WO2016043773A1

WO2016043773A1 - Swellguard er isolation tool

Info

Publication number: WO2016043773A1
Application number: PCT/US2014/056548
Authority: WO
Inventors: Evan Tanveer RASHID
Original assignee: Halliburton Energy Services, Inc.
Priority date: 2014-09-19
Filing date: 2014-09-19
Publication date: 2016-03-24
Also published as: US20170268308A1; DK201700043A1; DK179178B1; GB201701170D0; CA2958232A1; GB2543683B; GB2543683A; AU2014406447A1; AU2014406447B2; CA2958232C; MX2017000528A; NO20170212A1

Abstract

Methods and devices for multi-interval zonal isolation are disclosed. An isolation tool assembly adapted to provide zonal isolation includes a tubular member, a swellable packer disposed around the tubular member, and a plurality of rubber elements disposed around the tubular member. The isolation tool assembly further includes a sliding sleeve disposed within the tubular member, wherein the sliding sleeve is operable to slide in response to an annular pressure differential. The isolation tool assembly further includes a top sub coupled to the tubular member and adjacent one or more expansion devices, and a bottom sub coupled to the tubular member.

Description

SWELLGUARD ER ISOLATION TOOL

BACKGROUND

[0001] The present invention relates to methods and devices for treating multiple interval wellbores and more particularly, the use of an expandable radius isolation tool to provide zonal isolation for stimulation, fracturing or general production operations in multiple interval wellbores.

[0002] Oil and gas wells often produce hydrocarbons from more than one subterranean zone or wellbore interval. Occasionally, it is desired to treat or retreat one or more intervals of a wellbore. Reasons for treating or retreating intervals of a wellbore include the need to stimulate or re-stimulate an interval as a result of declining productivity during the life of the well. Examples of stimulation treatments include fracturing treatments and acid stimulation. Other treating operations include conformance treatments, sand control treatments, blocking or isolating intervals, consolidating treatments, sealing treatments, or any combination thereof.

[0003] One difficulty in treating a selected interval of an already producing wellbore is the lack of zonal isolation between intervals. That is, each of the selected intervals to be treated may be in fluid communication with other intervals of the wellbore. This lack of isolation between intervals can prevent targeted treatments to selected intervals because treatments intended for one selected interval may inadvertently flow into an unintended interval. Thus, before treating or re-treating a selected interval of a wellbore, the selected interval will often be isolated from the other intervals of the wellbore. In this way, treatments may be targeted to specific intervals.

[0004] Conventional methods for re-isolation of wellbore intervals include the use of isolation devices such as, for example, straddle packers, packers with sand plugs, packers with bridge plugs, isolation via cementing, and combinations thereof. Such conventional methods, however, can suffer from a number of disadvantages including lower rate throughputs due to additional wellbore restrictions inherent in such methods, poor isolation between intervals, and depletion between intervals.

[0005] Thus, a need exists for an improved method for providing isolation between wellbore intervals to allow treatment or retreatment of selected intervals in multiple interval wellbores. BRIEF DESCRIPTION OF THE DRAWINGS

[0006] These drawings illustrate certain aspects of some of the embodiments of the present invention, and should not be used to limit or define the invention.

[0007] Figure 1 illustrates a wellbore having a casing string disposed therein.

[0008] Figure 2 illustrates a cross-sectional view of an isolation tool assembly in a wellbore providing isolation of selected intervals of a wellbore, in accordance with an illustrative embodiment of the present invention.

[0009] Figure 3 is a flowchart depicting illustrative method steps associated with activating the isolation tool assembly of Figure 2, in accordance with an illustrative embodiment of the present disclosure.

[0010] Figures 4A-4C illustrates a cross-sectional view of the isolation tool assembly of Figure 2 and illustrative method steps associated with activating the isolation tool assembly of Figure 2, in accordance with an illustrative embodiment of the present invention.

DETAILED DESCRIPTION

[001 1] The present invention relates to methods and devices for treating multiple interval wellbores and more particularly, the use of an expandable radius isolation tool to provide zonal isolation for stimulation, fracturing or general production operations in multiple interval wellbores.

