Geothermal liner system with packer

A geothermal liner system with packer for sealing a producing zone within a wellbore has a mandrel placed in an interior of the wellbore, a packer releasably affixed around an outer surface of the mandrel, and a sleeve positioned adjacent an end of the mandrel. The liner system is generally tubular and may include joint casings and a mandrel, all being tubular-shaped. The packer is expandable upon exposure to wellbore conditions. The sleeve has perforations in a wall thereof. The mandrel is slidable relative to the packer when the packer expands against the wellbore. The sleeve is selectively controlled to manage production from sealed wellbore zones. The system is stabilized through various wellbore conditions, such as geothermal heat, by being adjustable for thermal expansion of parts of the system.

CROSS-REFERENCE TO RELATED APPLICATIONS

Not applicable.

Not applicable.

NAMES OF THE PARTIES TO A JOINT RESEARCH AGREEMENT

Not applicable.

Not applicable.

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present invention relates to the production of fluids within a wellbore. More particularly, the present invention relates to the isolation of producing zones within a wellbore using a liner system of a liner with packers. More particularly, the present invention relates to sealing a mandrel of the liner within a wellbore using packers that prevent fluids from flowing between producing zones. Additionally, the present invention relates to packers that allow mandrels of the liner to slide longitudinally therein, so as to account for exposure to wellbore conditions.

It is well known that land formations that produce oil and gas have different “zones” where different mixtures of oil and gas are produced, where other fluids—such as water—are produced, and where no fluids are produced at all. An oil and gas wellbore can pass through any number and combination of these zones so as to maximize the production of oil and gas from the land formation.

Open-hole completions are commonly used for producing oil and gas in a wellbore. Open-hole completions are particularly useful in slant-hole wells. In these wells, the wellbore may be deviated and run horizontally for thousands of feet through a producing zone. It is often desirable to provide annular isolators, or packers, along the length of the horizontal production tubing to allow selective production from, or isolation of, various portions of the producing zone.

In open-hole wells, standard casing is cemented only into upper portions of the well, and not through the producing zones. A liner then runs from the bottom of the cased portion of the well down through the various zones in the wellbore. In a typical production of oil and gas in a wellbore, production tubulars or casings are inserted in the wellbore. In open-hole completions, nothing supports the wellbore from collapse upon itself. Thus, the liner is used to fill the interior of the wellbore and to support the walls of the wellbore. Liners are typically run into uncased portions of wellbores. It is desirable for liners to minimize the annular space between the liner and the wellbore wall so as to provide mechanical support and restrict or prevent annular flow of fluids outside the production tubing of the liner. However, due to irregularities in the wellbore wall, liners do not prevent annular flow in the wellbore. For this reason, a liner system includes packers that are used to stop annular flow of fluids around the liner. Packers provide annular seals, or barriers, between the liner and the wellbore wall to isolate various zones within the wellbore and along the liner. A mandrel and a packer are components that can be installed in the liner, along with the regular tubular joint casings as part of a liner system.

A problem associated with oil and/or gas production within a wellbore is that when a wellbore passes through certain zones, such as a water zone, water can enter the annular space between the liner and the wellbore wall and mix with oil and/or gas. Thus, there is a need to isolate water zones (or other non-desirable zones) from oil and/or gas zones.

Another problem associated with oil and/or gas production within a wellbore is that various production zones can have different natural pressures. Zones of different pressures must be isolated from each other so as to prevent flow in the wrong direction and to allow production from the low pressure zones. Thus, where multiple zones are penetrated by the same wellbore, there is a need to isolate the zones to allow separate control of fluid flow in each zone for more efficient oil and/or gas production.

A problem associated with typical liner systems is the inability to move the liner relative to the packers once the packers have expanded within the wellbore. Thus, there is a need for a liner system with a liner and packers that allows for the longitudinal movement of the liner relative to the expanded packers within the wellbore.

Various patents have been issued relating to liner systems. For example, U.S. Pat. No. 7,404,437, issued on Jul. 29, 2008 to Brezinski et al., discloses an apparatus and method for forming an annular isolator in a borehole after the installation of production tubing Annular seals are carried in or on production tubing as it is run into a borehole. In conjunction with expansion of the tubing, the seals are deployed to form annular isolators. An inflatable element carried on the tubing can be inflated with a fluid carried in the tubing and forced into the inflatable element during expansion of the tubing. Reactive chemicals can be carried in the tubing and injected into the annulus to react with each other and also with ambient fluids so as to increase in volume and harden into an annular seal. An elastomeric sleeve, ring, or band carried on the tubing may be expanded into contact with a borehole wall and may have its radial dimension increased in conjunction with tubing expansion to form an annular isolator.

