CA2816008A1 - Packer with integral centralizer - Google Patents
Packer with integral centralizer Download PDFInfo
- Publication number
- CA2816008A1 CA2816008A1 CA2816008A CA2816008A CA2816008A1 CA 2816008 A1 CA2816008 A1 CA 2816008A1 CA 2816008 A CA2816008 A CA 2816008A CA 2816008 A CA2816008 A CA 2816008A CA 2816008 A1 CA2816008 A1 CA 2816008A1
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- CA
- Canada
- Prior art keywords
- packer
- mandrel
- packing element
- centralizer
- carried
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
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- 238000012856 packing Methods 0.000 claims abstract description 41
- 238000004891 communication Methods 0.000 claims abstract description 5
- 238000001125 extrusion Methods 0.000 claims description 6
- 238000000926 separation method Methods 0.000 claims description 6
- 239000012530 fluid Substances 0.000 claims description 5
- 239000011248 coating agent Substances 0.000 claims description 3
- 238000000576 coating method Methods 0.000 claims description 3
- 238000005553 drilling Methods 0.000 description 4
- 238000005452 bending Methods 0.000 description 2
- 230000001939 inductive effect Effects 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 239000011324 bead Substances 0.000 description 1
- 239000003638 chemical reducing agent Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000002028 premature Effects 0.000 description 1
- 238000003825 pressing Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
Landscapes
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Earth Drilling (AREA)
Abstract
A packer for use in a wellbore including a mandrel having an uphole end and an opposed downhole end, a bore defined within the mandrel and extending between the uphole end and the downhole end, an expandable packing element carried about the mandrel, an actuator in operative communication with the packing element for expanding the packing element to isolate a portion of the wellbore, and a centralizer carried about the mandrel proximate the packing element.
Description
PACKER WITH INTEGRAL CENTRALIZER
FIELD
The present disclosure relates generally to tools for use in a wellbore. More particularly, the present disclosure relates to packers.
BACKGROUND
Open hole packers are used for open hole wellbore isolation purposes in multi-stage fracturing completion systems. Aggressive vertical-to-lateral wellbore build sections or drilling undulations, may be prevalent in an open-hole section of a wellbore.
If the equipment (e.g. frac sleeves, packers, etc.) that make up a multi-stage fracturing completion system is long and rigid, greater friction may be created between the equipment and the intermediate casing or open hole wellbore sections. This may result in liner conveyance problems resulting in the inability to reach a target depth. In many instances, centralizers, being steel or composite material, are run just below an open hole packer to protect and centralize the packer, particularly the packer's elastomeric pack-off element, from contacting (or "skidding") along the wellbore and being damaged. In some situations, "beads"
and other friction reducers are included in drilling/completion fluids to reduce the amount of friction that is created through the build and horizontal sections of the wellbore when conveying multi-stage fracturing liners to depth. If difficulties are encountered while conveying multi-stage fracturing systems to depth, greater compressive force may have to be applied to the liner and its associated equipment to get it past frictional "tight" spots in the wellbore. This may result in additional stress and damage to surface equipment and the liner.
If the multi-stage fracturing systems cannot be installed to target depth, the customer may have to eliminate fracturing intervals between the open hole packers, compromising the fracturing operation. This results in lost production potential and lost revenue for the customer.
Existing hydraulic-set open hole packers with a centralizer below the packer may not effectively centralize the packer's pack-off element, potentially compromising the radial elastomeric seal to the open hole. The centralizer may for example be located a moderate distance (2 feet - 6 feet) away from the packer's pack-off element. This distance allows the packer to tilt in the open hole section, de-centralizing the pack-off element.
When the open hole packer is set hydraulically, the packer is forced to try and re-orient and centralize itself in the open hole section to create a proper seal with the open hole wall.
