WO2020139459A2

WO2020139459A2 - Expanding sleeve for isolation

Info

Publication number: WO2020139459A2
Application number: PCT/US2019/059184
Authority: WO
Inventors: Jason Hoang Mai; Joseph Albert Henke; Johnny COVALT; Chenghua Han; Christopher Brian Sokolove
Original assignee: Hunting Titan, Inc.
Priority date: 2018-10-31
Filing date: 2019-10-31
Publication date: 2020-07-02
Also published as: WO2020139459A3

Abstract

A method and apparatus for plugging a wellbore casing with a sleeve either mechanically or explosively.

Description

Expanding Sleeve for Isolation

RELATED APPLICATIONS

[1] This application claims priority to U.S. Provisional Application No. 62/753,486, filed October 31, 2018 and U.S. Provisional Application No. 62/753,507 filed October 31, 2018.

BACKGROUND OF THE INVENTION

[2] Generally, when completing a subterranean well for the production of fluids, minerals, or gases from underground reservoirs, several types of tubulars are placed downhole as part of the drilling, exploration, and completions process. These tubulars can include casing, tubing, pipes, liners, and devices conveyed downhole by tubulars of various types. Each well is unique, so combinations of different tubulars may be lowered into a well for a multitude of purposes.

[3] A subsurface or subterranean well transits one or more formations. The formation is a body of rock or strata that contains one or more compositions. The formation is treated as a continuous body. Within the formation hydrocarbon deposits may exist. Typically a wellbore will be drilled from a surface location, placing a hole into a formation of interest. Completion equipment will be put into place, including casing, tubing, and other downhole equipment as needed. Perforating the casing and the formation with a perforating gun is a well known method in the art for accessing hydrocarbon deposits within a formation from a wellbore.

[4] Explosively perforating the formation using a shaped charge is a widely known method for completing an oil well. A shaped charge is a term of art for a device that when detonated generates a focused output, high energy output, and/or high velocity jet. This is achieved in part by the geometry of the explosive in conjunction with an adjacent liner. Generally, a shaped charge includes a metal case that contains an explosive material with a concave shape, which has a thin metal liner on the inner surface. Many materials are used for the liner; some of the more common metals include brass, copper, tungsten, and lead. When the explosive detonates, the liner metal is compressed into a super-heated, super pressurized jet that can penetrate metal, concrete, and rock. Perforating charges are typically used in groups. These groups of perforating charges are typically held together in an assembly called a perforating gun. Perforating guns come in many styles, such as strip guns, capsule guns, port plug guns, and expendable hollow carrier guns. [5] Perforating charges are typically detonated by detonating cord in proximity to a priming hole at the apex of each charge case. Typically, the detonating cord terminates proximate to the ends of the perforating gun. In this arrangement, an initiator at one end of the perforating gun can detonate all of the perforating charges in the gun and continue a ballistic transfer to the opposite end of the gun. In this fashion, numerous perforating guns can be connected end to end with a single initiator detonating all of them.

[6] The detonating cord is typically detonated by an initiator triggered by a firing head. The firing head can be actuated in many ways, including but not limited to electronically, hydraulically, and mechanically.

[7] Expendable hollow carrier perforating guns are typically manufactured from standard sizes of steel pipe with a box end having internal/female threads at each end. Pin ended adapters, or subs, having male/external threads are threaded one or both ends of the gun. These subs can connect perforating guns together, connect perforating guns to other tools such as setting tools and collar locators, and connect firing heads to perforating guns. Subs often house electronic, mechanical, or ballistic components used to activate or otherwise control perforating guns and other components.

[8] Perforating guns typically have a cylindrical gun body and a charge tube, or loading tube that holds the perforating charges. The gun body typically is composed of metal and is cylindrical in shape. Charge tubes can be formed as tubes, strips, or chains. The charge tubes will contain cutouts called charge holes to house the shaped charges.

