EP1339944A1

EP1339944A1 - High temperature and pressure packer

Info

Publication number: EP1339944A1
Application number: EP01999728A
Authority: EP
Inventors: Patrick J. Zimmerman; Donald Greenlee; Michael G. Ritter
Original assignee: Weatherford Lamb Inc
Current assignee: Weatherford Lamb Inc
Priority date: 2000-12-08
Filing date: 2001-12-04
Publication date: 2003-09-03
Anticipated expiration: 2021-12-04
Also published as: US20020070503A1; CA2427017C; AU2002220885A1; EP1339944B1; DE60106294D1; CA2427017A1; WO2002046573A1; US20040036225A1

Abstract

A high temperature and high pressure packer (100) and method for sealing an annulus in a wellbore is provided. The packer can withstand temperatures up to 450°F (232°C) and differential pressures up to 15,000 psi (103 MPa). In one aspect, the packer comprises a body (102); and a sealing system disposed about the body including an element (500) having an anti-extrusion ring (360,660) at an end thereof, wherein the sealing system is compressible in length and expandable in outer diameter to seal the annulus. In another aspect, the method comprises running a packer into the wellbore, the packer comprising a body (102) and a sealing system comprising an element (500) and an anti-extrusion ring (360,660), wherein the element is disposed about the body proximate the anti-extrusion ring, and wherein an extrusion ring (380, 680) is disposed substantially on an inner diameter of the anti-extrusion ring; flowing the extrusion ring radially outward and axially across the body in a direction opposite the element to fill a portion of the annulus; and radially expanding the element to fill a remaining portion of the annulus.

Description

HIGH TEMPERATURE AND PRESSURE PACKER

The present invention relates to downhole packers. More particularly, the present invention relates to a high pressure and temperature element system for a downhole packer.

Downhole packers are typically used to seal an annular area formed between two co-axially disposed tubulars within a wellbore. For example, downhole packers may seal an annulus formed between production tubing disposed within wellbore casing. Alternatively, packers may seal an annulus between the outside of a tubular and an unlined borehole. Routine uses of packers include the protection of casing from pressure, both well and stimulation pressures, as well as the protection of the wellbore casing from corrosive fluids. Other common uses include the isolation of formations or leaks within a wellbore casing or multiple producing zones, thereby preventing the migration of fluid between zones. Packers may also be used to hold kill fluids or treating fluids within the casing annulus.

Conventional packers typically comprise a sealing element located between upper and lower retaining rings or elements. The sealing element is typically a synthetic rubber composite which can be compressed by the retaining rings to expand radially outward into contact with an inner surface of a well casing there-around. This compression and expansion of the sealing element seals the annular area by preventing the flow or passage of fluid across the expanded sealing element.

Conventional packers are typically run into a wellbore within a string of tubulars and anchored in the wellbore using mechanical compression setting tools or fluid pressure devices. Conventional packers are also typically installed using cement or other materials pumped into an inflatable sealing element.

One problem associated with conventional packers arises with high temperature and/or high pressure applications. High temperatures are generally defined as downhole temperatures above 300°F (149°C) and up to 450°F (232°C). High pressures are generally defined as downhole pressures above 7,500 psi (52 MPa) and up to 15,000 psi (103 MPa). At these temperatures and pressures, conventional sealing elements become ineffective. Most often, the physical properties of the sealing element suffer from degradation due to the extreme conditions. For example, the sealing element may experience a loss of elasticity. Alternatively, the sealing element may melt or otherwise decrease in viscosity and flow or extrude.

Another problem associated with conventional packers occurs during the activation of the conventional packer at high temperatures and pressures. Most often, the sealing element softens and possibly flows before the packer reaches its final destination in the wellbore. Consequently, the sealing element becomes disconfigured and cannot be properly activated. As a result, the sealing element does not adequately seal the annulus.