[0012] The methods and devices in accordance with the present disclosure may allow for reestablishing zonal isolation of producing intervals, bypassed, or non-producing intervals, or previously producing intervals in multiple interval wellbores through the use of an expandable radius isolation tool. The methods and devices in accordance with the present disclosure may further provide zonal isolation for stimulation, fracturing or general production operations. In certain embodiments, isolation tool assemblies in accordance with the present disclosure may comprise a top sub, a tubular member, one or more expansion devices, a plurality of rubber elements forming a seal, a swellable packer, a sliding sleeve, and a bottom sub. The methods in accordance with the present disclosure may allow the expandable radius isolation tool to be run in an open hole or cased hole. Once the isolation tool reaches its desired depth, the swellable packer may be activated, a pressure differential may be created, and pressure from the annulus may be applied to shift a sleeve into place and compress the plurality of rubber elements, thus expanding the radius of the isolation tool and forming a seal.

[0013] To facilitate a better understanding of the present invention, the following examples of certain embodiments are given. In no way should the following examples be read to limit, or define, the scope of the invention. Embodiments of the present disclosure may be applicable to horizontal, vertical, deviated, or otherwise nonlinear wellbores in any type of subterranean formation. Embodiments may be applicable to injection wells, monitoring wells, and production wells, including hydrocarbon or geo hermal wells. Embodiments described below with respect to one implementation are not intended to be limiting.

[0014] The terms "couple" or "couples" as used herein are intended to mean either an indirect or a direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection, or through an indirect mechanical or electrical connection via other devices and connections. The term "uphole" as used herein means along the drillstring or the hole from the distal end towards the surface, and "downhole" as used herein means along the drillstring or the hole from the surface towards the distal end.

[0015] Figure 1 illustrates a typical wellbore after drilling. In Figure 1, a casing or casing string 105 is disposed in wellbore 140.

[0016] Figure 2 illustrates a cross-sectional view of an isolation tool assembly 100 in accordance with the present disclosure. The isolation tool assembly 100 may include a top sub 1 10, a tubular member 120, one or more expansion devices 1 15, a plurality of rubber elements 130, a swellable packer 160, a sliding sleeve 170, and a bottom sub 180. The top sub 1 10 may be used to attach the isolation tool assembly 100 to a tubing string. The tubular member 120 may be a tubular pipe or mandrel, metal pipe, or other tubing known to one of ordinary skill in the art, and the tubular member 120 may further be inserted into the wellbore 140 as single tubing, tubing spliced by connectors, or tubing spliced by welding. As would be appreciated by one of ordinary skill in the art with the benefit of the present disclosure, the tubular member 120 may have any suitable size and length for the particular application. The one or more expansion devices 1 15 may comprise one or more mechanical seal expansion lugs, and may apply pressure to compress the plurality of rubber elements 130 in a first direction and expand the plurality of rubber elements 130 in a second direction. In certain embodiments, the first direction may be generally parallel with the length of the isolation tool assembly 100 and the second direction may be generally perpendicular to the length of the isolation tool assembly 100 and into the wellbore 140. The plurality of rubber elements 130 may form a seal. The plurality of rubber elements 130 may be disposed about the tubular member 120 and in close proximity to the one or more expansion devices 115. The swellable packer 160 may be disposed about the tubular member 120. The sliding sleeve 170 may be disposed within the tubular member 120. The bottom sub 180 may be used to attach the isolation tool assembly 100 to a tubing string.

[0017] The isolation tool assembly 100 may further comprise a spacer ring 175 separating the plurality of rubber elements 130 from the expansion devices 1 15. The spacer ring 175 may help compress the plurality of rubber elements 130. The isolation tool assembly 100 may further comprise a center ring 185 separating the plurality of rubber elements 130 from the swellable packer 160. The center ring 185 may provide support for the compression of the plurality of rubber elements 130.