[9] Electric initiators are commonly used in the oil and gas industry for initiating different energetic devices down hole. Most commonly, 50-ohm resistor initiators are used. Other initiators and electronic switch configurations are common.

[10] Modular or“plug and play” perforating gun systems have become increasingly popular in recent years due to the ease of assembly, efficiencies gained, and reduced human error. Most of the existing plug and play systems either (1) utilize a wired in switch and/or detonator, or (2) require an initiating“cartridge” that houses the detonator, switch, electrical contacts and possibly a pressure bulkhead. The wired in switch/detonator option is less desirable, because the gun assembler must make wire connections which is prone to human error. The initiating cartridge option is less desirable because the cartridge can be a large explosive device - in comparison to a standard detonator - thus takes up additional magazine space at the user facility. [11] There are many instances where one might desire to isolate a section of a well. One example is for a cement plug base during plug and abandonment of a well. Another instance is during plug and perf operations commonly employed for the completion of unconventional wells.

[12] During plug and perf operations, a stage is completed with a tool string containing perforating guns with a setting tool and isolation plug at the bottom or toe end. A power charge is ignited within the setting tool. The action of the setting tool causes the plug to seal off the well casing and then release off of the plug. The tool string is moved up hole to begin perforating while the isolation plug remains set on depth. The tool string is then pulled out of the well. The stage is then hydraulically fractured. Since the stage is isolated by the plug, tracking fluids and pressure are applied to the desired stage only. Subsequent stages are completed in the same manner. After all stages are completed, a coil tubing unit is brought to the well site to drill out all of the plugs. The coil tubing unit is expensive and takes a long time to remove all of the plugs. In some case, due to the limitation or the accessibility of a wellsite, large equipment such as coil tubing unit may not be available.

[13] Dissolvable (or degradable) plugs are options for having the plug materials dissolve over time in the well, thereby reducing the amount of time required for the coiled tubing unit. Some plug designs contain a through hole that allows fluid to pass through the plug until a ball is dropped and seated over the hole. These balls are commonly dissolvable. However, the remainder of the plug must still be drilled out as it restricts the inside of the casing, otherwise, hampering the full capacity of production, or inhibiting passage of future tools through.

SUMMARY OF EXAMPLE EMBODIMENTS

[14] An example embodiment may include a wellbore expandable tool having a cylindrical expandable sleeve with a plurality of radial slips located about its exterior and a radial sealing element, a mandrel having a rod portion and a head portion disposed within the expandable sleeve, a piston coupled to the mandrel rod, disposed within the cylindrical expandable sleeve, wherein the piston and cylinder form a pressure chamber, a power charge disposed within the piston, having a passageway between the power charge and the pressure chamber, a top sub slideably engaged with the piston, and wherein the expandable sleeve can be plastically deformed outwards against a wellbore casing with the radial slips engaging the wellbore casing and the sealing element creating a pressure seal against the wellbore casing.

[15] An alternative embodiment may include a firing head coupled to the top sub. The cylindrical sleeve may be expanded by pressure generated by the pyrotechnic burn of the power charge. The cylindrical sleeve may be expanded mechanically by pulling a mandrel through the hollow cylindrical sleeve. The sealing element may be an elastomer seal. The sealing element may be an adhesive. The sealing element may be an impact sensitive thermite. The sealing element may be a metal seal.

[16] An example embodiment may include a wellbore seal having a hollow cylindrical sleeve having an inner surface, outer surface, a first end, a second end, a plurality of radial slips, and at least one radial groove on the outer surface, a sealing element disposed within the at least one radial groove, a ball seat shoulder on the inner surface, wherein a ball can seat against the shoulder and create a pressure differential between the first end and second end, and wherein the cylindrical sleeve can be plastically deformed outwards against a wellbore casing with the radial slips engaging the wellbore casing and the sealing element creating a pressure seal against the wellbore casing.