However, this centralizing action may require a large degree of mechanical force to lift the open hole packer and associated liner length up from the low side of the open hole. As well, if the open hole packer is situated on the high side of the open hole, bending the liner down to centralize the packer in the open hole wellbore may also require a large degree of force. In both these situations, the hydraulic force generated in the packer's hydraulic setting chamber, that was originally dedicated to expand the pack-off element to form the radial seal with the open hole face, is re-directed to lift/bend the liner. Depending on the differential pressure applied to the packer's hydraulic setting chamber, a decrease in the amount of radial pack-off force that is directly transferred to the elastomeric packer element can be reduced which can lead to seal integrity issues during fracturing operations.
SUMMARY
Previous open hole packers with a centralizer located below the packer result in a greater overall length and rigidity of the packer and contribute to the aforementioned friction inducing problems when tripping the liner to depth. It is, therefore, desirable to provide a packer in combination with a centralizer wherein the overall length and rigidity of the packer is such that contribution to friction-inducing problems during tripping are mitigated.
Generally, the present disclosure provides a packer in combination with a centralizer.
It is an object of the present disclosure to obviate or mitigate at least one disadvantage of previous packers.
In a first aspect, the present disclosure provides a packer for use in a wellbore including a mandrel having an uphole end and an opposed downhole end, a bore defined within the mandrel and extending between the uphole end and the downhole end, an
FIELD
The present disclosure relates generally to tools for use in a wellbore. More particularly, the present disclosure relates to packers.
BACKGROUND
Open hole packers are used for open hole wellbore isolation purposes in multi-stage fracturing completion systems. Aggressive vertical-to-lateral wellbore build sections or drilling undulations, may be prevalent in an open-hole section of a wellbore.
If the equipment (e.g. frac sleeves, packers, etc.) that make up a multi-stage fracturing completion system is long and rigid, greater friction may be created between the equipment and the intermediate casing or open hole wellbore sections. This may result in liner conveyance problems resulting in the inability to reach a target depth. In many instances, centralizers, being steel or composite material, are run just below an open hole packer to protect and centralize the packer, particularly the packer's elastomeric pack-off element, from contacting (or "skidding") along the wellbore and being damaged. In some situations, "beads"
and other friction reducers are included in drilling/completion fluids to reduce the amount of friction that is created through the build and horizontal sections of the wellbore when conveying multi-stage fracturing liners to depth. If difficulties are encountered while conveying multi-stage fracturing systems to depth, greater compressive force may have to be applied to the liner and its associated equipment to get it past frictional "tight" spots in the wellbore. This may result in additional stress and damage to surface equipment and the liner.
If the multi-stage fracturing systems cannot be installed to target depth, the customer may have to eliminate fracturing intervals between the open hole packers, compromising the fracturing operation. This results in lost production potential and lost revenue for the customer.
Existing hydraulic-set open hole packers with a centralizer below the packer may not effectively centralize the packer's pack-off element, potentially compromising the radial elastomeric seal to the open hole. The centralizer may for example be located a moderate distance (2 feet - 6 feet) away from the packer's pack-off element. This distance allows the packer to tilt in the open hole section, de-centralizing the pack-off element.
When the open hole packer is set hydraulically, the packer is forced to try and re-orient and centralize itself in the open hole section to create a proper seal with the open hole wall.
However, this centralizing action may require a large degree of mechanical force to lift the open hole packer and associated liner length up from the low side of the open hole. As well, if the open hole packer is situated on the high side of the open hole, bending the liner down to centralize the packer in the open hole wellbore may also require a large degree of force. In both these situations, the hydraulic force generated in the packer's hydraulic setting chamber, that was originally dedicated to expand the pack-off element to form the radial seal with the open hole face, is re-directed to lift/bend the liner. Depending on the differential pressure applied to the packer's hydraulic setting chamber, a decrease in the amount of radial pack-off force that is directly transferred to the elastomeric packer element can be reduced which can lead to seal integrity issues during fracturing operations.
SUMMARY
Previous open hole packers with a centralizer located below the packer result in a greater overall length and rigidity of the packer and contribute to the aforementioned friction inducing problems when tripping the liner to depth. It is, therefore, desirable to provide a packer in combination with a centralizer wherein the overall length and rigidity of the packer is such that contribution to friction-inducing problems during tripping are mitigated.
Generally, the present disclosure provides a packer in combination with a centralizer.