Therefore, there is a need for a downhole packer having an element system that can resist or prevent extrusion or degradation in high temperature and/or high pressure applications. There is also a need for a method for actuating a downhole packer that can withstand a high temperature and/or high pressure environment by staging the expansion of a sealing element and minimizing a void within an annulus to be sealed.

A downhole packer having an element system that can withstand high temperature and high pressure environments is provided. A method for actuating a downhole packer is also provided which can withstand high temperature and high pressure environments by staging the expansion of an element system and minimizing a void within an annulus to be sealed. The packer can withstand temperatures up to 450°F (232°C) and differential pressures up to 15,000 psi (103 MPa).

In accordance with a first aspect of the present invention there is provided a packer comprising a body and a sealing system disposed about the body including an element having an anti-extrusion ring at an end thereof, wherein the sealing system is compressible in length and expandable in outer diameter to seal the annulus. The packer preferably further comprises an extrusion ring disposed substantially on an inner diameter of the anti-extrusion ring such that flow of the extrusion ring in a direction opposite the element is inhibited by the anti-extrusion ring. Further preferred features are set out in claims 2 et seq.

In accordance with a second aspect of the invention there is provided a method of running a packer into the wellbore, the packer comprising a body and a sealing system comprising an element and an anti-extrusion ring, wherein the element is disposed about the body proximate the anti-extrusion ring, and wherein an extrusion ring is disposed substantially on an inner diameter of the anti-extrusion ring; flowing the extrusion ring radially outward and axially across the body in a direction opposite the element to fill a portion of the annulus; and radially expanding the element to fill a remaining portion of the annulus.

Some preferred embodiments of the invention will now be described by way of example only and with reference to the accompanying drawings, in which:

Figure 1 is a cross section of a packer;

Figure 1 A is an enlarged view of a retaining assembly disposed about a body of the packer shown in Figure 1 ;

Figure 2 is a partial cross section of the packer during a first stage of activation;

Figure 3 is a partial cross section of the packer during a second stage of activation;

Figure 4 is a partial cross section of the packer during a third stage of activation; and

Figure 4A is an enlarged view of the element system disposed about the body of the packer shown in Figure 4 during the third stage of activation.

Figure 1 is a cross section of a high temperature down hole packer 100. The packer 100 includes a body 102 having a first and second retaining system and an element system disposed there-around. The body 102 may include a longitudinal bore there through, and may include a sealed bore there-through. The retaining systems are disposed at either end of the element system and all are comprised of ring-shaped components concentrically disposed about the body 102. The element system comprises filler rings 320, 620, containment rings 340, 640, anti-extrusion rings 360, 660, back-up rings 380, 680, and an element 500. The first and second retaining system each comprise a slip 200, 400, a cone 220, 420, an expansion ring 260, 460, and a slide ring 300, 600. In operation, the retaining systems secure the packer 100 within a tubular therearound, such as casing for example, and provide the boundaries of an annular area for the element system to expand and seal, thereby providing an effective seal in high temperature and high pressure applications.

For ease and clarity of description, the packer 100 will be further described in more detail as if disposed within a tubular 700 in a vertical position as oriented in the Figures. It is to be understood, however, that the packer 100 may be disposed in any orientation, whether vertical or horizontal. It is also to be understood that the packer 100 may be disposed in a borehole without a tubular therearound. Additionally, for ease and clarity of description, the first retaining system and an upper portion of the element system will be described since the components of the second retaining system and a lower portion of the element system are substantially identical.

Considering the retaining system in greater detail, the slip 200 is disposed about the body 102 adjacent a first end 221 of the cone 220. Each slip 200 comprises a tapered inner surface 201 conforming to the first end 221 of the cone 220. An outer surface of the slip 200, preferably includes at least one outwardly extending serration or edged tooth 205, to engage an inner surface of the tubular 700 when the slip 200 is driven radially outward from the body 102 by the movement of the sloped surfaces of the cones thereunder.