U.S. Pat. No. 7,373,973, issued on May 20, 2008 to Smith et al., discloses a bridge plug having a segmented backup shoe, and a split-cone extrusion limiter. The extrusion limiter has a two-part conical retainer positioned between packer elements and the segmented backup shoe. The extrusion limiter blocks packer element extrusion though spaces between backup shoe segments. In one embodiment, two split-cone extrusion limiters are used together and positioned so that each split cone extrusion limiter covers gaps in the other extrusion limiter. The two split-cone extrusion limiters block packer element extrusion though gaps between backup shoe segments regardless of their orientation relative to the segmented backup shoe. In another embodiment, a solid retaining ring is positioned between a split retaining cone extrusion limiter and a packer element. The solid retaining ring resists extrusion of packer elements into spaces in the split-cone extrusion limiter or limiters.

U.S. Pat. No. 7,392,851, issued on Jul. 15, 2008 to Brennan, III et al., discloses an inflatable packer assembly that has a first expandable tubular element having a pair of ends, a first pair of annular end supports for securing the respective ends of the first tubular element about a mandrel disposed within the first tubular element, and a first annular bracing assembly deployable from one of the end supports for reinforcing the first tubular element upon pressurization and expansion thereof. An end of the first annular bracing assembly is pivotally connected to one of the end supports for reinforcing the first tubular element upon pressurization and expansion thereof. An opposite end of the first annular bracing assembly is expandable. One of the end supports is movable. The other end support is fixed with respect to the mandrel. The first annular bracing assembly has a slats arranged in an annular configuration and pivotally connected at one of to the movable end support. Each of the slats has a width that increases from its pivotally connected end to its other end.

U.S. Pat. No. 7,387,170, issued on Jun. 17, 2008 to Doane et al., discloses a packer device that includes a central packer mandrel and a radially-surrounding expansion mandrel. A slip mandrel carrying wickers surrounds the expansion mandrel and is secured in place upon the expansion mandrel by an annular retaining ring. The slip mandrel is secured to the retaining ring by screw connectors that pass through the slip mandrel and into retainer segments. The retaining ring is clamped between the slip mandrel and segments. The packer device carries a fluid seal that is made up of a thermoplastic material with elastomeric energizing elements.

U.S. Pat. No. 7,387,158, issued on Jun. 17, 2008 to Murray et al., discloses a packer that has a main sealing element that swells after a delay that is long enough to get the sealing element into a proper position. A sleeve is removed from the packer so as to allow well fluids to contact the main sealing element so as to start the swelling process. The main sealing element swells until the surrounding tubular or the surrounding wellbore is sealed. Sleeves that remain above and below the main sealing element preferably swell in a longitudinal direction so as to abut the main sealing element and increase the contact pressure of the main sealing element against the surrounding tubular or wellbore. The longitudinally-swelling members can be covered to initiate their growth after the main sealing element has started or completed a swelling action. The longitudinally-swelling members can be constrained against radial growth to direct swelling action in a longitudinal direction. Extrusion barriers above and below the main sealing element can optionally be used.

U.S. Pat. No. 7,314,092, issued on Jan. 1, 2008 to Telfer, discloses a packer tool for mounting on a work string that has a body with packer elements thereon, and a sleeve positioned around the packer elements so as to compress the packer elements. The packer tool is set by movement of the tool body relative to the sleeve. The sleeve includes a retaining member. The retaining member is removable between a first and a second position. In the first position, the retaining member prevents movement of the sleeve relative to the tool body so as to prevent setting of the packer tool. In the second position, the retaining member releases the tool body so as to arrest a movement of the sleeve. In the second position, the retaining member also facilitates compression of the packer elements so that the tool can be set.