It is an object of the present disclosure to obviate or mitigate at least one disadvantage of previous packers.
In a first aspect, the present disclosure provides a packer for use in a wellbore including a mandrel having an uphole end and an opposed downhole end, a bore defined within the mandrel and extending between the uphole end and the downhole end, an
2 expandable packing element carried about the mandrel, an actuator in operative communication with the packing element for expanding the packing element to isolate a portion of the wellbore, and a centralizer carried about the mandrel proximate the packing element.
In an embodiment, the packer may be adapted for use in an open hole wellbore.
In an embodiment, the packer may be adapted for use in a cased hole wellbore.
In an embodiment, the centralizer is carried about the mandrel with a separation of substantially 6 inches from the packing element. In an embodiment, the centralizer is carried about the mandrel with a separation of substantially 4 inches from the packing element. In an embodiment, the centralizer is carried about the mandrel with a separation of substantially 2 inches from the packing element.
In an embodiment, the centralizer is carried about the mandrel intermediate the packing element and the downhole end.
In an embodiment, the centralizer is rotatably carried about the mandrel. In an embodiment, the centralizer is hardened for durability. In an embodiment, a friction-reducing coating is applied to the centralizer.
In an embodiment, the actuator comprises a sleeve carried about the mandrel for advancing along the mandrel against the packing element in a first direction to expand the packing element. In an embodiment, the packer further includes a cavity between the sleeve and the mandrel, the cavity in fluid communication with the bore for causing the sleeve to advance along the mandrel in response to increased fluid pressure in the bore.
In an embodiment, the packer further includes a ratchet ring located between the sleeve and the mandrel for preventing the sleeve from advancing along the mandrel in a second direction opposed to the first direction. In an embodiment, the first direction is towards the downhole end.
In an embodiment, the packer further includes an anti-extrusion backup ring system carried about the mandrel intermediate the sleeve and the packing element.
In an embodiment, the packer may be adapted for use in an open hole wellbore.
In an embodiment, the packer may be adapted for use in a cased hole wellbore.
In an embodiment, the centralizer is carried about the mandrel with a separation of substantially 6 inches from the packing element. In an embodiment, the centralizer is carried about the mandrel with a separation of substantially 4 inches from the packing element. In an embodiment, the centralizer is carried about the mandrel with a separation of substantially 2 inches from the packing element.
In an embodiment, the centralizer is carried about the mandrel intermediate the packing element and the downhole end.
In an embodiment, the centralizer is rotatably carried about the mandrel. In an embodiment, the centralizer is hardened for durability. In an embodiment, a friction-reducing coating is applied to the centralizer.
In an embodiment, the actuator comprises a sleeve carried about the mandrel for advancing along the mandrel against the packing element in a first direction to expand the packing element. In an embodiment, the packer further includes a cavity between the sleeve and the mandrel, the cavity in fluid communication with the bore for causing the sleeve to advance along the mandrel in response to increased fluid pressure in the bore.
In an embodiment, the packer further includes a ratchet ring located between the sleeve and the mandrel for preventing the sleeve from advancing along the mandrel in a second direction opposed to the first direction. In an embodiment, the first direction is towards the downhole end.
In an embodiment, the packer further includes an anti-extrusion backup ring system carried about the mandrel intermediate the sleeve and the packing element.
3 In an embodiment, the packer further includes an anti-extrusion backup ring system carried about the mandrel intermediate the sleeve and the downhole end.
Other aspects and features of the present disclosure will become apparent to those ordinarily skilled in the art upon review of the following description of specific embodiments in conjunction with the accompanying figures.
BRIEF DESCRIPTION OF THE DRAWINGS
Embodiments of the present disclosure will now be described, by way of example only, with reference to the attached Figures.
Fig. 1 is a cross-section elevation view of a packer of the present disclosure in a run position;
Fig. 2 is a cross-section elevation view of the packer of Fig. 1 in a set position; and Fig. 3 is an example of a multi-stage fracturing system utilizing packers of the present disclosure.