[17] An alternative embodiment may include the cylindrical sleeve being expanded by explosive energy released within the hollow cylindrical sleeve. The cylindrical sleeve may be expanded mechanically by pulling a mandrel through the hollow cylindrical sleeve. The ball seat may be located proximate to the first end. The ball seat may be located proximate to the second end. The sealing element may be an elastomer seal. The sealing element may be an adhesive. The sealing element may be an impact sensitive thermite. The sealing element may be a metal seal. [18] A wellbore expandable tool having a cylindrical expandable sleeve with a plurality of radial slips located about its exterior and a radial sealing element having a hollow cylindrical sleeve having an inner surface, outer surface, a first end, a second end, a plurality of radial slips, and at least one radial groove on the outer surface, a sealing element disposed within the at least one radial groove, a ball seat shoulder on the inner surface, wherein a ball can seat against the shoulder and create a pressure differential between the first end and second end, a mandrel having a rod portion and a head portion disposed within the expandable sleeve, a detonator disposed within the expandable sleeve and having at least one explosive sheet located radially about the detonator, and wherein the detonation of the at least one explosive radial sheet causes the expandable sleeve can be plastically deformed outwards against a wellbore casing with the radial slips engaging the wellbore casing and the sealing element creating a pressure seal against the wellbore casing.

[19] An alternative example may include the at least one explosive sheet being a plurality of explosive sheets. The ball seat may be located proximate to the first end.

[20] An example embodiment may include a method for sealing a wellbore including lowering a metal wellbore sleeve coupled to a setting tool to a predetermined location in a wellbore casing, wherein the metal wellbore sleeve includes a plurality of radial slips for engaging with the wellbore casing, a radial sealing element for sealing against the wellbore casing, and a seat for a ball, expanding the wellbore sleeve against the wellbore, removing the setting tool from the wellbore, pumping a ball downhole and engaging it with the seat of the wellbore sleeve, and creating a pressure differential in the wellbore casing across the predetermined location.

[21] An alternative embodiment may include expanding the wellbore sleeve including plastically deforming the sleeve against the wellbore mechanically. The expanding of the wellbore sleeve may include plastically deforming the sleeve against the wellbore mechanically. It may include dissolving the ball engaged with wellbore sleeve. It may include milling out the wellbore sleeve. It may include dissolving the wellbore sleeve. The radial sealing element may be an elastomer seal. The radial sealing element may be an adhesive. The radial sealing element may be an impact sensitive thermite. The radial sealing element may be a metal seal. BRIEF DESCRIPTION OF THE DRAWINGS

[22] For a thorough understanding of the present invention, reference is made to the following detailed description of the preferred embodiments, taken in conjunction with the accompanying drawings in which reference numbers designate like or similar elements throughout the several figures of the drawing. Briefly:

FIG. 1 shows an example embodiment of a cross section of an expandable sleeve setting tool prior to setting.

FIG. 2 shows an example embodiment of a cross section of an expandable sleeve setting tool after setting.

FIG. 3 shows an example embodiment of a cross section of the expandable sleeve after setting.

FIG. 4 shows an example embodiment of a cross section of the expandable sleeve after setting.

FIG. 5 shows an example embodiment of a cross section of an expandable sleeve setting tool before setting the isolation sleeve.

FIG. 6 shows an example embodiment of a cross section of an expandable sleeve setting tool after setting the isolation sleeve.

FIG. 7 shows an example embodiment of a cross section of the expandable sleeve after setting.

DETAILED DESCRIPTION OF EXAMPLES OF THE INVENTION

[23] In the following description, certain terms have been used for brevity, clarity, and examples. No unnecessary limitations are to be implied therefrom and such terms are used for descriptive purposes only and are intended to be broadly construed. The different apparatus, systems and method steps described herein may be used alone or in combination with other apparatus, systems and method steps. It is to be expected that various equivalents, alternatives, and modifications are possible within the scope of the appended claims.