[0018] Swellable packer 160 may be any elastomeric sleeve, ring, or band suitable for creating a fluid tight seal between tubular member 120 and an outer tubing, casing, or wellbore in which tubular member 120 is disposed, for example, casing 105. As would be appreciated by one of ordinary skill in the art with the benefit of the present disclosure, the swellable packer 160 may any material, shape, and size. In certain embodiments, the swellable packer 160 may be designed for the conditions anticipated at each selected interval in which the isolation tool assembly 100 is being used, taking into account the expected temperatures and pressures, for example. In certain embodiments, only a portion of the swellable packer 160 may comprise a swellable material. [0019] The term "swellable" is used herein to indicate an increase in volume of a material. Typically, this increase in volume is due to incorporation of molecular components of a fluid into the swellable material itself, but other swelling mechanisms or techniques may be used, if desired. The swellable material may swell when contacted by an activating agent, such as an inorganic or organic fluid. In one embodiment, a swellable material may be a material that swells upon contact with and/or absorption of a hydrocarbon, such as oil. In another embodiment, a swellable material may be a material that swells upon contact with and/or absorption of an aqueous fluid. Suitable activating agents are discussed later in the disclosure with reference to methods associated with multi-interval zonal isolation utilizing the isolation tool assembly of the present disclosure.

[0020] Some exemplary swellable materials may include, but are not limited to, elastic polymers, such as EPDM rubber, styrene butadiene, natural rubber, ethylene propylene monomer rubber, ethylene-propylene-copolymer rubber, ethylene propylene diene monomer rubber, ethylene-propylene-diene terpolymer rubber, ethylene vinyl acetate rubber, hydrogenized acrylonitrile butadiene rubber, acrylonitrile butadiene rubber, isoprene rubber, butyl rubber, halogenated butyl rubber, brominated butyl rubber, chlorinated butyl rubber, chlorinated polyethylene, chloroprene rubber and polynorbornene. In one embodiment, the rubber of the swellable material may also have other materials dissolved in or in mechanical mixture therewith, such as fibers of cellulose. Additional options may be rubber in mechanical mixture with polyvinyl chloride, methyl methacrylate, acrylonitrile, ethylacetate or other polymers that expand in contact with oil. Other swellable materials that behave in a similar fashion with respect to hydrocarbon fluids or aqueous fluids also may be suitable. Those of ordinary skill in the art, with the benefit of this disclosure, will be able to select an appropriate swellable material for use in the present invention based on a variety of factors, including the desired swelling characteristics of the swellable material and the environmental conditions in which it is to be deployed.

[0021] Operation of the isolation tool assembly 100 in accordance with the illustrative embodiment of Figure 2 will now be discussed in conjunction with Figure 3. Figure 3 is a flowchart depicting illustrative method steps associated with a method for multi-interval zonal isolation utilizing the isolation tool assembly 100, in accordance with an illustrative embodiment of the present disclosure. Although a number of steps are depicted in Figure 3, as would be appreciated by those of ordinary skill in the art, having the benefit of the present disclosure, one or more of the recited steps may be eliminated or modified without departing from the scope of the present disclosure. [0022] First, at step 302, the isolation tool assembly 100 may be introduced into a wellbore. At step 304, the swellable packer 160 may swell in the presence of an activating agent. At step 306, an annular pressure differential may be generated. As would be appreciated by one of ordinary skill in the art with the benefit of the present disclosure, the annular pressure differential is the difference between the pressure present on a first side of the isolation tool assembly and the pressure present on a second side of the isolation tool assembly, as described below with reference to Figure 4C. The annular pressure differential may adjust the positioning of the sliding sleeve 170. In certain embodiments, adjusting the positioning of the sliding sleeve 170 may activate the expansion devices 115. At step 308, the expansion devices 115 may be activated. In certain embodiments, activating the expansion devices 115 may compress the plurality of rubber elements 130 in a first direction. At step 310, the compression of the plurality of rubber elements 130 may expand the plurality of rubber elements 130 in a second direction to form a seal and provide zonal isolation of one or more selected intervals.

[0023] Figures 4A-4C depict a sequence of method steps associated with multi-interval zonal isolation utilizing the isolation tool assembly 400, in accordance with certain embodiments of the present disclosure. Referring to Figure 4A, Figure 4A illustrates a cross-sectional view of isolation tool assembly 400 disposed in casing or tubing string 405 of wellbore 440. Although wellbore 440 is depicted here as a vertical well, it is recognized that isolation assembly 400 may be used in horizontal and deviated wells in addition to vertical wells. Additionally, it is expressly recognized that isolation tool assembly 400 may extend the entire length of wellbore 440 (i.e., effectively isolating the entire string 405) or only along a longitudinal portion of wellbore 440 as desired.

