possible one of which is retaining the ribs in a run in position with a band that releases by interaction with well fluid. In another embodiment the ribs are of a shape memory material and go to the enlarged state after a time and exposure to well fluids. The swelling action of the element could urge the ribs to the expanded position. Alternatively, a retractable sleeve can be actuated after a delay using a piston and a sealed compartment where a material must dissolve or otherwise go away before the piston can stroke to remove a retainer from ribs that can then move out.

Abstract: Setting mechanisms for downhole tools are described that take advantage of hydrostatic pressure in the wellbore which is harnessed to set a tool after exposure to well fluids for a given time or temperature defeats a lock and allows hydrostatic forces to trigger the setting of the tool. Alternatively, some other biasing source is released to set the downhole tool after exposure to well fluids for a time or a temperature and time defeats a lock and allows the biasing source to set the tool. While applications to packers are preferred, other downhole tools can be set in his manner removing the need for an inner string, dropping a ball on a seat or pressurizing the wellbore to achieve the setting of the downhole tool.

Abstract: A packer assembly which incorporates a swellable elastomeric packer element and one or more swellable thermoplastic components. The swellable thermoplastic components are support rings that are located at each axial end of the elastomeric element and provide positive mechanical backups for the elastomeric element to limit extrusion of the packer element.

Abstract: A field assembled packer or plug features a sleeve of a swelling material, preferably rubber, which is slipped over the tubular. A pair of molds is assembled over the tubular. The molds can accommodate variation in the size and out of roundness of standard API tubulars. An epoxy mixture is formulated on site and pumped into the molds at opposed ends of the sealing element assembly and allowed to set up. The molds are removed and the assembly is ready to be run in the hole as a packer included in a tubular string. The element assembly can include a harder swelling material on opposed ends of the main sealing element to protect the main sealing element from damage during run in.

Abstract: A sealing element that swells on exposure to well fluids present or added to the wellbore is assembled to the mandrel in a manner to induce circumferential stresses proximately to the inside diameter of the element so as to resist the tendency of the inside diameter of the element to grow during the swelling process. A vacuum and a pressure method are described. Leak paths between the mandrel and the sealing element are minimized or eliminated as a result.

Abstract: A packer assembly features one or more elements that preferably swell when in contact with well fluids and have a feature in them that responds to an applied load in a given direction by retaining such a boost force with a locking mechanism. A single element can have two such mechanisms that respond to applied forces from opposed directions. Friction force for adhering the element to the mandrel is enhanced with surface treatments between them that still allow the locking mechanisms to operate.

Abstract: A field assembled packer or plug features a sleeve of a swelling material, preferably rubber, which is slipped over the tubular. A pair of molds is assembled over the tubular. The molds can accommodate variation in the size and out of roundness of standard API tubulars. An epoxy mixture is formulated on site and pumped into the molds at opposed ends of the sealing element assembly and allowed to set up. The molds are removed and the assembly is ready to be run in the hole as a packer included in a tubular string. The element assembly can include a harder swelling material on opposed ends of the main sealing element to protect the main sealing element from damage during run in.

Abstract: A sealing element that swells on exposure to well fluids present or added to the wellbore is assembled to the mandrel in a manner to induce circumferential stresses proximately to the inside diameter of the element so as to resist the tendency of the inside diameter of the element to grow during the swelling process. A vacuum and a pressure method are described. Leak paths between the mandrel and the sealing element are minimized or eliminated as a result.

Abstract: Setting mechanisms for downhole tools are described that take advantage of hydrostatic pressure in the wellbore which is harnessed to set a tool after exposure to well fluids for a given time or temperature defeats a lock and allows hydrostatic forces to trigger the setting of the tool. Alternatively, some other biasing source is released to set the downhole tool after exposure to well fluids for a time or a temperature and time defeats a lock and allows the biasing source to set the tool. While applications to packers are preferred, other downhole tools can be set in his manner removing the need for an inner string, dropping a ball on a seat or pressurizing the wellbore to achieve the setting of the downhole tool.

Abstract: A packer assembly features one or more elements that preferably swell when in contact with well fluids and have a feature in them that responds to an applied load in a given direction by retaining such a boost force with a locking mechanism. A single element can have two such mechanisms that respond to applied forces from opposed directions. Friction force for adhering the element to the mandrel is enhanced with surface treatments between them that still allow the locking mechanisms to operate.

Abstract: Preformed ribs are held closely to the swelling element and then are allowed to assume an expanded position to capture the ends of the swelling element. Many variations are possible one of which is retaining the ribs in a run in position with a band that releases by interaction with well fluid. In another embodiment the ribs are of a shape memory material and go to the enlarged state after a time and exposure to well fluids. The swelling action of the element could urge the ribs to the expanded position. Alternatively, a retractable sleeve can be actuated after a delay using a piston and a sealed compartment where a material must dissolve or otherwise go away before the piston can stroke to remove a retainer from ribs that can then move out.

