US20070062690A1 - Packer washout assembly - Google Patents
Packer washout assembly Download PDFInfo
- Publication number
- US20070062690A1 US20070062690A1 US11/229,781 US22978105A US2007062690A1 US 20070062690 A1 US20070062690 A1 US 20070062690A1 US 22978105 A US22978105 A US 22978105A US 2007062690 A1 US2007062690 A1 US 2007062690A1
- Authority
- US
- United States
- Prior art keywords
- packer
- fluid
- mandrel
- tubing string
- washout
- 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.)
- Abandoned
Links
- 239000012530 fluid Substances 0.000 claims abstract description 105
- 238000000034 method Methods 0.000 claims description 5
- 238000007789 sealing Methods 0.000 claims 2
- 230000015572 biosynthetic process Effects 0.000 description 7
- 238000004519 manufacturing process Methods 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- JEIPFZHSYJVQDO-UHFFFAOYSA-N iron(III) oxide Inorganic materials O=[Fe]O[Fe]=O JEIPFZHSYJVQDO-UHFFFAOYSA-N 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- 238000009825 accumulation Methods 0.000 description 2
- 239000004568 cement Substances 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 238000005406 washing Methods 0.000 description 2
- 241000251468 Actinopterygii Species 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000003801 milling Methods 0.000 description 1
- 210000002445 nipple Anatomy 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B31/00—Fishing for or freeing objects in boreholes or wells
- E21B31/03—Freeing by flushing
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Definitions
- the packer washout sub 22 is used in the event that the packer 20 fails to release due to the accumulation of debris (depicted in FIG. 1 by the reference numeral 48 ) such as sand, shale, silt, or rust, on top of the packer 20 .
- debris depictted in FIG. 1 by the reference numeral 48
- a standing valve 46 is landed on a seating nipple (not shown) to close off the tubing string 18 from below the packer washout sub 22 .
- the tubing string 18 is pressurized with fluid, such as water, to a pressure sufficient to rupture the rupture disks 42 .
- fluid is circulated through the debris (depicted in FIG. 5 by the reference numeral 60 ), over the top of the packer 20 a , and finally to the surface 52 so as to carry the debris to the surface 52 and thereby wash the debris from the top of the packer 20 a .
- the packer 20 a is released and the tubing string 18 a , along with the packer washout sub 22 and the packer 20 a , is withdrawn from the well bore 12 a.
Abstract
A packer washout assembly for removing debris from a well bore is disclosed. The packer washout assembly includes a tubing string positioned in the well bore and forming an annulus with the well bore. A packer is interposed in the tubing string and is sealable against the interior of the well bore. A packer washout sub is connected to an upper end of the packer. The packer washout sub includes a mandrel having at least one fluid flow port extending through a sidewall and a rupture disk positioned in the fluid flow port of the mandrel. The rupture disk is adapted to rupture upon the application of a predetermined pressure within the fluid passage of the mandrel so as to place the fluid passage in fluid communication with the annulus to permit fluid to pass through the fluid port from the mandrel to the annulus and thereby circulate fluid over the top of the packer so as to wash debris from the top of the packer.
Description
- 1. Field of the Invention
- The present invention relates generally to an apparatus for washing debris from a well bore, and more particularly, but not by way of limitation, to an apparatus and method for washing debris from a packer set in a well bore to permit the packer to be released.
- 2. Brief Description of Related Art
- Packers are downhole tools widely used in the completion of oil and gas wells to isolate and control producing and injected fluids. A variety of packers are known. Packers are often classified as either permanent or retrievable. A permanent packer is recovered from the well bore by using milling tools, while a retrievable packer is designed to be released and retrieved on the production tubing or on a workstring.
- A concern of well operators when setting a retrievable packer is the possibility of debris, such as sand, shale, or rust, settling on top of the packer and prohibiting the release of the packer. When this occurs one of several things may be attempted to retrieve the packer from the well bore. First, the tubing may be shot off just above the packer thereby permitting the majority of the tubing to be removed from the well bore. Next, an operator may fish back on the tubing in attempt to release the packer. Finally, if all the above fail, then the packer is milled out, or the well may be abandoned.