The slip 200 is designed to fracture with radial stress as the cones are driven thereunder. The slip 200 typically includes at least one recessed groove (not shown) milled therein to fracture under stress allowing the slip 200 to expand outwards to engage the inner surface of the tubular 700. For example, the slip 200 may include four evenly sloped segments separated by equally spaced recessed grooves to contact the tubular 700 and become evenly distributed about the outer surface of the body 102.

The cone 220 is disposed about the body 102 adjacent the slip 200 and is secured to the body 102 by a plurality of shearable members like screws 106. As stated above, the cone 220 comprises a tapered first end '221 which rests underneath the tapered inner surface 201 of the slip 200. The slip 200 travels about the tapered first end 221 of the cone 220, thereby expanding radially outward from the body 102 to engage the inner surface of the tubular 700. Referring to Figure 1A, the cone 220 also comprises a second end 223 which is tapered and abuts a corresponding tapered end 261 of the expansion ring 260.

Referring to Figures 1 and 1 A, the expansion ring 260 is disposed between the cone 220 and the slide ring 300. In the preferred embodiment, the expansion ring 260 includes a male split ring 270 and a female split ring 280. The male and female split rings 260, 270, are disposed about the body 102 so that their respective expandable openings and are not vertically aligned. In this orientation, the male split ring 270 and female split ring 280 provide a solid circumferential barrier against extruded or expanded material of back-up ring 380. The male split ring 270, as depicted in section view, includes three sides. A first side 261 has a sloped surface corresponding to the sloped second end 223 of the cone 240 as described above. A second side is substantially flat or perpendicular to the body 102, with an extension 265 extending therefrom. The female split ring 280 also includes three sides, visible in section view, including a substantially flat or perpendicular first side having a recessed groove 285 disposed therein. The female split ring 280 also includes a second side having a tapered surface 283 to abut a first end of the slide ring 300. The extension 265 disposed on the second side of the male split ring 270 is disposable within the recessed groove 285. The extrusion 265 and recessed groove 285 allow the male and female split ring 270 to engage one another thereby allowing the expansion rings 260, 460, to move radially outward from the body 102 as a single unit 260.

The slide ring 300 includes a first end having a first 301 and second 303 tapered surface. The first tapered surface 301 corresponds to the second end 283 of the female split ring 280. The second tapered surface 303 is sloped in an opposite direction from the first tapered surface 301 and corresponds to the sloped second end 223 of the cone 240. The slide ring 300 also includes a second end abutting the filler ring 320 and having an extension or lip 307 disposed thereon. The lip extends axially away from the slide ring 300 toward the element 500 and extends between a portion of an inner surface of the filler ring 320, 620 and an outer surface of the body 102.

Considering the element system in greater detail, the filler ring 320 comprises two sections, a larger diameter section and a smaller diameter section which form a shoulder 325 at the interface of the two sections. The smaller diameter section of the filler ring 320 is disposed about the extension 307 of slide ring 300. The larger diameter section rests against the outer surface of the body 102. The filler ring 320 may be manufactured from, for example, Teflon® or any flexible plastic or resin material which flows at a predetermined temperature. As will be explained below, the filler ring 320 will expand under high temperature and/or pressure and create a collapse load on the extension 307 of the slide ring 300. This collapse load holds the slide ring 300 firmly against the body 102.

A spacer ring 310 is disposed about the body 102 between the slide ring 300 and the filler ring 320. The spacer ring 310 serves to accommodate tolerance variations created during the manufacturing of the element system.