[0024] Referring to Figure 4B, the swelling of the swellable packer 460 may be initiated by allowing an activating agent, such as, for example, a hydrocarbon to contact the swellable packer 460. In certain embodiments, the swelling of the swellable packer 460 may be initiated by spotting the activating agent across the swellable packer 460 with a suitable fluid. As would be appreciated by one of ordinary skill in the art with the benefit of this disclosure, the activating agent may be placed in contact with the swellable material in a number of other ways not specifically described herein.

[0025] As would be appreciated by one of ordinary skill the art with the benefit of the present disclosure, the selection of the activating agent depends on the composition of the swellable material as well as the wellbore environment. Suitable activating agents include any hydrocarbon-based fluids such as crude oil, natural gas, oil-based solvents, diesel, condensate, aqueous fluids, gases, or any combination thereof. The spotting of the swellable packers may occur before, after, or during the introduction of the isolation tool assembly 460 into the wellbore 440. In some cases, a reservoir fluid may be allowed to contact the swellable packer 460 to initiate swelling of the swellable packer 460.

[0026] Referring to Figure 4C, once the swellable packer 460 swells, an annular differential pressure may be created across the isolation tool assembly 400. The annular differential pressure may be created from the surface by additional pressure pumped into annulus. In certain embodiments in accordance with the present disclosure, to effectuate the annular pressure differential, any suitable fluid may be pumped into the annulus, as would be appreciated by one of ordinary skill in the art, including, but not limited to, water, diesel, and completion fluids. As would be appreciated by one of ordinary skill in the art with the benefit of the present disclosure, the applied pressure from the surface will not pass through the seal created by the activated (i.e., swollen) swellable packer 460. Thus, the pressure at the bottom of the seal remains the same while the pressure on top of the seal is increased due to the applied annular pressure, thus creating the annular differential pressure. As would be appreciated by one of ordinary skill in the art with the benefit of the present disclosure, the pumping of additional pressure into the annulus from the surface may be controlled by pumps on surface.

[0027] In certain embodiments in accordance with the present disclosure, the annular pressure differential may adjust the positioning of the sliding sleeve 470. In certain embodiments, adjusting the positioning of the sliding sleeve 470 may activate the expansion devices 415. In certain embodiments, activating the expansion devices 415 may compress the plurality of rubber elements 430 in a first direction, which in turn may expand the plurality of rubber elements 430 in a second direction. In certain embodiments, the plurality of rubber elements 430 may be compressed in a first direction so as to expand the plurality of rubber elements 430 in a second direction to form a seal and provide zonal isolation of one or more selected intervals. In certain embodiments, the formed seal may be a mechanical seal. In certain embodiments, the spacer ring 475 separating the plurality of the rubber elements 430 from the expansion devices 415 may help compress and expand the plurality of rubber elements 430, and the center ring 485 separating the plurality of rubber elements 430 from the swellable packer 460 may provide support for the compression and expansion of the plurality of rubber elements 430. Thus, in this manner, the annular differential pressure may expand the one or more expansion devices 415, which may in turn compress the plurality of rubber elements 430, which may in turn activate the mechanical seal. Although the illustrative embodiments are discussed in conjunction with utilizing a swellable packer, the present disclosure is not limited to this specific embodiment. For instance, another device may be used to apply pressure and activate the sliding sleeve 470.

[0028] As would be appreciated by one of ordinary skill the art with the benefit of the present disclosure, the swelling of swellable packer 460 and activation of isolation tool assembly 400 may cause an interference fit between tubular member 420 and string 405 so as to provide fluidic isolation between selected intervals along the length of the wellbore 440. The fluidic isolation may provide zonal isolation between intervals that were previously not fluidly isolated from one another. In this way, integrity of a previously perforated casing may be reestablished. That is, the isolation tool assembly 400 may be used to re-isolate intervals from one another as desired. As would further be appreciated by one of ordinary skill the art with the benefit of the present disclosure, the isolation tool assembly 400 may be positioned to isolate intervals that will no longer be produced such as intervals producing excessive water. As would further be appreciated by one of ordinary skill the art with the benefit of the present disclosure, once the isolation tool assembly 400 is in place and has been activated to provide fluidic isolation between the intervals, selected intervals may be isolated and perforated as desired to allow treatment of the selected intervals. For example, as illustrated in Figure 4C, the string 405 may be perforated at fracture zones above and below the isolation tool assembly 400. In certain embodiments in accordance with the present disclosure, perforations 450 may allow fluid communication to each of the perforated intervals along wellbore 440.