DETAILED DESCRIPTION
Referring to Figs. 1 and 2, a packer 100 (e.g. an open hole packer) includes a packing element (14) mounted on a mandrel (1) with a centralizer (9) close to the packing element, providing the packer 100 with a shorter overall length when the relative outside diameters of the packing element (14) and the centralizer (9) are taken into consideration.
The shorter length results in a shorter overall packer to centralizer assembly which permits easier equipment movement in wellbores that have aggressive vertical to lateral wellbore build sections and/or drilling undulations. The shorter completion equipment (open hole packers) do not have to bend as much as longer pieces of equipment as they travel through casing build sections or open hole drilling undulations, reducing the friction between the outside diameter of the completion equipment and the inside diameter of the casing or open hole sections. This, in turn, reduces the force required to convey the multi-stage
Other aspects and features of the present disclosure will become apparent to those ordinarily skilled in the art upon review of the following description of specific embodiments in conjunction with the accompanying figures.
BRIEF DESCRIPTION OF THE DRAWINGS
Embodiments of the present disclosure will now be described, by way of example only, with reference to the attached Figures.
Fig. 1 is a cross-section elevation view of a packer of the present disclosure in a run position;
Fig. 2 is a cross-section elevation view of the packer of Fig. 1 in a set position; and Fig. 3 is an example of a multi-stage fracturing system utilizing packers of the present disclosure.
DETAILED DESCRIPTION
Referring to Figs. 1 and 2, a packer 100 (e.g. an open hole packer) includes a packing element (14) mounted on a mandrel (1) with a centralizer (9) close to the packing element, providing the packer 100 with a shorter overall length when the relative outside diameters of the packing element (14) and the centralizer (9) are taken into consideration.
The shorter length results in a shorter overall packer to centralizer assembly which permits easier equipment movement in wellbores that have aggressive vertical to lateral wellbore build sections and/or drilling undulations. The shorter completion equipment (open hole packers) do not have to bend as much as longer pieces of equipment as they travel through casing build sections or open hole drilling undulations, reducing the friction between the outside diameter of the completion equipment and the inside diameter of the casing or open hole sections. This, in turn, reduces the force required to convey the multi-stage
4 fracturing completion systems to target depth and improves the chances of reaching target depth.
Locating the centralizer (9) and the packing element (14) within inches also results in the packing element (14) is more reliably centralized (the offset between the packing element OD and open hole ID is reduced) in the wellbore prior to packer hydraulic setting operations.
This results in more hydraulic energy being dedicated to radially packing off the element than being lost to lifting/bending the liner to obtain a centralized packer position within the wellbore. This, in turn, results in a more reliable pack-off elastomeric seal against the open hole wall during hydraulic fracturing operations.
The centralizer (9) is an integral part of the packer (100), located approximately 2 inches away from the packing element (14) and not located on a pup joint several feet below the packer (100). The centralizer (9) is free to rotate, hardened for durability, yet contains a friction reducing coating when sliding into the cased hole or open hole wellbore sections.
Referring to Fig. 1, in an embodiment disclosed, the packer (100) may be hydraulically actuated. A cylinder (3) is operable though port (110) to move relative to the mandrel (1) to set the packing element (14). A shear screw (13) holds the cylinder (3) in place relative to the mandrel (1) to avoid premature actuation. An o-ring (17) with a backup ring (20) and an o-ring (16) with backup ring (19) provide a seal between the mandrel (1) and the sleeve (3).
As shown, the centralizer (9) and the packing element (14) are proximate. A
retaining ring (10) held in place with a set screw (11) may be used to retain the centralizer (9) on a bottom sub (8).
Referring to Fig. 2, the packer (100) is shown in the set position. The open hole packer operates by applying pressure into the inner bore of the packer (100) to the port (110) to provide a force to overcome the shear value of the shear screws (13). Once the shear screws (13) shear, the cylinder (3) moves down along with a cylinder cap (2) and a ratchet ring (4) to apply a compressive force to the packing element (14) and associated anti-extrusion backup ring system (items 5, 6, 7). Sufficient pressure is applied to expand the packing element (14) to contact the wall of the wellbore (in an open hole configuration) or the inner diameter of the casing (in a cased hole configuration) and create a seal. As the packing element (14) expands, the anti-extrusion backup ring system expands as well to provide support and integrity to the ends of the packing element (14) when pressure is applied above or below the expanded packing element (14) to prevent bleed-off. The ratchet ring (4) engages ratchet (120) along the mandrel (1) to hold the packer (100) in the set position.