- Each of these procedures is time consuming and expensive. As such, a need exists for a tool that may be used with a packer to allow debris to be selectively removed from the packer when required. However, such an improved tool must also be cost efficient and substantially maintenance-free. It is to such a tool and method of use that the present invention is directed.
-
FIG. 1 is a schematic illustration, partially in cross section, of a packer washout assembly constructed in accordance with the present invention. -
FIG. 2 is a cross sectional view of a packer washout sub. -
FIG. 3 is a cross sectional view of another embodiment of a packer washout sub constructed in accordance with the present invention. -
FIG. 4 is a cross sectional view of another embodiment of a packer washout sub constructed in accordance with the present invention. -
FIG. 5 is a schematic illustration, partially in cross section, of another embodiment of a packer wash out assembly constructed in accordance with the present invention. - Referring now to
FIG. 1 , apacker washout assembly 10 constructed in accordance with the present invention for removing debris, such as sand, silt, shale, and rust, from the top of apacker 20 to permit the packer to be released is schematically illustrated. Awell bore 12 is shown to be lined with acasing 14 extending down from awellhead 15. Thecasing 14 provides a permanent borehole through which production operations may be conducted. Thecasing 14 is affixed in thewell bore 12 in a conventional manner, such as by cement (not shown), and is provided withperforations 16 open to a producingsubterranean formation 17. - The
packer washout assembly 10 includes atubing string 18, apacker 20, and apackerwashout sub 22. Thetubing string 18 provides fluid communication between the producingsubterranean formation 17 and asurface 24 such that a reservoir fluid (not shown), for example oil and/or natural gas, is produced through thetubing string 18. Thecasing 14 and thetubing string 18 define anannulus 26 which also provides fluid communication through thewell bore 12. - The
packer 20 is interposed in thetubing string 18 in a manner well known in the art. Thepacker 20 is commonly known as a retrievable packer in that it is designed to be inserted in thecasing 14 when in a deflated or relaxed condition, set so as to seal against the interior wall of the well bore 12, and then released when it is desired to remove thetubing string 18 and thepacker 20 from the well bore 12. As mentioned above, release of thepacker 20 may be hindered by the accumulation of debris on top of thepacker 20. - The
packer washout sub 22 is interposed in thetubing string 18 by connecting thepacker washout sub 22 to the top of thepacker 20. As best shown inFIG. 2 , thepacker washout sub 22 includes amandrel 30 having anupper end 32 adapted to be threadingly coupled to thetubing string 18, alower end 34 adapted to be threadingly coupled to theupper end 32 of thepacker 20, and asidewall 36 extending from theupper end 32 to thelower end 34. Thesidewall 36 defines afluid passage 38 extending from theupper end 32 to thelower end 34 so as to permit fluid flow between thetubing string 18 and thepacker 20. Themandrel 30 has at least onefluid port 40 extending through thesidewall 36; however, preferably, themandrel 30 has a plurality offluid ports 40.FIG. 2 shows one version where threefluid ports 40 are longitudinally aligned from thelower end 34 to theupper end 32 of themandrel 30 along one side of themandrel 30. - To close the
fluid ports 40, aclosure member 42 is positioned in each of thefluid ports 40 of themandrel 30 to close thefluid ports 40 during normal well operations. Theclosure members 42 are illustrated as being rupture disks that are screwed into thefluid ports 40 or otherwise secured in thefluid ports 40. Therupture disks 42 are adapted to rupture upon the application of a predetermined pressure within thefluid passage 38 of themandrel 30 so as place thefluid passage 38 in fluid communication with theannulus 26 to permit fluid to pass through thefluid port 40 from themandrel 30 to theannulus 26 and thereby circulate fluid over the top of thepacker 20 so as to wash debris from the top of thepacker 20. - The