[0029] Although isolation tool assembly 400 is shown as providing isolation along string 405, it is expressly recognized that isolation tool assembly 400 may provide isolation to an openhole without a casing or tubing string or to a gravel pack as desired. Thus, string 405 is not a required feature in all embodiments of the present invention. In other words, the depiction of string 405 in the figures is merely illustrative and should in no way require the presence of string 405 in all embodiments of the present invention.

[0030] The isolation tool assembly of the present disclosure may have a variety of uses.

In an illustrative embodiment, and without limitation, the isolation tool assembly of the present disclosure may run in conjunction with hydraulic fracturing tools for multi-stage hydraulic fracturing. For example, two fracturing sleeves and two isolation tool assemblies in accordance with the present disclosure may be run in hole in a series. However, it will be appreciated the any suitable number of isolation tool assemblies may be employed in any suitable operation and remain within the scope of the present disclosure.

[0031] In addition, the isolation tool assembly may include a planned delay barrier system, although it should be appreciated by one of ordinary skill in the art that delay systems may not be necessary in certain embodiments in accordance with the present disclosure. In accordance with certain embodiments of the present disclosure, delay systems may be used to delay the swelling activation. In certain embodiments, for example, swellable material elements may be encapsulated so that they generally do not swell until after a delay period after exposure to hydrocarbon and/or water. After the delay period, the hydrocarbon is absorbed into the swellable material such that the volume of the swellable material increases creating an expansion of the swellable material. Further, a delay system may be applied in such a fashion that an isolation tool assembly located at the bottom-most zone may swell first followed by consecutive packers moving uphole. In this manner, only the bottom-most isolation tool assembly will be initially activated fully by applying the annular pressure. In this example, after fracturing the zone underneath the bottom-most isolation tool assembly, an isolation tool assembly located in a second portion of the string, uphole from the bottom-most portion, may then be activated by applying additional annular pressure and fracturing operations on a second zone may be carried out. In this manner, the activation of the isolation tool assemblies (and sealing of various zones) will be gradually delayed coming from toe to heel. Accordingly, certain embodiments according to the present disclosure may provide zonal isolation on demand, being able to hold differential pressure and avoid losses to the formation. Thus, certain embodiments may ensure well integrity and may provide reliable zonal isolation in open hole and cased hole implementations.

[0032] An embodiment of the present disclosure is an isolation tool assembly adapted to provide zonal isolation. The isolation tool assembly includes a tubular member, a swellable packer disposed around the tubular member, and a plurality of rubber elements disposed around the tubular member. The isolation tool assembly further includes a sliding sleeve disposed within the tubular member, wherein the sliding sleeve is operable to slide in response to an annular pressure differential. The isolation tool assembly further includes a top sub coupled to the tubular member and adjacent one or more expansion devices, and a bottom sub coupled to the tubular member.

[0033] Optionally, the one or more expansion devices is coupled to a spacer ring, and the spacer ring separates the plurality of rubber elements from the one or more expansion devices. Optionally, the one or more expansion devices are operable to compress the plurality of rubber elements in a first direction, and the spacer ring is operable to assist in compressing the plurality of rubber elements. Optionally, isolation tool assembly further includes a center ring separating the plurality of rubber elements from the swellable packer. Optionally, the plurality of rubber elements are compressible in a first direction and expandable in a second direction and operable to form a seal when compressed. Optionally, the formed seal is a mechanical seal. Optionally, the swellable packer swells when it comes in contact with a material selected from the group consisting of water and a hydrocarbon.