The back-up ring 380 is disposed about the body 102 between the element 500 and the filler ring 320. The back-up ring 380 includes a recessed groove 385 formed in a portion of an outer surface thereof. Similar to the filler ring 380 the back-up ring 380 may be manufactured from, for example, Teflon® or any flexible plastic or resin material which flows at a predetermined temperature. At high temperatures, the backup ring 380 expands radially outward from the body 102 and flows across the outer surface of the body 102. As will be explained below, the back-up ring 380 helps to fill a void 550 created between the expansion rings 260, 460, thereby reducing a volume of the void 550 to be filled by the element 500. The anti-extrusion ring 360 is disposed in a portion of the groove 385 and extends over the second portion of the filler ring 320. The anti-extrusion ring 360 includes a lip 365 which extends radially inward toward the body 102. The lip 365 is disposed adjacent the shoulder 325 formed between the larger diameter and the smaller diameter sections of the filler ring 320. As will be explained below, the lip 365 prevents the filler ring 320 from flowing or travelling between the anti-extrusion ring 360 and the container ring 340. The lip or extrusion 365 also acts as a carrier when the back-up ring 380 expands and travels over the slide ring 300.

The containment ring 340 is disposed about an outer surface of the smaller diameter section of the filler ring 320, 620. The containment ring 340 include a first end which abuts the spacer ring 310 and a second end which abuts the anti-extrusion ring 360. As will be explained below, the containment ring 340 holds the filler ring 320 in place and prevents the filler ring 320 from extruding across an outer surface of the slide ring 300.

The element 500 is disposed about the body 102 between the back-up rings 380, 680. The element 500 may have any number of configurations to effectively seal the annulus created between the body 102 and the casing wall. For example, the element 500 may include grooves, ridges, indentations, or extrusions designed to allow the element 500 to conform to variations in the shape of the interior of the tubular 700 there-around. The element 500 can be constructed of any expandable or otherwise malleable material which creates a permanent set position and stabilizes the body 102 relative to the wellbore casing. For example, the element 500 may be a metal, a plastic, an elastomer, or a combination thereof. The element 500, however, must withstand temperatures in excess of 450°F (232°C), and pressures in excess of 15,000 psi (103 MPa).

Referring to Figure 4, the packer 100 further includes a ratchet assembly 800 disposed about a first end of the packer 100 to prevent the components described above from prematurely releasing once the components have been actuated. The ratchet assembly 800 includes a ring housing 810 disposed about a lock ring 830 and is disposed about the body 102 adjacent to and abutting a first end of the slip 200. The lock ring 830 is a cylindrical member annularly disposed between the body 102 and the ring housing 810 and includes an inner surface having profiles disposed thereon to mate with profiles formed on the outer surface of the body 102. The profiles formed on the lock ring 830 have a tapered leading edge allowing the lock ring 830 to move across the mating profiles formed on the body 102 in one axial direction while preventing movement in the other direction. The profiles formed on both the outer surface of the body 102 and an inner surface of the lock ring 830 consist of formations having one side which is sloped and one side which is perpendicular to the outer surface of the body 102. The sloped surfaces of the mating profiles allows the lock ring 830 to move across the body 102 in a single axial direction. The perpendicular sides of the mating profiles prevent movement in the opposite axial direction. Therefore, the split ring may move or "ratchet" in one axial direction, but not the opposite axial direction.

The ring housing 810 comprises a jagged inner surface to engage a mating jagged outer surface of the lock ring 830. The relationship between the jagged surfaces creates a gap there-between allowing the lock ring 830 to expand radially as the profiles formed thereon move across the mating profiles formed on the body 102. A longitudinal cut within the lock ring 830 allows the lock ring 830 to expand radially and contract as it movably slides or ratchets in relation to the outer surface of the body 102. The ring housing 810 also comprises a first end which abuts a first end of the cone 200 thereby transferring movement of the ratchet assembly 800 to the cone 200.

To set or activate the packer 100, the packer 100 is first run down the hole to a predetermined depth. A setting tool applies an axial load to the outer components of the packer 100 relative to the body 102. Once the axial force reaches a predetermined value, which exceeds the shear strength of the pins 106 the pins 106 release or shear, thereby causing the outer components to move axially across the body 102.

Figure 2 is a section view of a packer 100 during a first stage of activation.