U.S. Pat. No. 7,143,832, issued on Dec. 5, 2006 to Fyer, discloses an annular packer arranged on the outside of the production tubing. The packer has a core that has an elastic polymer that swells by the addition of hydrocarbons. The core can be surrounded by an external mantel of rubber. The external mantel of rubber is permeable to hydrocarbons and may be equipped with a reinforcement. The core swells by absorption of hydrocarbons and the packer expands accordingly. The expansion of the packer seals the annular space between the production tubing and the well wall.

U.S. Pat. No. 6,848,505, issued on Feb. 1, 2005 to Richard et al., discloses a method of sealing casing or liners in a wellbore. Strands of casing or liners receive a jacket bonded to the outer surface. Preferably, the jacket is a rubber compound bonded to the outer wall. The rubber compound swells at a predetermined rate in response to contact with fluids in the well. The casing or liner can be expanded with a swage preferably prior to the onset of the swelling of the jacket. Packers and sealing hangers can be added at the extremes of the casing or liner string to further secure against channeling between adjacent formations.

U.S. Pat. No. 7,228,917, issued on Jun. 12, 2007 to Thomson, discloses an apparatus and method for creating a seal in a bore hole annulus. A conduit within a wellbore has an outer surface covered with an elastomeric material that can expand and/or swell when the material comes into contact with an actuating agent. The conduit is an expandable conduit. The conduit is located inside a second conduit and radially expanded therein. The actuating agent can be naturally occurring in the bore hole or can be injected or pumped into the bore hole so as to expand or to swell the elastomeric material to create the seal.

U.S. Pat. No. 7,121,352, issued on Oct. 17, 2006 to Cook et al., discloses an apparatus that has a zone-isolation assembly. The assembly has a solid tubular member. The solid tubular member has external seals. A perforated tubular member is coupled to the solid tubular member. A shoe is coupled to the zone-isolation assembly. The perforated tubular members include an elastic sealing member that is coupled to the perforated tubular member. The elastic sealing member covers the perforations of the perforated tubular member.

It is an object of the present invention to control the flow of fluids in a producing wellbore.

It is another object of the present invention to prevent the flow of water into a producing liner.

It is another object of the present invention to produce oil and gas from zones having different pressures.

It is still another object of the present invention to provide a liner system, having a mandrel-packer assembly that can be opened and closed within the wellbore so as to allow or prevent a flow of fluid into the producing liner.

It is another object of the present invention to provide a liner system, having a mandrel-packer assembly, wherein the mandrel longitudinally extends within the interior of packers after the packers have been locked in position by expansion within the wellbore.

It is another object of the present invention to maximize oil and gas production for any number and combination of zones within a wellbore.

It is still another object of the present invention to provide a liner system, having a mandrel-packer assembly, wherein the mandrel that can be installed with packers affixed thereto and that can adjust longitudinally through the packers, after the packers are expanded in place against the wellbore.

It is another object of the present invention to provide a liner system that can be used in vertically and horizontally-extending wells.

It is another object of the present invention to provide a liner system for injection wells and producing wells.

It is another object of the present invention to isolate the various zones of a wellbore that have no casing or liner.

It is another object of the present invention to support the walls of a wellbore with expandable packers.

It is another object of the present invention to provide a liner system that is easily placed within a wellbore.

It is still another object of the present invention to provide a liner system that withstands wellbore conditions associated with oil and gas production, including but not limited to environmental conditions related to geothermal temperatures and pressure.

It is another object of the present invention to provide a liner system where the packer is releasably affixed to the outer surface of the mandrel.

BRIEF SUMMARY OF THE INVENTION

The present invention is a geothermal liner system with packer that seals a producing zone within a wellbore, comprising a plurality of joint casings, a mandrel placed in an interior of the wellbore in sequence with the joint casings, a packer releasably affixed around an outer surface of the mandrel, and a sleeve positioned adjacent an end of the mandrel. The liner is generally tubular because the joint casings and mandrels are tubular-shaped. The mandrel is a component within the liner. The packer is of a material that is expandable upon contact with fluids in the wellbore, and there can be more than one packer in the liner system. The mandrel is longitudinally slidable within an interior of the packer. The sleeve has a plurality of perforations in a wall thereof and is independently activated to open or close the perforations with respect to the wellbore. The sleeve is placed in the open position so as to allow production of fluid from the corresponding wellbore zone. The sleeve can be placed in the closed position so as to prevent fluid flow into the liner, such as during installation and positioning of the mandrel in the wellbore.