rupture disks 42 selected to be positioned in thefluid ports 40 must maintain their integrity under normal fluid production or injection operations. For example, if thetubing string 18 will be subject to 1000 psi during production operations, a rupture disk rated to rupture at 2,500 psi may be selected. On the other hand, if thetubing string 18 is being used for the injecting fluid into a formation, thetubing string 18 may be subject to 5,000 psi. In this case, a rupture disk rated to rupture at 10,000 psi may be selected. -
FIGS. 3 and 4 illustrate other embodiments of apacker washout sub FIG. 3 shows thepacker washout sub 22 a having fourfluid ports 40 a arranged in a helical pattern about thesidewall 36 of the mandrel 30 a. Arupture disk 42 a is positioned in each of thefluid ports 40 a.FIG. 4 shows thepacker washout sub 22 b having fourfluid ports 40 b that are circumferentially spaced an equal distance about the mandrel 30 b. Arupture disk 42 b is positioned in each of thefluid ports 40 b. - The
packer washout sub 22 is used in the event that thepacker 20 fails to release due to the accumulation of debris (depicted inFIG. 1 by the reference numeral 48) such as sand, shale, silt, or rust, on top of thepacker 20. Upon determining that thepacker 20 is stuck, a standingvalve 46 is landed on a seating nipple (not shown) to close off thetubing string 18 from below thepacker washout sub 22. Next, thetubing string 18 is pressurized with fluid, such as water, to a pressure sufficient to rupture therupture disks 42. Upon therupture disk 42 rupturing, fluid communication between thefluid passage 38 of themandrel 30 and theannulus 26 is established to permit fluid to pass from themandrel 30 through thefluid port 40 and into theannulus 26. In theannulus 26, fluid is circulated through the debris, over the top of thepacker 20, and finally to thesurface 24 so as to carry the debris to thesurface 24 and thereby wash the debris from the top of thepacker 20. After the debris has been washed from the top of thepacker 20, the packer is released and thetubing string 18, along with thepacker washout sub 22 and thepacker 20, is withdrawn from the well bore 12. -
FIG. 5 illustrates the use of apacker washout sub 22 in atubing string 18 a. Thetubing string 18 a includes apacker 20 a and aplug 48. Thetubing string 18 provides fluid communication between producingsubterranean formation 50 and asurface 52 such that a reservoir fluid (not shown), for example oil and/or natural gas, is produced through thetubing string 18 a. Acasing 14 a is affixed in awell bore 12 a in a conventional manner, such as by cement (not shown), and is provided with perforations 54 open to the producingsubterranean formation 50. It will be noted that the producingsubterranean formation 50 is above thepacker 20 a. As such, thetubing string 18 a is provided withperforations 56 to permit fluid passing from theformation 50 to pass into thetubing string 18 a. - In the situation where the
packer 20 a fails to release and thetubing string 18 a is perforated above thepacker 20 a, theperforations 56 are first sealed prior to pressuring thetubing string 18 a for the purpose of rupturing therupture disks 42. Theperforations 56 may be sealed by insertingballs 58 into a stream of fluid injected into thetubing string 18 a at thesurface 52. Theballs 58 will lodge in theperforations 56 and thereby seal theperforations 56. Upon determining that theperforations 56 are sealed by an increase in fluid pressure, the fluid pressure in thetubing string 18 a is further increased to a pressure sufficient to rupture therupture disks 42. Upon the rupturing of therupture disks 42, fluid is circulated through the debris (depicted inFIG. 5 by the reference numeral 60), over the top of thepacker 20 a, and finally to thesurface 52 so as to carry the debris to thesurface 52 and thereby wash the debris from the top of thepacker 20 a. After the debris has been washed from the top of thepacker 20 a, thepacker 20 a is released and thetubing string 18 a, along with thepacker washout sub 22 and thepacker 20 a, is withdrawn from the well bore 12 a. - From the above description it is clear that the present invention is well adapted to carry out the objects and to attain the advantages mentioned herein as well as those inherent in the invention. While presently preferred embodiments of the invention have been described for purposes of this disclosure, it will be understood that numerous changes may be made which will readily suggest themselves to those skilled in the art and which are accomplished within the spirit of the invention disclosed and as defined in the appended claims.