[24] Terms such as booster may include a small metal tube containing secondary high explosives that may be crimped onto the end of detonating cord. The explosive component is designed to provide reliable detonation transfer between perforating guns or other explosive devices, and often serves as an auxiliary explosive charge to ensure detonation.

[25] Detonating cord is a cord containing high-explosive material sheathed in a flexible outer case, which is used to connect the detonator to the main high explosive, such as a shaped charge. This provides an extremely rapid initiation sequence that can be used to fire several shaped charges simultaneously.

[26] A detonator or initiation device may include a device containing primary high-explosive material that is used to initiate an explosive sequence, including one or more shaped charges. Two common types may include electric detonators and percussion detonators. Detonators may be referred to as initiators. Electric detonators have a fuse material that burns when high voltage is applied to initiate the primary high explosive. Percussion detonators contain abrasive grit and primary high explosive in a sealed container that is activated by a firing pin. The impact of the firing pin is sufficient to initiate the ballistic sequence that is then transmitted to the detonating cord.

[27] FIG. 1 shows an example embodiment of a cross section of an expandable sleeve setting tool prior to setting. Mechanical sleeve setting tool assembly 100 is disposed in a wellbore casing 111. The tool assembly 100 has a GO igniter 108 housed within a firing head 106. A quick-change connector 110 is coupled to, and located uphole from, the firing head 106. A top sub 105 is coupled to, and located downhole from, the firing head 106. A power charge 109 is located within the piston 104, which is coupled to the top sub 105. The cylinder 103 includes an expansion chamber 114. When the GO igniter 108 ignites the power charge 109, gases are generated and exit the power charge 109 via passageway 112, into ports 113, which then vents the gas into the expansion chamber 114. The gases push piston 104 away from the plug, in this case expanding slip cylinder 101. Relief cut 115 allows the depressurization of chamber 114 when the mandrel 102 has reached its intended travel limit. Mandrel 102 is coupled to, and downhole from, the piston 104. The uphole movement of the piston 104 pulls the mandrel 102 uphole, through the expanding slip cylinder 101 and the sealing element 107. The mandrel 102, when pulled uphole, deforms the expanding slip cylinder 101 outwards against the casing 111, causing the slips 1 16 to dig into, and couple to the casing 111. Ball seat 118 will seat a ball pumped downhole after the mandrel 102 is removed. The sealing element 107 may be an elastomer seal, glue, other types of adhesives, impact sensitive thermite that ignites when expanded, or a soft metal seal such as copper, aluminum, lead, brass, or some appropriate alloy. In this example the mandrel 102 is pulled through the slip cylinder 101, however an alternative embodiment may include pushing the mandrel through the slip cylinder 101.

[28] FIG. 2 shows an example embodiment of a cross section of an expandable sleeve setting tool after setting. Mechanical sleeve setting tool assembly 100 is disposed in a wellbore casing 111. The tool assembly 100 has a GO igniter 108 housed within a firing head 106. A quick change connector 110 is coupled to, and located uphole from, the firing head 106. A top sub 105 is coupled to, and located downhole from, the firing head 106. A power charge 109 is located within the piston 104, which is coupled to the top sub 105. The cylinder 103 includes an expansion chamber 114. When the GO igniter 108 ignites the power charge 109, gases are generated and exit the power charge 109 via passageway 112, into ports 113, that then vent the gas into the expansion chamber 114. The gases push piston 104 uphole. Mandrel 102 is coupled to, and downhole from, the piston 104. The uphole movement of the piston 104 pulls the mandrel 102 uphole, through the expanding slip cylinder 101 and the sealing element 107. The mandrel 102 has been pulled uphole in this example, through the expanding slip cylinder 101, causing slips 116 to engage the casing 111 and sealing element 107 to seal against the casing 111.