The packer comprises a packing structure having a channel formed therein, a packer element received in the channel of the packing structure, and a fusible link connected to the packing structure. The packing structure is slidable relative to the outer surface of the mandrel, after the packer element has expanded in an annular space between the packing structure and the wellbore upon contact with the fluids in the wellbore. The fusible link is releasably affixed to the outer surface of the mandrel. During installation and while traveling through the wellbore, the fusible link fixes the packer to the mandrel. After reaching the planned destination, the fusible link releases, allowing the longitudinal sliding relation between the packer and mandrel.

The packing structure comprises a tubular element slidably positioned on the outer surface of the mandrel, a first end portion affixed to an end of the tubular element, and a second end portion affixed to an opposite end of the tubular element. The first end portion and the second end portion and the tubular element form the channel.

The fusible link comprises a first connection affixed to the first end portion of the packing structure, and a second connection affixed to the second end portion of the packing structure. The first connection is releasably affixed to the outer surface of the mandrel. The second connection is releasably affixed to the outer surface of the mandrel. The first and second connections are suitable for dissolving upon contact with the fluids in the wellbore. The mandrel can be a chromed mandrel and can be expanded longitudinally through the wellbore upon exposure to wellbore conditions. The sleeve has an inner diameter smaller than an outer diameter of the mandrel. The plurality of perforations are in fluid communication with an interior of the liner through the mandrel, sleeve or the joint casings.

The present invention is an apparatus for sealing a producing zone within a wellbore comprising a first packing assembly having a mandrel and a packer, a sleeve having an end positioned adjacent an end of the mandrel of the first packing assembly, and a second packing assembly having a mandrel and a packer. The mandrel of the second packing assembly has an end positioned adjacent an opposite end of the sleeve. The packer of the first packing assembly is releasably affixed to the mandrel of the first packing assembly. The packer of the second packing assembly is releasably affixed to the mandrel of the second packing assembly. The sleeve has a plurality of perforations in a wall thereof. The mandrels of the first and second packing assemblies are slidable relative to the packers, after the packers have expanded. The sleeves are separately controlled to expose the perforations to the isolated wellbore selectively. The perforations are selectively opened and closed without regard to the expansion and sliding relation between the mandrels and packers. The plurality of perforations of the sleeve can be in fluid communication with the liner through an interior of the mandrel at the first packing assembly and an interior of the mandrel at the second packing assembly.

The packers of the first and second packing assemblies each have a packing structure having a channel therein, a packer element received in the channel of the packing structure, and a fusible link connected to the packing structure. The packing structure is slidable relative to an outer surface of the mandrel. The packer element is expandable in an annular space between the packing structure and the wellbore upon contact with fluids in the wellbore. The fusible link is releasably affixed to the outer surface of the mandrel. The fusible link fixes the packing structure in place until the wellbore conditions release the fusible link. The packing structure comprises a tubular element slidably positioned on the outer surface of the mandrel, a first end portion affixed to an end of the tubular element, and a second end portion affixed to an opposite end of the tubular element. The first end portion and the second end portion and the tubular element form the channel. The fusible link has a first connection affixed to the first end portion of the packing structure, and a second connection affixed to the second end portion of the packing structure. The first connection is releasably affixed to the outer surface of the mandrel. The second connection is releasably affixed to the outer surface of the mandrel. As such, the first and second connections are suitable for dissolving upon contact with the fluids in the wellbore.

DETAILED DESCRIPTION OF THE INVENTION

Referring toFIG. 1, there is shown a cross-sectional view of a land formation16, with the preferred embodiment of the apparatus10of the present invention inserted within a wellbore50that has been formed in the land formation16. The land formation16has a water-producing layer20, a non-producing layer21below the water-producing layer20, an oil-and-gas layer22below the non-producing layer21, another water layer23below the oil-and-gas layer22, and another oil-and-gas layer24below the water layer23. The wellbore50extends vertically and diagonally through the water-producing layer20. The wellbore50extends diagonally through the non-producing layer21, the oil-and-gas layer22, the other water layer23, and a portion of the oil-and-gas layer24. The wellbore50extends horizontally through oil-and-gas layer24. The various layers20,21,22,23and24are also referred to as zones. These zones can reside at a great depth below the surface12of the land formation16. Near the surface12of the land formation16, the wellbore50has casing14on the walls18thereof. The casing14adds structural integrity to the wellbore50. The casing14is not used within the wellbore50when the wellbore50turns diagonally or horizontally through the land formation16. Because the wellbore50cuts through the water-producing zones20and23and the oil-and-gas producing zones22and24, water and oil and gas will seep into the wellbore50. These fluids will mix and be urged upward towards the surface12of the land formation16unless an obstruction keeps them from moving upwardly in the wellbore50.

