ISOLATION PLUG TOOL AND METHOD

Abstract

An isolation plug tool including a mandrel, an anchor assembly disposed on the mandrel, a seal assembly disposed on the mandrel having a seal, and a sleeve removably disposed radially outwardly of the seal.

Description

BACKGROUND

In the resource recovery industry there is often need to isolate a section of borehole, casing or tubing from an adjacent section of borehole, casing or tubing. There are many designs of isolation plugs available in the art but each has its benefits and detriments. Some of the detriments come with cost disadvantages that the industry would prefer to avoid. Accordingly, the art will well receive alternative isolation plugs that provide solid function at reduced cost.

SUMMARY

An embodiment of an isolation plug tool including a mandrel, an anchor assembly disposed on the mandrel, a seal assembly disposed on the mandrel having a seal, and a sleeve removably disposed radially outwardly of the seal.

BRIEF DESCRIPTION OF THE DRAWINGS

The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:

FIG. 1 is a schematic cross section view of an isolation plug tool as described herein in a run-in position;

FIG. 2 is the plug as illustrated in FIG. 1 in the set position; and

FIG. 3 is a schematic elevation view of a wellbore system within which the isolation plug tool is disposed.

DETAILED DESCRIPTION

A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.

Referring to FIGS. 1 and 2, an isolation plug 10 is illustrated in a run-in and set position, respectively. The plug 10 may be run on slick line, electric wireline or coiled tubing. The plug 10 comprises a mandrel 12 upon which an anchor assembly 14 and a seal assembly 16 are disposed. Further, a sleeve 18 is disposed radially outwardly of the seal assembly 16 to protect and deflect seals 20 and 22 during run in. Finally, a trigger assembly 24 is positioned on the mandrel 12 as well that will allow hydrostatic fluid pressure to actuate the tool 10 upon a selected trigger event such as temperature, time, or pressure, for example. Alternatively, the tool may be actuated hydraulically, if desired. The following discussion is applicable to hydrostatic or hydraulic actuation but for the source of pressure. Upon the exposure of the tool 10 to the trigger event, the trigger assembly 24 opens the tool 10 to hydrostatic fluid pressure (or hydraulic pressure is applied) and ports that pressure through pressure pathway 26. Pressure pathway 26 is fluidically connected to an anchor port 28 such that hydrostatic pressure may act upon a hydrostatic chamber 30 which urges piston 32 toward slips 34. Movement of the piston 32 occurs only after the pressure in the hydrostatic chamber 30 is sufficient to place a load upon the piston 32 greater than a release threshold for a release member 36 such as a shear screw. Upon the member 36 releasing, the piston 30 moves toward the slips 34 causing them to move radially outwardly as is depicted in FIG. 2. This motion anchors the tool in the borehole, casing or other tubular as the case may be.

Once the anchor assembly 14 is set, the sleeve 18 may be removed from the tool 10 and simply moved partially uphole or withdrawn from the hole by placing a tensile load on a sleeve mount 38 to which the sleeve 18 is connected. The sleeve mount and sleeve can be seen removed in FIG. 2. Upon removal of sleeve 18, the seals 20 and 22 are allowed to naturally rebound radially outwardly. The degree to which these seals may rebound radially outwardly is greater than the radial capability of common cement plugs because they are both deflected and protected during run in. The seals 20 and 22 themselves thus present no impediment to motion in the borehole during running as they would if not for the sleeve 18 and may be constructed with a larger expanded diameter than would be the case if they were run traditionally. In addition, the tool benefits from a slimmer deployment (running) diameter. In an embodiment, sleeve 18 includes one or more openings 40 to prevent differential pressure being generated across the sleeve 18, which helps avoid difficulty in removing the sleeve 18 from the seals 20 and 22.

Seals 20 and/or 22 may be directional seals in embodiments. As illustrated both seals 20 and 22 are directional and are opposed to one another. In this embodiment, pressure testing may be accomplished for each seal from uphole thereof by utilizing a negative pressure test for the downhole seal 22 and a positive pressure test for the uphole seal 20.

The tool 10 provides an excellent plug for cement in that it anchors positively, and seals in both directions so that cement will not leak past the seal 20 nor may gas leak uphole past seal 22 into the cement. Gas contamination of the cement is avoided and accordingly greater cement integrity is achieved in this manner.

Referring to FIG. 3, a wellbore system 50 is illustrated comprising a borehole 52 in a formation 54. The system 50 as illustrated includes a string 56 having a tool 10 therein run on one of the conveying structures mentioned above (electric wireline, slick line, or coiled tubing). The conveying structure is identified with numeral 58. Finally, cement 60 is illustrated as optionally disposed upon the tool 10.