[0034] Another embodiment of the present disclosure is a method for multi-interval zonal isolation. The method includes introducing an isolation tool assembly to a wellbore. The isolation tool assembly includes a tubular member, a swellable packer disposed around the tubular member, and a plurality of rubber elements disposed around the tubular member. The isolation tool assembly further includes a sliding sleeve disposed within the tubular member, wherein the sliding sleeve is operable to slide in response to an annular pressure differential. The isolation tool assembly further includes a top sub coupled to the tubular member and adjacent one or more expansion devices, and a bottom sub coupled to the tubular member. The method further includes swelling the swellable packer, generating an annular pressure differential to adjust the positioning of the sliding sleeve, and activating the expansion devices to compress the plurality of rubber elements.

[0035] Optionally, the method further includes coupling the isolation tool assembly to one of a casing string or a tubing string. Optionally, adjusting the positioning of the sliding sleeve activates the expansion devices. Optionally, the method further includes expanding the plurality of rubber elements to form a seal and provide zonal isolation of one or more selected intervals. Optionally, the formed seal is a mechanical seal. Optionally, the one or more expansion devices are operable to compress the plurality of rubber elements in a first direction, and the plurality of rubber elements are compressible in a first direction and expandable in a second direction and operable to form a seal when compressed. Optionally, the swellable packer swells when it comes in contact with a material selected from the group consisting of water and a hydrocarbon.

[0036] Another embodiment of the present disclosure is a method for multi-interval zonal isolation. The method includes introducing a plurality of isolation tool assemblies to a wellbore. Each of the isolation tool assemblies includes a tubular member, a swellable packer disposed around the tubular member, a plurality of rubber elements disposed around the tubular member, a sliding sleeve disposed within the tubular member, a top sub coupled to the tubular member and adjacent one or more expansion devices, and a bottom sub coupled to the tubular member. The method further includes swelling the swellable packer of a first isolation tool assembly. The method further includes generating an annular pressure differential to adjust the positioning of the sliding sleeve of the first isolation tool assembly. The method further includes activating the expansion devices of the first isolation tool assembly, wherein activating the expansion devices of the first isolation tool assembly compresses the plurality of rubber elements of the first isolation tool assembly in a first direction so as to expand the plurality of rubber elements of the first isolation tool assembly in a second direction to form a seal and provide zonal isolation of a first selected interval. Further, the method includes swelling the swellable packer of a second isolation tool assembly. The method further includes generating an annular pressure differential to adjust the positioning of the sliding sleeve of the second isolation tool assembly. The method further includes activating the expansion devices of the second isolation tool assembly, wherein activating the expansion devices of the second isolation tool assembly compresses the plurality of rubber elements of the second isolation tool assembly in a first direction so as to expand the plurality of rubber elements of the second isolation tool assembly in a second direction to form a seal and provide zonal isolation of a second selected interval.

[0037] Optionally, the formed seals are mechanical seals. Optionally, the sliding sleeve of each of the plurality of isolation tool assemblies is operable to slide in response to the annular pressure differential. Optionally, the swellable packer of the second isolation tool assembly is encapsulated to delay swelling of the swellable packer. Optionally, the first isolation tool assembly is located downhole from the second isolation tool assembly.

[0038] Optionally, the method further includes swelling the swellable packer of a third isolation tool assembly, generating an annular pressure differential to adjust the positioning of the sliding sleeve of the third isolation tool assembly, and activating the expansion devices of the third isolation tool assembly, wherein activating the expansion devices of the third isolation tool assembly compresses the plurality of rubber elements of the third isolation tool assembly in a first direction so as to expand the plurality of rubber elements of the third isolation tool assembly in a second direction to form a seal and provide zonal isolation of a third selected interval.

[0039] Therefore, the present invention is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present invention. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee.

Claims

What is claimed is:

1. An isolation tool assembly adapted to provide zonal isolation comprising:

a tubular member;

a swellable packer disposed around the tubular member;

a plurality of rubber elements disposed around the tubular member; a sliding sleeve disposed within the tubular member;

wherein the sliding sleeve is operable to slide in response to an annular pressure differential;

a top sub coupled to the tubular member and adjacent one or more expansion devices; and

a bottom sub coupled to the tubular member.

2. The isolation tool assembly of claim 1, wherein the one or more expansion devices are coupled to a spacer ring, and wherein the spacer ring separates the plurality of rubber elements from the one or more expansion devices.

3. The isolation tool assembly of claim 2, wherein the one or more expansion devices are operable to compress the plurality of rubber elements in a first direction, and wherein the spacer ring is operable to assist in compressing the plurality of rubber elements.