The apparatus10of the present invention seals the producing zones20,22,23, and24from one another within the wellbore50, and only allows the oil-and-gas producing zones22and24to produce fluid that moves upwardly through the liner by joint casings or mandrels11toward the surface12of the land formation16within the wellbore50. The apparatus10has a mandrel11placed in an interior52of the wellbore50. The liner has a generally tubular shape because the joint casings and mandrels11have a tubular shape. The joint casings are tubular elements that extend the length of the liner through the wellbore. A packer17is releasably affixed around an outer surface15of the mandrel11. The packer17is of a material that is expandable upon contact with fluids in the wellbore50. There can be more than one packer17in a system of the present invention10. The mandrel11is slidable within the interior19of the packer17, when the packer17is expanded and released. A sleeve44is positioned adjacent an end9of the mandrel11and has perforations46in a wall47thereof.

InFIG. 1, packers17are placed so that any water produced from zone20cannot move upwardly or downwardly within the wellbore50. The annular space56between the outer surface15of the mandrel11and the wall18of the wellbore50may fill with water in the region between packers17; however, the water will remain within this space and not be produced. Any water that is produced in zone23is also blocked from flowing within the wellbore50by packers17. Although the mandrel11passes by the water-producing zones20and23, there are no sleeves with perforations that allow the water to flow into the interior19of the mandrel11so as to be produced. In the oil-and-gas zones22and24, sleeves44are incorporated with the mandrel11so as to allow oil and gas to enter the perforations46of the sleeve44and thus enter the liner for production at the surface12. The ends9of the mandrel11and the wellbore50ofFIG. 1are spaced apart so as to allow fluids of oil and gas to enter the perforations46of the sleeves44and into the liner.

As will be explained in more detail below, the sleeves44can be placed in an open position, for example inFIG. 1, so that fluid can flow through the sleeves44and into the liner, including the mandrels11. The mandrels11are longitudinally slidable within the wellbore50, relative to the fixed packers, after the packers17swell within the wellbore50, so as to account for thermal expansion of the mandrel11due to wellbore conditions, such as geothermal heat. Prior to the apparatus10of the present invention, this was not possible. The wellbore conditions would expand and rupture the sealed packer installations because the packers17remained fixed on the liner. In the apparatus10, the fusible links of the packer17that affixed the packer17to the outer surface15of the mandrel11are released from the outer surface15after the packers17swelled within the wellbore50. Thus, the mandrels11are now longitudinally slidable within the interior19of the packers17relative to the packers17, allowing for stability of the entire liner system through various environmental stress in the wellbore.

Referring toFIG. 2, there is shown a cross-sectional view of the land formation16, with the liner, including joint casings and mandrels11moved relative to the packers17within the wellbore50. The sleeve44in zone24that produces oil and gas is shown in the open position so as to allow oil and gas fluids to flow through the perforations46in the sleeves44and into the interior13of the liner. The sleeves44are separately controlled with regard to the thermal expansion of the liner, including the joint casings and mandrels11. The sleeves44are selectively opened, and the liner system of the present invention maintains the sealed zones, accounting for various wellbore conditions, by movable mandrels11. The sleeves44are tubular in shape so as to fit over and into the ends9of the mandrels11. InFIG. 2, the ends9of the mandrels11in zone22are longitudinally expanded because of geothermal heat in the wellbore. The sleeve44maintains control of the fluid access to the wellbore in any expanded or non-expanded status of the mandrels. Production of oil and maintenance of the fluid connection are not determined by particular mandrel movement because collection may need to occur in a particular zone without regard to any expansive movement of any particular mandrel11. The present invention presents a simple and effective solution to maintain the sealed zones without ruptures from various wellbore conditions, such as geothermal powered expansion, and fluid access controlled by sleeves. The present invention is a more stable system to install a liner with the packers in the proper locations and to maintain the sealed zones for fluid collection.