Set forth below are some embodiments of the foregoing disclosure:

Embodiment 1: An isolation plug tool including a mandrel, an anchor assembly disposed on the mandrel, a seal assembly disposed on the mandrel having a seal, and a sleeve removably disposed radially outwardly of the seal.

Embodiment 2: The isolation plug tool as in any previous embodiment, wherein the anchor assembly includes a slip displaceable to a set position by a piston.

Embodiment 3: The isolation plug tool as in any previous embodiment, wherein the piston is displaceable by hydrostatic or applied hydraulic pressure.

Embodiment 4: The isolation plug tool as in any previous embodiment, wherein the tool further includes a trigger assembly.

Embodiment 5: The isolation plug tool as in any previous embodiment, wherein the trigger assembly is responsive to one or more of temperature, pressure, and time.

Embodiment 6: The isolation plug tool as in any previous embodiment, wherein the seal is a directional seal.

Embodiment 7: The isolation plug tool as in any previous embodiment, wherein seal is a plurality of seals.

Embodiment 8: The isolation plug tool as in any previous embodiment, wherein the plurality of seals are oppositely directional.

Embodiment 9: The isolation plug tool as in any previous embodiment, wherein the sleeve during running compresses a diameter of the seal.

Embodiment 10: The isolation plug tool as in any previous embodiment, wherein the sleeve includes an opening to alleviate differential pressure across the sleeve.

Embodiment 11: A method for isolating one portion of a wellbore from an adjacent portion of the wellbore including deploying a tool as in any previous embodiment into the wellbore, anchoring the tool in the wellbore, and removing the sleeve from the seal.

Embodiment 12: The method as in any previous embodiment, wherein the anchoring includes hydrostatically or hydraulically setting the anchoring assembly.

Embodiment 13: The method as in any previous embodiment, wherein the removing is by applying tensile force to the sleeve.

Embodiment 14: The method as in any previous embodiment, further comprising depositing cement on the tool.

Embodiment 15: A wellbore including a borehole in a formation, a string in the wellbore, and a tool as in any previous embodiment disposed in the string.

Embodiment 16: The wellbore as in any previous embodiment, further including cement disposed on the tool and extending uphole of the tool

The use of the terms “a” and “an” and “the” and similar referents in the context of describing the invention (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Further, it should be noted that the terms “first,” “second,” and the like herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another. The terms “about”, “substantially” and “generally” are intended to include the degree of error associated with measurement of the particular quantity based upon the equipment available at the time of filing the application. For example, “about” and/or “substantially” and/or “generally” can include a range of ±8% or 5%, or 2% of a given value.

The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.

While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited.

Claims

1. An isolation plug tool comprising:

a mandrel;

an anchor assembly disposed on the mandrel;

a seal assembly disposed on the mandrel having a seal; and

a sleeve removably disposed radially outwardly of the seal.

2. The isolation plug tool as claimed in claim 1 wherein the anchor assembly includes a slip displaceable to a set position by a piston.

3. The isolation plug tool as claimed in claim 2 wherein the piston is displaceable by hydrostatic or applied hydraulic pressure.

4. The isolation plug tool as claimed in claim 1 wherein the tool further includes a trigger assembly.

5. The isolation plug tool as claimed in claim 4 wherein the trigger assembly is responsive to one or more of temperature, pressure, and time.

6. The isolation plug tool as claimed in claim 1 wherein the seal is a directional seal.

7. The isolation plug tool as claimed in claim 1 wherein seal is a plurality of seals.

8. The isolation plug tool as claimed in claim 7 wherein the plurality of seals are oppositely directional.

9. The isolation plug tool as claimed in claim 1 wherein the sleeve during running compresses a diameter of the seal.

10. The isolation plug tool as claimed in claim 1 wherein the sleeve includes an opening to alleviate differential pressure across the sleeve.

11. A method for isolating one portion of a wellbore from an adjacent portion of the wellbore comprising:

deploying a tool as claimed in claim 1 into the wellbore;

anchoring the tool in the wellbore; and

removing the sleeve from the seal.

12. The method as claimed in claim 11 wherein the anchoring includes hydrostatically or hydraulically setting the anchoring assembly.

13. The method as claimed in claim 11 wherein the removing is by applying tensile force to the sleeve.

14. The method as claimed in claim 11 further comprising depositing cement on the tool.

15. A wellbore comprising:

a borehole in a formation;

a string in the wellbore; and

a tool as claimed in claim 1 disposed in the string.

16. The wellbore as claimed in claim 15 further including cement disposed on the tool and extending uphole of the tool.