4. The isolation tool assembly of claim 1, further comprising a center ring separating the plurality of rubber elements from the swellable packer.

5. The isolation tool assembly of claim 1, wherein the plurality of rubber elements are compressible in a first direction and expandable in a second direction and operable to form a seal when compressed.

6. The isolation tool assembly of claim 5, wherein the formed seal is a mechanical seal.

7. The isolation tool assembly of claim 1, wherein the swellable packer swells when it comes in contact with a material selected from the group consisting of water and a hydrocarbon.

8. A method for multi-interval zonal isolation comprising the steps of: introducing an isolation tool assembly to a wellbore, the isolation tool assembly comprising:

a tubular member;

a swellable packer disposed around the tubular member;

a plurality of rubber elements disposed around the tubular member;

a sliding sleeve disposed within the tubular member;

a bottom sub coupled to the tubular member;

swelling the swellable packer;

generating an annular pressure differential to adjust the positioning of the sliding sleeve; and

activating the expansion devices to compress the plurality of rubber elements.

9. The method of claim 8, further comprising the step of coupling the isolation tool assembly to one of a casing string or a tubing string.

10. The method of claim 8, wherein adjusting the positioning of the sliding sleeve activates the expansion devices.

11. The method of claim 8, further comprising the step of expanding the plurality of rubber elements to form a seal and provide zonal isolation of one or more selected intervals.

12. The method of claim 1 1, wherein the formed seal is a mechanical seal.

13. The method of claim 8, wherein the one or more expansion devices are operable to compress the plurality of rubber elements in a first direction, and wherein the plurality of rubber elements are compressible in a first direction and expandable in a second direction and operable to form a seal when compressed.

14. The method of claim 8, wherein the swellable packer swells when it comes in contact with a material selected from the group consisting of water and a hydrocarbon.

15. A method for multi-interval zonal isolation comprising the steps of: introducing a plurality of isolation tool assemblies to a wellbore, each of the isolation tool assemblies comprising: a tubular member; a swellable packer disposed around the tubular member; a plurality of rubber elements disposed around the tubular member; a sliding sleeve disposed within the tubular member; a top sub coupled to the tubular member and adjacent one or more expansion devices; and a bottom sub coupled to the tubular member;

swelling the swellable packer of a first isolation tool assembly;

generating an annular pressure differential to adjust the positioning of the sliding sleeve of the first isolation tool assembly;

activating the expansion devices of the first isolation tool assembly;

wherein activating the expansion devices of the first isolation tool assembly compresses the plurality of rubber elements of the first isolation tool assembly in a first direction so as to expand the plurality of rubber elements of the first isolation tool assembly in a second direction to form a seal and provide zonal isolation of a first selected interval;

swelling the swellable packer of a second isolation tool assembly; generating an annular pressure differential to adjust the positioning of the sliding sleeve of the second isolation tool assembly; and

activating the expansion devices of the second isolation tool assembly;

wherein activating the expansion devices of the second isolation tool assembly compresses the plurality of rubber elements of the second isolation tool assembly in a first direction so as to expand the plurality of rubber elements of the second isolation tool assembly in a second direction to form a seal and provide zonal isolation of a second selected interval.

16. The method of claim 15, wherein the formed seals are mechanical seals.

17. The method of claim 15, wherein the sliding sleeve of each of the plurality of isolation tool assemblies is operable to slide in response to the annular pressure differential.

18. The method of claim 15, wherein the swellable packer of the second isolation tool assembly is encapsulated to delay swelling of the swellable packer.

19. The method of claim 15, wherein the first isolation tool assembly is located downhole from the second isolation tool assembly. The method of claim 15, further comprising the steps of:

swelling the swellable packer of a third isolation tool assembly;

generating an annular pressure differential to adjust the positioning of the sliding sleeve of the third isolation tool assembly; and

activating the expansion devices of the third isolation tool assembly;

wherein activating the expansion devices of the third isolation tool assembly compresses the plurality of rubber elements of the third isolation tool assembly in a first direction so as to expand the plurality of rubber elements of the third isolation tool assembly in a second direction to form a seal and provide zonal isolation of a third selected interval.