The movement of the mandrels11relative to the packers17is made possible by the fusible links38releasably attached to each packer. In prior art, each packer17would be fixed to the outer surface15of the mandrels11. In the present invention, the packers17are affixed to the outer surface15of the mandrels11when the packers17and mandrels11are inserted within the wellbore50. After the packers17expand within the wellbore50so as to fix the apparatus10within the wellbore50, the fusible links38release from the outer surface15of the mandrels11so as to allow the mandrels11to longitudinally expand and slide within the interior19of the packers17. The packers17thus stay in place within the mandrels11and support both the wall18of the wellbore50and the outer surface15of the mandrels11within the wellbore50while the mandrels11adjust to wellbore conditions within the interior19of the packers17.

Referring toFIG. 3, there is shown an isolated cross-sectional view of a packer17and mandrel11inserted within the wellbore50. The apparatus10is shown as residing within the wellbore50before the packer17has expanded within the wellbore50. The mandrel11is a chromed mandrel. The chromed mandrel is resistant to certain contaminants and corrosives that are contained in the fluids that are produced within the wellbore50. The packer17is releasably affixed to the outer surface15of the mandrel11.

The packer17has a packing structure25. The packing structure has a channel27formed therein. The packer17has a packer element36that is received within the channel27of the packing structure25. The packer element36is expandable in the annular space56between the packer structure25and the wellbore50upon contact with the fluids in the wellbore50. The packer17also has a fusible link38that is connected to the packer structure25. The fusible link38is releasably affixed to the outer surface15of the mandrel11. The packing structure25can be slidable relative to the outer surface15of the mandrel11, after the fusible links release. Specifically, the packing structure25has a tubular element26that is slidably positioned on the outer surface15of the mandrel11. A first end portion32is affixed to an end28of the tubular element26. A second end portion34is affixed to an opposite end30of the tubular element26. The first end portion32and the second end portion34and the tubular element26form the channel27of the packing structure25. The tubular element26extends radially outwardly from the outer surface15of the mandrel11for a distance less than a distance which the first and second end portions32and34extend radially outwardly from the outer surface15of the mandrel11. A packing31is placed on a bottom of each of the first and second end portions32and34so that the first and second end portions32and34slide easily along the outer surface15of the mandrels11. The fusible link38of the packer17has a first connection40affixed to the first end portion32of the packing structure25and a second connection42affixed to the second end portion34of the packing structure25. The first connection40is releasably affixed to the outer surface15of the mandrel11. The second connection42is releasably affixed to the outer surface15of the mandrel11. The first and second connections40and42are suitable for dissolving upon exposure to wellbore conditions. Particular wellbore conditions, such as temperature and pressure, can be pre-determined for a liner system to be placed in the wellbore50. The mandrel11is also expandable upon exposure to wellbore conditions. Once fluids from the land formation fill within the annular space56of the wellbore50, the packer element36expands radially outwardly from the outer surface15of the mandrel11so as to abut the wall18of the wellbore50. As needed, the mandrel11can expand in response to heat, mechanical forces, or chemical reactions. While the packer element36is expanding, the first and second connections40and42of the fusible links38dissolve or release when exposed to the wellbore conditions at the determined place within the wellbore50. Once the fusible links38are dissolved, the first and second end portions32and34and the tubular element26of the packing structure25can slide longitudinally relative to the outer surface15of the mandrel11. The ends of the first and second end portions32and34taper toward the outer surface15of the mandrel11. The packing structure25can be made of any material suitable for oil and gas operations within the wellbore50. The packer element36is preferably made of a material suitable for expanding within a wellbore50producing oil and gas, such as a polymer or elastomer. The packing31can be made of a slidable friction-reducing material such as polytetrafluoroethylene. The mandrels11are typical of production tubing used in oil and gas wells. The mandrels11can be chromed, as stated above.