[29] FIG. 3 shows an example embodiment of a cross section of the expandable sleeve after setting. The mandrel 102 has been pulled uphole through the expanding slip cylinder 101, causing slips 116 and sealing element 107 to seal against the casing 111.

[30] FIG. 4 shows an example embodiment of a cross section of the expandable sleeve after setting. The mandrel 102 has been pulled uphole through the expanding slip cylinder 101, causing slips 116 and sealing element 107 to seal against the casing 111. Furthermore, ball 117 has been pumped downhole and seats within the ball seat 118. Ball 117 may be later dissolved by chemicals or milled out when the wellborn seal is no longer necessary. Slip cylinder 101 in its entirety may be later dissolved by chemicals or milled out when the seal is no longer necessary.

[31] FIG. 5 shows an example embodiment of a cross section of an expandable sleeve setting tool before setting the isolation sleeve. Explosive sleeve setting tool assembly 200 has a top sub 216 connected to the bottom sub 202. Electric signals are sent from the top sub 216 to the initiation cartridge 205 via feed-thru contact pins 212 coupled together with electrically conductive spring 211 and disposed within feed through cap 210. The initiation cartridge 205 includes detonator 219. The expanding slip cylinder 203 is coupled to the downhole end of the bottom sub 202. The expanding slip cylinder 203 includes a plurality of slips 218 located radially about the outside of the slip cylinder 203. A radial groove 221 contains a sealing element 201. The sealing element 201 may be an elastomer seal, glue, other types of adhesives, impact sensitive thermite that ignites when expanded, or a soft metal seal such as copper, aluminum, lead, brass, or some appropriate alloy. The mandrel 204 is located within the slip cylinder 203 and is wrapped in a one or more explosive sheets 208 and 209. The amount of expansion necessary to seal the wellbore casing determines the amount of explosives needed. In this example two sheets of explosives are shown to achieve a desired expansion. Explosive sheets, or energetic elements in general, may be used to expand slip cylinder 203. Explosive sheets 208 and 209 can be made of high explosives such as RDX, HMX, HNS, and PETN. Explosive sheets 208 and 209 can also be made of other energetic materials such as low explosive or propellants (single base or double base powder, black powder, etc.), or thermites, or any mixture of those materials. During operation the setting tool assembly is disposed into a predetermined location in the wellbore casing. An electric signal to the initiation cartridge 205 causes detonator 219 to fire. The boosters 207, located radially about the detonator 219 and held in place by snap rings 213, are ignited. The boosters 207 ignite the explosive sheets 208 and 209. Slip cylinder 203 is sealed from the wellbore by o-rings 214 and 215. The deformation eventually compromises seals provided by o-rings 214 and 215, thus relieving pressure within the slip cylinder 203 and allowing the withdrawal of the mandrel 204 and retention cap 206. Ball seat 217 provides a shoulder for a ball to seat against thus plugging the borehole. An alternative embodiment may include the sleeve having no slips or sealing element and instead relying on the explosive output to cause the sleeve to seal with the casing via friction welding or explosive welding. [32] FIG. 6 shows an example embodiment of a cross section of an expandable sleeve setting tool after setting the slip cylinder 203. In this example sealing element 201 is engaged with the casing 220 to form a seal. Slips 218 are in contact and deformed against the casing 220 to hold the deformed slip cylinder 203 in place. Bottom sub 202 with its o-ring 215, along with mandrel 204, initiation cartridge 205, retention cap 206 with its o-ring 214, top sub 216, and the connection made via contact pins 212 and spring 211 within feed through cap 210 can be withdrawn from the wellbore after the expandable sleeve, in this case slip cylinder 203, has been set

[33] FIG. 7 shows an example embodiment of a cross section of the expandable after setting slip cylinder 203. In this example sealing element 201 is engaged with the casing 220 to form a seal. Slips 218 are in contact and deformed against the casing 220 to hold the deformed slip cylinder 203 in place. Ball 219 is engaged with ball seat 217, thus providing a one way pressure seal within casing 220.