Referring to Fig. 3, a multi-stage fracturing system (125) may utilize packers of the present disclosure. A bottom hole assembly (130) includes several packers (100), ball actuated frac sleeves (140), a pressure actuated frac sleeve (150), and a liner closing valve (155). A liner top packer (160) provides a seal between the bottom hole assembly (130) and casing (170). The bottom hole assembly (130) with packers (100) having integral centralizer (9)(see Fig. 1 and 2) is placed in the wellbore (180) though the build section (190) and landed in the horizontal section (200). The packers (100) may be set by pressuring up the bottom hole assembly (130). The ball actuated frac sleeves (140) may be activated by one or more corresponding frac balls (210) provided at the appropriate time and in the appropriate sequence. This, of course, is only an example.
In an embodiment disclosed, the packer (100) having the centralizer (9) may be used in casing for cased hole applications.
Examples Only In the preceding description, for purposes of explanation, numerous details are set forth in order to provide a thorough understanding of the embodiments.
However, it will be apparent to one skilled in the art that these specific details are not required.
The above-described embodiments are intended to be examples only. Alterations, modifications and variations can be effected to the particular embodiments by those of skill in the art without departing from the scope, which is defined solely by the claims appended hereto.
Locating the centralizer (9) and the packing element (14) within inches also results in the packing element (14) is more reliably centralized (the offset between the packing element OD and open hole ID is reduced) in the wellbore prior to packer hydraulic setting operations.
This results in more hydraulic energy being dedicated to radially packing off the element than being lost to lifting/bending the liner to obtain a centralized packer position within the wellbore. This, in turn, results in a more reliable pack-off elastomeric seal against the open hole wall during hydraulic fracturing operations.
The centralizer (9) is an integral part of the packer (100), located approximately 2 inches away from the packing element (14) and not located on a pup joint several feet below the packer (100). The centralizer (9) is free to rotate, hardened for durability, yet contains a friction reducing coating when sliding into the cased hole or open hole wellbore sections.
Referring to Fig. 1, in an embodiment disclosed, the packer (100) may be hydraulically actuated. A cylinder (3) is operable though port (110) to move relative to the mandrel (1) to set the packing element (14). A shear screw (13) holds the cylinder (3) in place relative to the mandrel (1) to avoid premature actuation. An o-ring (17) with a backup ring (20) and an o-ring (16) with backup ring (19) provide a seal between the mandrel (1) and the sleeve (3).
As shown, the centralizer (9) and the packing element (14) are proximate. A
retaining ring (10) held in place with a set screw (11) may be used to retain the centralizer (9) on a bottom sub (8).
Referring to Fig. 2, the packer (100) is shown in the set position. The open hole packer operates by applying pressure into the inner bore of the packer (100) to the port (110) to provide a force to overcome the shear value of the shear screws (13). Once the shear screws (13) shear, the cylinder (3) moves down along with a cylinder cap (2) and a ratchet ring (4) to apply a compressive force to the packing element (14) and associated anti-extrusion backup ring system (items 5, 6, 7). Sufficient pressure is applied to expand the packing element (14) to contact the wall of the wellbore (in an open hole configuration) or the inner diameter of the casing (in a cased hole configuration) and create a seal. As the packing element (14) expands, the anti-extrusion backup ring system expands as well to provide support and integrity to the ends of the packing element (14) when pressure is applied above or below the expanded packing element (14) to prevent bleed-off. The ratchet ring (4) engages ratchet (120) along the mandrel (1) to hold the packer (100) in the set position.