During a first stage of activation, axial movement of the outer components forces the cone 420 underneath the slip 400, thereby forcing the slip 400 radially outward toward the tubular 700. As shown in Figures 2 and 4A, the slip 400 engages the inner surface of the tubular 700 creating an opposing axial force which causes the expansion rings 260, 460, to slide radially outward across the first surface 223 of the cones 240, 440 and across the first tapered surface 301 of the slide rings 300, 600, thereby engaging the inner surface of the tubular 700. The actuation of the expansion rings 260, 460, provides a fixed volume or void space 550 within the annulus to be sealed off by the element 500 and back-up rings 380, 680 and also provides an extrusion barrier on the face of the cones 220, 420, and the inner surface of the tubular 700.

The axial forces next cause the recessed grooves of the slip 400 to fracture, and divide into equal segments, permitting the serrations or teeth 405 to engage the inner surface of the tubular 700. Once the slip 400 fractures, the axial forces across the body

102 are met by an equal and opposite axial force which causes the malleable outer portions of the packer 100 to compress and expand radially outward.

Figure 3 shows a second stage of activation which involves extruding the backup rings 380, 680. As shown, the compressive forces exerted against opposite sides of the back-up rings 380, 680 cause the back-up rings 380, 680, to expand radially outward toward the tubular 700. Expansion of the back-up rings 380, 680, causes the anti- extrusion ring 380, 680 to expand due to the applied hoop stress created by the expanding back-up rings 380, 680. As the anti-extrusion rings 380, 680, yield, the back-up rings 380, 680, are allowed to travel or flow up and over the filler rings 320, 620, the container rings 340, 640, and the slide rings 300, 600, as shown in Figure 4. The increasing pressure exerted by the back-up rings 380, 680, and the element 500 applies a load to the filler ring 320, 620, that applies a collapse load on the extension 307 of the slide ring 300, 600, thereby eliminating any extrusion between the slide ring 300, 600, and the body 102. The lip 365 formed on the first end of the anti-extrusion ring 360, 660, prevents the filler rings 320, 620, from flowing or travelling between the anti-extrusion ring 360, 660, and the container ring 340, 640. The lip 365 also acts as a carrier when the back-up ring 380, 680, expands and travels over the slide ring 300, 600. The anti-extrusion rings 380, 680, also serve to retain the back-up rings 380, 680, until the expansion rings 260, 460, are fully expanded against the tubular 700. Figure 4 shows a third stage of activation. During a third stage of activation, the anti-extrusion rings 380, 680 flow and fill a substantial portion of the void 550 created by the expansion rings 260, 460, while the element 500 is expanded radially outward toward the tubular 700 to seal off the remaining portion of the void 550. Because the anti-extrusion rings 380, 680, occupy a significant portion of the void 550, the element 500 must only expand radially outward, not axially, to fill the remaining void 550. As a result, less stress is placed on the element 500, and the element 500 is less subject to degradation providing a more effective seal for a longer period of time.

During the final stages of activation, the axial forces cause the ratchet assembly

800 to move or ratchet down the outer surface 102 of the body 300. As described herein, the ratcheting is accomplished when the axial forces against the lock ring 830 cause the profiles formed on the ring 830 to ramp up and over the mating profiles formed on the outer surface of the body 102. Once the profiles of the ring 830 travel up and over the adjoining profiles of the body 102, the first lock ring 830 contracts or snaps back into place, re-setting or interlocking the concentric profiles of the lock ring 830 against the next adjoining profiles formed on the outer surface of the body 102. In this manner, the ratchet assembly 800 moves in a first direction and not in a second, opposite direction.

In addition to a downhole packer as described above, the element system and the retaining system described herein may be used in conjunction with any other downhole tool used for sealing an annulus within a wellbore, such as a bridge plug, for example.

It will be appreciated that variations from the above described embodiments may still fall within the scope of the invention.