Abstract: The present invention is directed to a reinflatable external casing packer which is operable in three modes, including: a filling mode of operation, a locking mode of operation, and a reinflation mode of operation. A valve system is provided which allows for selective filling and reinflation of the external casing packer in response to suspected or detected loss of pressure within the inflation chamber. The present invention may also be characterized as a method of placing a wellbore.

Abstract: An inflatable packer assembly for use in a subterranean well bore to isolate an interval of the well bore and/or adjacent subterranean formation for treatment. The assembly comprises a hanger assembly, a fluid piston assembly and at least one inflatable packer. As constructed and positioned in the well bore, the hanger assembly and fluid piston assembly are sufficiently distant from the interval to be treated to inhibit being stuck in the well bore. By lowering and raising the tubing or drill string from which the inflatable packer assembly is suspended, the fluid piston assembly pumps well bore fluid into and from the packer to respectively inflate and deflate the packer. In this manner, the packer can be repeatedly inflated, deflated and repositioned within a well bore to treat successive intervals of the well bore.

Abstract: A zone isolation apparatus is provided which allows for selective communication of fluid between a workstring and one or more subterranean zones. Fluid-pressure actuated packers may be placed in any desired location within a workstring without regard to the placement of the other packers, allowing maximum user flexibility and on-site configuration of the zone isolation apparatus. Each packer includes a rotary coupling to allow rotation of the workstring during running and sealing modes of operation. A latch mechanism is provided to prevent premature or accidental inflation.

Abstract: The present invention is directed to a reinflatable external casing packer which is operable in three modes, including a filling mode of operation, a locking mode of operation, and a reinflation mode of operation. A valve system is provided which allows for selective filling and reinflation of the external casing packer in response to suspected or detected loss of pressure within the inflation chamber. The present invention may also be characterized as a method of placing a wellbore.

Abstract: An inflatable packing tool is provided for use in a subterranean wellbore. The inflatable packing tool is coupled to a wellbore conduit with a central bore which directs pressurized fluid into the wellbore. The inflatable packing tool includes a central tubular body for directing fluid in the wellbore. Upper and lower stationary collar members are secured to the central tubular body for coupling the central tubular body to the wellbore conduit. An annular inflatable packing element surrounds the central tubular body, and includes a flexible fluid-tight sleeve covered by a plurality of overlapping an axially extending reinforcing ribs. A slidable sleeve assembly is coupled to one end of the annular inflatable packing element.

Abstract: Existing inflatable packers employ a three valve system for controlling the application of tubing pressure to the interior of an inflatable packing element surrounding the tubing. The three valves of such system are disposed in chordal relationship in the tubular wall of a valve collar which is secured to one end of the inflatable packing element. The valves employed are respectively an inflation initiating valve, a check valve and an inflate limit valve which are serially connected insofar as fluid flow is concerned. Because of the configuration of the flow passages, damage caused by fluid flow is much more severe on the check valve and inflate limit valve. Since no increase in diameter of the check and inflate limit valve can be tolerated, a duplicate set of such valves are provided in the tubular wall of the valve collar with the two sets of check valves and inflate limit valves connected in parallel to essentially double the effective flow area through such valves.

Abstract: An inflatable packer is mounted on the bottom end of a well casing by valve housing defining an annular chamber which is in communication at its lower end with the inflatable packer. A radial port is provided in the inner wall of the annular chamber for communicating with the bore of the casing and, during run-in, such radial port is closed by a sleeve valve shearably secured in the annular chamber. Application of pressured inflation fluid to the sleeve valve causes it to shift to a position permitting inflation fluid to flow through the annular chamber to the inflatable packer. Intermediate the first sleeve valve and the inflatable packer is a second sleeve valve which is shearably secured in a normally open position with respect to fluid flow through the annular chamber.

Abstract: A setting assembly tool suitable for suspension in a subterranean well by a wireline is provided for activating an inflatable packer. A downhole firing head with a combustion device is utilized for generating downhole a high fluid pressure in a passageway of the setting assembly tool, with the passageway being in fluid communication with the packer for setting the packer. In response to a pressure buildup of a predetermined level, fluid pressure is dumped from the passageway to the well while a check valve closes to retain the packer in the set position. To deactivate the retrievable packer, a conventional fishing tool supported by a wireless may be used to exert an axial force on a housing sufficient to move the housing relative to the packer and open a fluid port for discharging liquid from the packer. The setting assembly tool may be retrieved to the surface via the wireline immediately after the packer is set.