[34] In both embodiments illustrated in FIG. 4 and FIG. 7, the isolation sleeve or expendable sleeve can be constructed so that it is either dissolvable or degradable in down hole conditions where brine or water is present. For degradability, sealing element 107 in FIG.’s 1-4, and sealing element 201 in FIG.’ s 5-7 are made of water-degradable plastics or rubber, or temperature sensitive rubber (epoxy). For water solubility, expanding slip cylinder 101 in FIG.’s 1-4 and slip cylinder 203 in FIG.’s 5-7 are made of hydrolytic metals such as Mg alloy or Mg/Al alloys, of which Mg ranges 5 ~ 100% and/or A1 ranges 0-95% in weight, and other elements ranges 0-20% in weight. Slip element 116 in FIG.’s 1-4 and slip 218 in FIG.’s 5-7 can be hard bits or grits embedded on the slip cylinder. The bits or grits can be made from either tungsten carbide or high strength ceramic (such as zirconia). Dissolvable components may include the slips, sleeve, ball seat, ball, and any sealing elements.

[35] Although the invention has been described in terms of embodiments which are set forth in detail, it should be understood that this is by illustration only and that the invention is not necessarily limited thereto. For example, terms such as upper and lower or top and bottom can be substituted with uphole and downhole, respectfully. Top and bottom could be left and right, respectively. Uphole and downhole could be shown in figures as left and right, respectively, or top and bottom, respectively. Generally downhole tools initially enter the borehole in a vertical orientation, but since some boreholes end up horizontal, the orientation of the tool may change. In that case downhole, lower, or bottom is generally a component in the tool string that enters the borehole before a component referred to as uphole, upper, or top, relatively speaking. The first housing and second housing may be top housing and bottom housing, respectfully. In a gun string such as described herein, the first gun may be the uphole gun or the downhole gun, same for the second gun, and the uphole or downhole references can be swapped as they are merely used to describe the location relationship of the various components. Terms like wellbore, borehole, well, bore, oil well, and other alternatives may be used synonymously. Terms like tool string, tool, perforating gun string, gun string, or downhole tools, and other alternatives may be used synonymously. The alternative embodiments and operating techniques will become apparent to those of ordinary skill in the art in view of the present disclosure. Accordingly, modifications of the invention are contemplated which may be made without departing from the spirit of the claimed invention.

Claims

What is claimed is:

1. A wellbore expandable tool comprising:

a cylindrical expandable sleeve with a plurality of radial slips located about its exterior and a radial sealing element;

a mandrel having a rod portion and a head portion disposed within the expandable sleeve; a piston coupled to the mandrel rod, disposed within the cylindrical expandable sleeve, wherein the piston and cylinder form a pressure chamber;

a power charge disposed within the piston, having a passageway between the power charge and the pressure chamber;

a top sub slideably engaged with the piston; and

wherein the expandable sleeve can be plastically deformed outwards against a wellbore casing with the radial slips engaging the wellbore casing and the sealing element creating a pressure seal against the wellbore casing.

2. The apparatus of claim 1, further comprising a firing head coupled to the top sub.

3. The apparatus of claim 1 , wherein the cylindrical sleeve is expanded by pressure generated by the pyrotechnic bum of the power charge.

4. The apparatus of claim 1, wherein the cylindrical sleeve is expanded mechanically by pulling a mandrel through the hollow cylindrical sleeve.

5. The apparatus of claim 1, wherein the sealing element is an elastomer seal.

6. The apparatus of claim 1, wherein the sealing element is an adhesive.

7. The apparatus of claim 1, wherein the sealing element is an impact sensitive thermite.

8. The apparatus of claim 1, wherein the sealing element is a metal seal.

9. A wellbore seal comprising: a hollow cylindrical sleeve having an inner surface, outer surface, a first end, a second end, a plurality of radial slips, and at least one radial groove on the outer surface;

a sealing element disposed within the at least one radial groove;

a ball seat shoulder on the inner surface, wherein a ball can seat against the shoulder and create a pressure differential between the first end and second end; and

wherein the cylindrical sleeve can be plastically deformed outwards against a wellbore casing with the radial slips engaging the wellbore casing and the sealing element creating a pressure seal against the wellbore casing.