Referring to Fig. 3, a multi-stage fracturing system (125) may utilize packers of the present disclosure. A bottom hole assembly (130) includes several packers (100), ball actuated frac sleeves (140), a pressure actuated frac sleeve (150), and a liner closing valve (155). A liner top packer (160) provides a seal between the bottom hole assembly (130) and casing (170). The bottom hole assembly (130) with packers (100) having integral centralizer (9)(see Fig. 1 and 2) is placed in the wellbore (180) though the build section (190) and landed in the horizontal section (200). The packers (100) may be set by pressuring up the bottom hole assembly (130). The ball actuated frac sleeves (140) may be activated by one or more corresponding frac balls (210) provided at the appropriate time and in the appropriate sequence. This, of course, is only an example.
In an embodiment disclosed, the packer (100) having the centralizer (9) may be used in casing for cased hole applications.
Examples Only In the preceding description, for purposes of explanation, numerous details are set forth in order to provide a thorough understanding of the embodiments.
However, it will be apparent to one skilled in the art that these specific details are not required.
The above-described embodiments are intended to be examples only. Alterations, modifications and variations can be effected to the particular embodiments by those of skill in the art without departing from the scope, which is defined solely by the claims appended hereto.
Claims (16)
1. A packer for use in a wellbore comprising:
a mandrel having an uphole end and an opposed downhole end;
a bore defined within the mandrel and extending between the uphole end and the downhole end;
an expandable packing element carried about the mandrel;
an actuator in operative communication with the packing element for expanding the packing element to isolate a portion of the wellbore; and a centralizer carried about the mandrel proximate the packing element.
a mandrel having an uphole end and an opposed downhole end;
a bore defined within the mandrel and extending between the uphole end and the downhole end;
an expandable packing element carried about the mandrel;
an actuator in operative communication with the packing element for expanding the packing element to isolate a portion of the wellbore; and a centralizer carried about the mandrel proximate the packing element.
2. The packer of claim 1, adapted for use in an open hole wellbore.
3. The packer of claim 1, adapted for use in a cased hole wellbore.
4. The packer of claim 1 wherein the centralizer is carried about the mandrel with a separation of substantially 6 inches from the packing element.
5. The packer of claim 4 wherein the centralizer is carried about the mandrel with a separation of substantially 4 inches from the packing element.
6. The packer of claim 5 wherein the centralizer is carried about the mandrel with a separation of substantially 2 inches from the packing element.
7. The packer of claim 1 wherein the centralizer is carried about the mandrel intermediate the packing element and the downhole end.
8. The packer of claim 1 wherein the centralizer is rotatably carried about the mandrel.
9. The packer of claim 1 wherein the centralizer is hardened for durability.
10. The packer of claim 1 further comprising a friction-reducing coating applied to the centralizer.
11. The packer of claim 1 wherein the actuator comprises a sleeve carried about the mandrel for advancing along the mandrel against the packing element in a first direction to expand the packing element.
12. The packer of claim 11 further comprising a cavity between the sleeve and the mandrel, the cavity in fluid communication with the bore for causing the sleeve to advance along the mandrel in response to increased fluid pressure in the bore.
13. The packer of claim 11 further comprising a ratchet ring located between the sleeve and the mandrel for preventing the sleeve from advancing along the mandrel in a second direction opposed to the first direction.
14. The packer of claim 11 further comprising an anti-extrusion backup ring system carried about the mandrel intermediate the sleeve and the packing element.
15. The packer of claim 11 wherein the first direction is towards the downhole end.
16. The packer of claim 11 further comprising an anti-extrusion backup ring system carried about the mandrel intermediate the sleeve and the downhole end.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2816008A CA2816008C (en) | 2013-05-17 | 2013-05-17 | Packer with integral centralizer |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2816008A CA2816008C (en) | 2013-05-17 | 2013-05-17 | Packer with integral centralizer |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2816008A1 true CA2816008A1 (en) | 2014-11-17 |
| CA2816008C CA2816008C (en) | 2019-07-16 |
Family
ID=51932087
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2816008A Active CA2816008C (en) | 2013-05-17 | 2013-05-17 | Packer with integral centralizer |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2816008C (en) |
-
2013
- 2013-05-17 CA CA2816008A patent/CA2816008C/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CA2816008C (en) | 2019-07-16 |
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| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request |
Effective date: 20170529 |