PACKER

Abstract

A packer includes a sealing element, a gage and a plurality of foldback rings. The rings are located between the gage and the sealing element.

Description

BACKGROUND

The invention generally relates to a packer.

A packer is a tool that typically is used in a well for purposes of forming an annular seal between the outer surface of a string (a production tubing, for example) and either the surrounding casing or borehole wall, depending on whether the well is cased. The packer typically includes a ring-like elastomer seal element, which is longitudinally compressed by the thimbles, or gages, of the packer to cause the seal element to radially expand to form the annular seal when the packer is set.

When compressed, the seal element has a tendency to undergo longitudinal extrusion. Because significant longitudinal extrusion may cause a loss of the annular seal (and potentially a catastrophic blowout), the packer typically includes a seal backup system to limit the extent of the longitudinal extrusion. Ideally, a backup system prevents catastrophic blowout of the elastomer seal element at the well pressure; is fully set with a limited setting force; and allows the packer to be unset (for retrievable packers). It may be challenging for a conventional backup system to accomplish these goals, due to ever-increasing well pressure in the environment in which the packer operates.

SUMMARY

In an embodiment of the invention, a packer includes a sealing element, a gage and a plurality of foldback rings. The rings are located between the gage and the sealing element.

In another embodiment of the invention, a system includes a packer and tubular member, which defines an annulus in the well. The packer is adapted to seal off the annulus in response to the packer being set. The packer includes a sealing element, a gage and a plurality of foldback rings, which are located between the gage and the sealing element.

In yet another embodiment of the invention, a technique that is usable with a well includes compressing a sealing element between gages to form an annular seal in the well. The technique includes controlling extrusion of the sealing element, a control that includes deforming a plurality of rings that are located between one of the gages and the sealing element.

Advantages and other features of the invention will become apparent from the following drawing, description and claims.

BRIEF DESCRIPTION OF THE DRAWING

FIG. 1 is a schematic diagram of a packer before the packer is set according to an embodiment of the invention.

FIG. 2 illustrates cross-sectional profiles of foldback rings of the packer according to an embodiment of the invention.

FIG. 3 is a schematic diagram depicting a more detailed view of a section of the packer of FIG. 1 when the packer is set according to an embodiment of the invention.

FIG. 4 is a schematic diagram illustrating features of another packer before the packer is set according to another embodiment of the invention.

FIG. 5 is a schematic diagram depicting the features of FIG. 4 when the packer is set according to an embodiment of the invention.

FIG. 6 is a schematic diagram depicting features of another packer before the packer is set according to another embodiment of the invention.

FIG. 7 is a schematic diagram of a well according to an embodiment of the invention.

DETAILED DESCRIPTION

Referring to FIG. 1, in accordance with embodiments of the invention, a packer 20 (depicted before being set in FIG. 1) includes a seal element 32, which may be formed from several elastomer seal rings (seals rings 32a, 32b and 32c, depicted as examples). The seal rings 32a, 32b and 32c surround an inner tubular member 24 (which contains the packer's central passageway) of the packer 20; circumscribe a longitudinal axis 62 of the packer 20; and are exposed to an annulus 12 that exists between the rings 32a, 32b and 32c and the inner surface of a well casing 10. It is noted that the seal element 32 may be formed from more or less than three seal rings (one seal ring, for example), depending on the particular embodiment of the invention. The seal element 32 is constructed to be radially expanded when the packer 20 is set to form an annular seal between the outer surface of the tubular member 24 and the interior surface of the casing 10. For other embodiments of the invention in which the borehole is uncased, the seal element 32 expands (when the packer 20 is set) to form a seal with the surrounding borehole wall.

For purposes of compressing the seal element 32 when the packer 20 is set, the packer 20 includes collars, or gages (also called “thimbles”), that slide together to compress the seal element 32, which is located in between. More specifically, in accordance with some embodiments of the invention, the packer 20 includes upper 35 and lower 36 gages, which longitudinally compress the seal element 32 (when the packer 20 is set) to radially expand the element 32. In this regard, the packer 20 may include a mandrel (not shown in FIG. 1) that moves when the packer 20 is being set for purposes of moving one or both of the gages 35 and 36 to compress the seal element 32.