10. The apparatus of claim 9, wherein the cylindrical sleeve is expanded by explosive energy released within the hollow cylindrical sleeve.

11. The apparatus of claim 9, wherein the cylindrical sleeve is expanded mechanically by pulling a mandrel through the hollow cylindrical sleeve.

12. The apparatus of claim 9, wherein the ball seat is located proximate to the first end.

13. The apparatus of claim 9, wherein the ball seat is located proximate to the second end.

14. The apparatus of claim 9, wherein the sealing element is an elastomer seal.

15. The apparatus of claim 9, wherein the sealing element is an adhesive.

16. The apparatus of claim 9, wherein the sealing element is an impact sensitive thermite.

17. The apparatus of claim 9, wherein the sealing element is a metal seal.

18. A wellbore expandable tool comprising:

a cylindrical expandable sleeve with a plurality of radial slips located about its exterior and a radial sealing element further comprising:

a hollow cylindrical sleeve having an inner surface, outer surface, a first end, a second end, a plurality of radial slips, and at least one radial groove on the outer surface; a sealing element disposed within the at least one radial groove;

a ball seat shoulder on the inner surface, wherein a ball can seat against the shoulder and create a pressure differential between the first end and second end;

a mandrel having a rod portion and a head portion disposed within the expandable sleeve; a detonator disposed within the expandable sleeve and having at least one explosive sheet located radially about the detonator; and

wherein the detonation of the at least one explosive radial sheet causes the expandable sleeve can be plastically deformed outwards against a wellbore casing with the radial slips engaging the wellbore casing and the sealing element creating a pressure seal against the wellbore casing.

19. The apparatus of claim 18, wherein the at least one explosive sheet is a plurality of explosive sheets.

20. The apparatus of claim 18, wherein the ball seat is located proximate to the first end.

21. The apparatus of claim 18, wherein the ball seat is located proximate to the second end.

22. The apparatus of claim 18, wherein the sealing element is an elastomer seal.

23. The apparatus of claim 18, wherein the sealing element is an adhesive.

24. The apparatus of claim 18, wherein the sealing element is an impact sensitive thermite.

25. The apparatus of claim 18, wherein the sealing element is a metal seal.

26. A method for sealing a wellbore comprising:

lowering a metal wellbore sleeve coupled to a setting tool to a predetermined location in a wellbore casing, wherein the metal wellbore sleeve includes a plurality of radial slips for engaging with the wellbore casing, a radial sealing element for sealing against the wellbore casing, and a seat for a ball;

expanding the wellbore sleeve against the wellbore;

removing the setting tool from the wellbore;

pumping a ball downhole and engaging it with the seat of the wellbore sleeve; and creating a pressure differential in the wellbore casing across the predetermined location.

27. The method of claim 26 wherein the expanding the wellbore sleeve includes plastically deforming the sleeve against the wellbore mechanically.

28. The method of claim 26 wherein the expanding the wellbore sleeve includes plastically deforming the sleeve against the wellbore mechanically.

29. The method of claim 26 further including dissolving the ball engaged with wellbore sleeve.

30. The method of claim 26 further including milling out the wellbore sleeve.

31. The method of claim 26 further comprising dissolving the wellbore sleeve.

32. The method of claim 26 wherein the radial sealing element is an elastomer seal.

33. The method of claim 26 wherein the radial sealing element is an adhesive.

34. The method of claim 26 wherein the radial sealing element is an impact sensitive thermite.

35. The method of claim 26 wherein the radial sealing element is a metal seal.