Referring toFIG. 4, there is shown an isolated cross-sectional view of apparatus100of the present invention with a first packing assembly102and a second packing assembly130. The first packing assembly102has a mandrel104and a packer110. The packer110of the first packing assembly102is releasably affixed to the mandrel104. The second packing assembly130has a mandrel132and packer138. The packer138of the second packing assembly130is releasably affixed to the mandrel132of the second packing assembly130. The apparatus100also has a sleeve158that has an end160positioned adjacent an end108of the mandrel104of the first packing assembly102. The sleeve158has perforations164formed in a wall166thereof. The mandrel132of the second packing assembly130has an end136positioned adjacent an opposite end162of the sleeve158. The mandrels104and132of the first and second packing assemblies102and130, respectively, are slidable relative to the packers110and138. As shown, the sleeve158is in a closed position during this installation time with the non-expanded and affixed packers, so the perforations164of the sleeve158are not in fluid communication with an interior of the liner through either an interior106of the mandrel104of the first packing assembly102or an interior134of the mandrel132of the second packing assembly130. The packer110of the first packing assembly102is similar to the packer17described inFIGS. 1-3. The packer110has a packing structure112, a packer element122, and a fusible link124. The packing structure112has a tubular element116, a first end portion118, and a second end portion120. The fusible link124of the first packing assembly102has a first connection126and a second connection128. The first and second connections126and128of the first packing assembly102dissolve or release upon exposure to the wellbore conditions within the wellbore50. The packer138of the second packing assembly130has packing structure140, a packer element150, and a fusible link152. The packing structure140has a tubular element144, a first end portion146and a second end portion148. The fusible link152has a first connection154and a second connection156. The first and second connections154and156of the second packing assembly130dissolve or release upon exposure to wellbore conditions within the wellbore50.

The relation of the parts of the first packing assembly102and the second packing assembly130is substantially similar to the apparatus10shown inFIGS. 1-3. InFIG. 4, the end108of the mandrel104of the first packing assembly102and the end136of the mandrel132of the second packing assembly are being installed. In the typical installation of the apparatus100within a wellbore50, the ends108and136of the mandrels104and132and sleeve158are abutted while placing the apparatus100within the wellbore50. The sleeve158is now shown in a closed position, such that the perforations do not expose the wellbore to the interior of the liner through either mandrels104and132for production through the liner. The sleeve158has an inner diameter that is smaller than the outer diameter of the mandrels104and132. When the mandrels104and132move within the wellbore50, the packers110and138remain in position on the respective mandrels104and132within the wellbore50.

Referring toFIG. 5, there is shown an isolated cross-sectional view of the preferred embodiment of the apparatus100of the present invention, with the packers122and150swollen in response to exposure to wellbore conditions, such as fluids54within the wellbore50. As discussed above, the wellbore50is a hole created in the land formation16. If land formation16is saturated with oil and gas, oil and gas will seep through the wall18of the wellbore50into the annular space56between the packing assemblies102and130and the wall18of the wellbore50. The fluid154within the wellbore50caused the packer elements122and150to swell against the wall18of the wellbore50. Also, the fluid154caused the first and second connections of the fusible links124and152to dissolve so as to release the packing structures132and140from the outer surface107and135of the mandrel104and132. Because the mandrels104and132are slidable relative to the packers110and138, the ends108and136of the mandrels104and132maintain the sealed zone of the packer elements122and15. The sleeve is shown in an open position, exposing the perforations to the wellbore fluid. The perforations164of the sleeve158are separately controlled to be exposed to the interiors106and134of the mandrels104and132. After the packer elements150and122swell in response to the wellbore conditions within the wellbore50and the first connections126and154and second connections128and156dissolve this same exposure within the wellbore50, the mandrels104and132within the wellbore50can longitudinally slide relative to the packers110and138, respectively. The mandrels104and132can expand or contract in spaces159and161due to wellbore conditions, such as geothermal heat, while the packers110and138remain in the sealed state. This arrangement allows fluid within the wellbore50to pass through the perforations164of the sleeve158and through the interiors134and106of the mandrels132and104, respectively, for production through the interior of the liner.

Referring toFIG. 6, there is shown an isolated cross-section view of the apparatus100of the present invention, the first packing assembly102and the second packing assembly130in an expanded state. The mandrels104and132moved relative to the packers110and130within the wellbore50, such as when the land formation16no longer produces oil and gas. The sleeve158remains closed, regardless of the expansion and sliding of the mandrels104and132through time. The sleeve could also be re-opened for venting, regardless of the expansion or contraction of the mandrels over time. Thus, a stable system of a liner system with a packer is provided by the present invention. Wellbore conditions, like geothermal heat, no longer pose problems to the pumping activity or maintenance of the sealed zones.