For purposes of limiting, if not preventing, the longitudinal extrusion of the seal element 32 when the packer 20 is set, the packer 20 includes a seal backup system, which includes multiple foldback rings between each gage 35, 36 and the seal element 32. More particularly, the seal backup system includes foldback rings 46 and 50 that are concentric with the longitudinal axis 62 of the packer 20 and surround the inner tubular member 24. Longitudinally, the foldback rings 46 and 50 are located between an upper edge 33 of the seal element 32 and the upper gage 35. The seal backup system also includes foldback rings 48 and 52 that are concentric with the longitudinal axis 62; surround the tubular member 24; and are longitudinally located between a lower edge 34 of the seal element 32 and the lower gage 36.

The foldback rings 46 and 48, which are located closest to the seal element 32, are primary foldback rings that generally conform to the profiles of the edges 33 and 34, respectively; and provide the overall strength to minimize longitudinal extrusion of the seal element 32. Foldback ring 50 is a secondary foldback ring that forms a buffer between the primary ring 46 and the upper gage 35; and likewise, foldback ring 52 is a secondary foldback ring that forms a buffer between the primary foldback ring 48 and the lower gage 36. As described further below, the secondary foldback rings 50 and 52 allow the seal element 32 to achieve higher pressure ratings without compromising the seal element's ability to be set or retrieved, because the secondary foldback rings 50 and 52 do not touch the casing 10 when the packer 20 is set.

Each of the secondary foldback rings 50 and 52 effectively increases the outer diameter of its associated gage, 35,36, which, in turn, increases the pressure handling capability of the seal element 32. Furthermore, each secondary foldback ring 50, 52 effectively reduces the longitudinal extrusion of the seal element 32 by a minimum of the thickness of the ring 50, 52 itself. Additionally, the secondary foldback rings 50 and 52 reduce the stress risers that are applied to the primary foldback rings 46 and 48 by the gages 35 and 36, as further described below.

FIG. 1 depicts features of the packer 20 relevant to the annular seal element 32 and its backup system. However, as can be appreciated by one skilled in the art, the packer 20 may have many additional features, such as slips to secure the packer 20 to the casing 10, one or more mandrels to activate the slips and move the gages 35 and 36, etc.

As depicted in FIG. 1, when the packer 20 is first run downhole and unset, only the outer edges of the secondary foldback ring 50 and 52 touch the adjacent primary foldback ring 46, 48. This arrangement maximizes the moment forces that are applied to the secondary foldback rings 50 and 52 when the packer 20 is set and thus, reduces the overall force that is needed to set the packer 20.

The specific geometries of the primary 48 and secondary 52 foldback rings are illustrated in FIG. 2, which is an enhanced view of section 60 of FIG. 1. The primary 46 and secondary 50 foldback rings may have similar designs to the primary 48 and secondary 52 foldback rings, in accordance with some embodiments of the invention. Thus, the primary foldback rings 46 and 48 may be identical and the secondary foldback rings 50 and 52 may be identical, in accordance with some embodiments of the invention.

Referring to FIG. 2 in conjunction with FIG. 1, the primary foldback ring 48, in accordance with some embodiments of the invention, generally follows the profile of the lower edge 34 of the seal element 32 when the packer 20 is unset. As shown in FIG. 2, the primary foldback ring 48 radially extends between an inner edge 48d (closest to the outer surface of the tubular member 24) of the ring 48 and an outer edge 48e of the ring 48. In this regard, the primary foldback ring 48 includes three annular sections: a first annular section 48a, which is radially closest to the tubular member 24 and extends radially away from the longitudinal axis 62 with generally no longitudinal variation; a middle annular section 48b that radially extends away from the annular section 48a and longitudinally increases at an angle 64; and an outer section 48c that extends upwardly from the annular section 48b and has a generally constant radius with respect to the longitudinal axis 62.

In accordance with some embodiments of the invention, the secondary foldback ring 52 is constructed so that only an outer edge 52c of the ring 52 contacts the primary foldback ring 48 when the packer 20 is unset. For purposes of forming this relationship between the primary 48 and secondary 52 foldback rings, the foldback ring 52 has an inclined section 52b, which rises at a steeper angle 66 (with respect to the longitudinal axis 62) than the section 48b of the primary foldback ring 48. More specifically, in accordance with some embodiments of the invention, the secondary foldback ring 52 radially extends between an inner edge 52d and the outer edge 52 and includes two annular sections: a first inner annular section 52a, which closely circumscribes the outer surface of the tubular member 24 (FIG. 1) and generally has no longitudinal variation; and an outer annular section 52b, which radially extends away from the annular section 52a and longitudinally increases at the angle 66.