Claims

CLAIMS:

1. A packer for sealing an annulus in a wellbore, comprising: a body; and a sealing system disposed about the body including an element having an anti- extrusion ring at an end thereof, wherein the sealing system is compressible in length and expandable in outer diameter to seal the annulus.

2. A packer as claimed in claim 1, further comprising an extrusion ring disposed substantially on an inner diameter of the anti-extrasion ring such that flow of the extrusion ring in a direction opposite the element is inhibited by the anti-extrusion ring.

3. A packer as claimed in claim 2, wherein the anti-extrusion ring is movable in the direction opposite the element.

4. A packer as claimed in claim 2 or 3, wherein the anti-extrusion ring comprises a lip or extrusion disposed thereon to act as a carrier when the extrusion ring flows across the body.

5. A packer as claimed in claim 2, 3 or 4, wherein the extrusion ring comprises a filler ring and a back-up ring.

6. A packer as claimed in claim 5, wherein the back-up ring is disposed about the body adjacent the element and the filler ring is disposed about the body adjacent the back-up ring.

7. A packer as claimed in claim 6, wherein the back-up ring is expandable radially outward from the body and axially across the body to fill a portion of a void formed within the annulus.

8. A packer as claimed in claim 7, wherein the anti-extrusion ring is movable in conjunction with the back-up ring.

9. A packer as claimed in claim 7 or 8, wherein the element is expandable radially outward from the body to fill a remaining portion of the void formed within the annulus.

10. A packer as claimed in claim 6, wherein a containment ring is disposed substantially on an outer diameter of the filler ring such that flow of the filler ring across the body is inhibited by the containment ring.

11. A packer as claimed in any preceding claim, wherein the sealing system is disposed about the body between a first and second expansion ring.

12. A packer for sealing an annulus in a wellbore, comprising: a body; a retaining system comprising an expansion ring disposed about the body; and a sealing system comprising an element and an anti-extrusion ring, wherein the element is disposed about the body proximate the anti-extrusion ring, and wherein an extrusion ring is disposed substantially on an inner diameter of the anti-extrusion ring such that flow of the extrusion ring in a direction opposite the element is inhibited by the anti-extrusion ring.

13. A packer as claimed in claim 12, wherein the anti-extrusion ring is moveable in the direction opposite the element.

14. A packer as claimed in claim 12 or 13, wherein the anti-extrusion ring comprises a lip or extrusion disposed thereon to act as a carrier when the extrusion ring flows across the body.

15. A packer as claimed in claim 12, 13 or 14, wherein the retaining system comprises a first and second expansion ring arranged so that actuation of the first and second expansion ring forms a void within the annulus.

16. A packer as claimed in claim 15, wherein the extrusion ring is expandable radially outward from the body and axially across the body to fill a portion of the void, and wherein the anti-extrasion ring is movable in conjunction with the extrusion ring.

17. A packer as claimed in claim 16, wherein the element expands radially outward from the body to fill a remaining portion of the void.

18. A packer as claimed in any preceding claim, wherein the sealing system comprises a first and second anti-extrasion ring disposed on each end of the element and wherein the first and second anti-extrasion rings are disposed substantially on an outer diameter of a first and second extrusion ring.

19. A method for sealing an annulus in a wellbore, comprising: running a packer into the wellbore, the packer comprising a body and a sealing system comprising an element and an anti-extrasion ring, the element being disposed about the body proximate the anti-extrasion ring, an extrusion ring being disposed substantially on an inner diameter of the anti-extrasion ring; flowing the extrusion ring radially outward and axially across the body in a direction opposite the element to fill a portion of the annulus; and radially expanding the element to fill a remaining portion of the annulus.

20. The method of claim 19, wherein flowing the extrusion ring radially outward and axially across the body is inhibited by the anti-extrasion ring.

21. A packer for sealing an annulus in a wellbore, comprising: a body; and a sealing system disposed about the body including an element having an extrasion ring at each end thereof, wherein the sealing system is compressible in length and expandable in outer diameter to seal the annulus.