FIG. 3 generally depicts the detailed section 60 (see FIG. 1) in a state that occurs when the packer 20 is set. In this configuration, the primary 48 and secondary 52 foldback rings are deformed between the seal ring 32c (of the seal element 32) and lower gage 36. As shown in FIG. 3, in this state, the primary foldback ring 48 bends upwardly at edge 104 to contain the seal element 32. The secondary foldback ring 52 also bends (at edge 102) toward the lower gage 36 due to the contact of an outer upper shoulder 100 of the lower gage 36 with the secondary foldback ring 52. As shown in FIG. 3, in the absence of the second foldback ring 52, the shoulder 100 of the lower gage 36 is capable of introducing a significant stress riser to the primary foldback ring 48, which may degrade the pressure rating of the packer 20. However, the intervening secondary foldback ring 52 serves as a buffer to more evenly distribute the forces on the primary foldback ring 48, which are caused by the shoulder 100. Therefore, when the packer 20 is set, the shoulder 100 does not introduce a sharp edge on the primary foldback ring 48. As a result, the pressure rating of the packer 20 is maximized. Additionally, the secondary foldback ring 48 reduces the extrusion gap of the seal element 32 by effectively increasing the outer diameter of the lower gage 36.

The secondary foldback ring 50 (FIG. 1) performs functions similar to the functions performed by the secondary foldback ring 52.

Other embodiments are within the scope of the appended claims. For example, in accordance with some embodiments of the invention, multiple secondary foldback rings may be used between a gage and the seal element of a packer. FIG. 4 depicts a detailed section 120 of a packer that includes such features according to another embodiment of the invention. The detailed section 120 illustrates a section similar to the section 60 (see FIG. 1) of the packer 20. However, this packer includes multiple secondary foldback rings 52. Due to this arrangement, the seal extrusion gap is further reduced by the thickness of the additional secondary foldback ring 52, as depicted in FIG. 5.

Although FIGS. 4 and 5 depict two identical secondary foldback rings 52 between the gage and the sealing element, it is noted that the secondary foldback rings may have different profiles in accordance with other embodiments of the invention.

For example, FIG. 6 depicts a detailed section 150 of a packer according to another embodiment of the invention. Unlike the packer 20 or the packer in FIGS. 4 and 5, this packer includes the secondary foldback ring 52; and a secondary foldback ring 160, which has a different profile. As shown in FIG. 6, in accordance with some embodiments of the invention, the secondary foldback ring 160 may be located between the secondary foldback ring 52 and the gage 36.

The secondary foldback ring 160 has the same general two annular section design as the secondary foldback ring 52. In this regard, the secondary foldback ring 160 includes an inner annular section 160a, which is generally longitudinally flat and has an inner edge 160a that closely circumscribes the outer surface of the tubular member 24. However, an outer annular section 160b of the secondary foldback ring 160 is longitudinally inclined at a greater angle than the outer annular section 52b (see FIG. 2) of the secondary foldback ring 52. Due to this arrangement, the only portion of the secondary foldback ring 160 that touches the secondary foldback ring 52 (before the packer is set) is an outer edge 160c of the secondary foldback ring 160. This maximizes the moment force that is applied to the secondary foldback ring 160 when the packer is set.

Other embodiments are within the scope of the appended claims. For example, in accordance with other embodiments of the invention, the packer may have more than two secondary foldback rings between the seal element of the packer and each gage. As another example, in accordance with some embodiments of the invention, some of the secondary foldback rings may be identical and other of the secondary foldback rings may have different profiles (such as outer annular sections that have different longitudinal inclines, for example). Thus, many variations are possible and are within the scope of the appended claims.

Referring to FIG. 7, in accordance with some embodiments of the invention, the packer 20 (or any of the other packers that are described herein) may be used in a subterranean well 200. More specifically, the packer 20 may be part of a tubular string, such as a production tubing 220 that extends downhole from the surface of the well. As depicted in FIG. 7, the well may include a wellbore 240 that is lined by the casing 10, although the packer 20 may likewise be used in uncased wellbores in accordance with some embodiments of the invention. Additionally, although FIG. 7 depicts a vertical wellbore, the packer 20 may be used in lateral wellbores. Furthermore, in accordance with some embodiments of the invention, the packer 20 may be used in a subsea well. Thus, many variations are possible and are within the scope of the appended claims.

For the embodiment that is depicted in FIG. 7, the production tubing string 220 may include, for example, a circulation or sleeve valve 290 to receive a flow of fluid from a particular production zone 230. As an example, the production zone 230 may be formed by the firing of a perforating gun 280, which produces corresponding perforation tunnels 260 into a formation 250 of the zone 230. Thus, production fluid from the zone 230 may flow into a central passageway 222 of the production tubing 220 and through the central passageway of the tubular member 24 to the surface of the well.

Although terms of orientation and direction, such as “upper,” “lower,” etc. have been used in the description herein for purposes of convenience, it is noted that such orientations and directions described herein are not needed to practice the invention. Therefore, in accordance with other embodiments of the invention, the packers that are described herein may be used in other orientations. For example, in accordance with some embodiments of the invention, the gages may move laterally about a lateral tubular member for purposes of compressing a sealing element in between.

The packers that are described herein may be a variety of different packers, such as weight set and hydraulically set packers, as just a few examples.

While the present invention has been described with respect to a limited number of embodiments, those skilled in the art, having the benefit of this disclosure, will appreciate numerous modifications and variations therefrom. It is intended that the appended claims cover all such modifications and variations as fall within the true spirit and scope of this present invention.

Claims

1. A packer, comprising: a sealing element; a gage; and a plurality of foldback rings located between the gage and the sealing element.

2. The packer of claim 1, wherein the sealing element comprises at least one elastomer ring.

3. The packer of claim 1, wherein the gage is adapted to compress the sealing element in response to the packer being set.

4. The packer of claim 1, wherein the rings are adapted to control extrusion of the sealing element when the packer is set.

5. The packer of claim 1, wherein at least one of the foldback rings is adapted to conform to an edge of the sealing element before the packer is set.

6. The packer of claim 1, wherein at least one of the foldback rings is adapted to at least partially bend over a feature of the gage in response to the packer being set.

7. The packer of claim 1, wherein the foldback rings comprises metal rings.

8. The packer of claim 1, wherein each of the foldback rings comprise a section that forms an angle with a longitudinal axis of the packer between zero and ninety degrees, and at least two of the angles are different.

9. The packer of claim 8, wherein the angles of the sections of at least two of the foldback rings are oriented to cause only an outer edge of one of said two foldback rings to contact the other of said two foldback rings before the packer is set.

10. The packer of claim 8, wherein the foldback rings comprises at least three foldback rings, and each of the angles are different.

11. The packer of claim 8, wherein the angles become progressively larger with the distance between foldback ring and the gage.

12. The packer of claim 1, wherein the foldback rings comprise a primary foldback ring, and secondary foldback rings, each of the secondary foldback rings being substantially identical.

13. The packer of claim 1, further comprising: additional foldback rings located between another gage and the sealing element.

14. A system comprising: a tubular member to define an annulus in a well; and a packer adapted to seal off the annulus in response to being set, the packer comprising a sealing element, a gage and a plurality of foldback rings located between the gage and the sealing element.

15. The system of claim 14, wherein the tubular member comprises a production tubing string.

16. The system of claim 14, wherein the rings are adapted to control extrusion of the sealing element when the packer is set.

17. The system of claim 14, wherein the foldback rings comprise a primary foldback ring and secondary foldback rings, and the secondary foldback rings are substantially identical.

18. The system of claim 14, wherein the foldback rings comprise a primary foldback ring and secondary foldback rings, and the secondary foldback rings comprise outer edges that are located different radial distances away from a longitudinal axis of the packer.

19. A method usable with a well, comprising: compressing a sealing element between gages to form an annular seal in the well; and controlling extrusion of the sealing element in response to the moving of gages, the act of controlling comprising deforming a plurality of rings located between one of the gages and the sealing element.

20. The method of claim 19, wherein the act of deforming comprises: at least partially bending at least one of the rings over a feature of said one of the gages.

21. The method of claim 19, wherein the act of controlling comprises: deforming a primary ring and deforming secondary rings, each of the secondary rings being substantially identical and different from the primary ring.

22. The method of claim 19, wherein the act of controlling comprises: deforming a primary ring and deforming secondary rings, each of the secondary rings being different from each other and different form the primary ring.

23. The method of claim 19, wherein the act of controlling comprises: deforming a primary ring and a secondary ring, and using the secondary ring to limit deformation of the primary ring.

24. The method of claim 19, wherein the act of controlling further comprises: deforming a second plurality of rings located on an opposite side of the sealing element from the first plurality of rings.