Claims (12)
1. A packer washout assembly for removing debris from a well bore, comprising:
a tubing string positioned in the well bore and forming an annulus with the well bore;
a packer interposed in the tubing string and sealable against the interior of the well bore, the packer having an upper end and a lower end;
a packer washout sub comprising:
a mandrel having an upper end connected to the tubing string, a lower end connected to the upper end of the packer, and a sidewall extending from the upper end to the lower end, the sidewall defining a fluid passage extending from the upper end to the lower end, the mandrel having at least one fluid flow port extending through the sidewall; and
a closure member positioned in the fluid flow port of the mandrel, the closure member adapted to open upon the application of a predetermined pressure within the fluid passage of the mandrel so as to place the fluid passage in fluid communication with the annulus to permit fluid to pass through the fluid port from the mandrel to the annulus and thereby circulate fluid over the top of the packer so as to wash debris from the top of the packer.
2. The packer washout assembly of claim 1 wherein the mandrel includes a plurality of fluid ports, each fluid port has a closure member positioned therein.
3. The packer washout assembly of claim 1 wherein the mandrel includes a plurality of fluid flow ports extending through the sidewall, the fluid ports longitudinally axially aligned from the lower end to the upper end of the mandrel, each fluid flow port having a closure member positioned therein.
4. The packer washout assembly of claim 1 wherein the mandrel includes a plurality of fluid flow ports extending through the sidewall, the fluid ports arranged in a helical pattern about the sidewall of the mandrel, each fluid flow port having a closure member positioned therein.
5. The packer washout assembly of claim 1 wherein the mandrel includes a plurality of fluid flow ports extending through the sidewall, the fluid ports circumferentially spaced an equal distance about the mandrel, each fluid flow port having a closure member positioned therein.
6. A packer washout assembly for removing debris from a well bore, comprising:
a tubing string positioned in the well bore and forming an annulus with the well bore;
a packer interposed in the tubing string and sealable against the interior of the well bore, the packer having an upper end and a lower end;
a packer washout sub comprising:
a mandrel having an upper end connected to the tubing string, a lower end connected to the upper end of the packer, and a sidewall extending from the upper end to the lower end, the sidewall defining a fluid passage extending from the upper end to the lower end, the mandrel having at least one fluid flow port extending through the sidewall; and
a rupture disk positioned in the fluid flow port of the mandrel, the rupture disk adapted to open upon the application of a predetermined pressure within the fluid passage of the mandrel so as to place the fluid passage in fluid communication with the annulus to permit fluid to pass through the fluid port from the mandrel to the annulus and thereby circulate fluid over the top of the packer so as to wash debris from the top of the packer.
7. The packer washout assembly of claim 6 wherein the mandrel includes a plurality of fluid ports, each fluid port having a rupture disk positioned therein.
8. The packer washout assembly of claim 6 wherein the mandrel includes a plurality of fluid flow ports extending through the sidewall, the fluid ports longitudinally axially aligned from the lower end to the upper end of the mandrel, each fluid flow port having a rupture disk positioned therein.
9. The packer washout assembly of claim 6 wherein the mandrel includes a plurality of fluid flow ports extending through the sidewall, the fluid ports arranged in a helical pattern about the sidewall of the mandrel, each fluid flow port having a rupture disk positioned therein.
10. The packer washout assembly of claim 6 wherein the mandrel includes a plurality of fluid flow ports extending through the sidewall, the fluid ports circumferentially spaced an equal distance about the mandrel, each fluid flow port having a rupture disk positioned therein.
11. A method for removing debris from the top of a packer sealed against a well bore, comprising:
producing fluid through a tubing string positioned in the well bore, the tubing string forming an annulus with the well bore, the tubing string having a packer interposed therein, the packer sealed against the interior of the well bore and the packer having an upper end and a lower end, the tubing string further having a packer washout sub, the packer washout sub comprising:
a mandrel having an upper end connected to the tubing string, a lower end connected to the upper end of the packer, and a sidewall extending from the upper end to the lower end, the sidewall defining a fluid passage extending from the upper end to the lower end, the mandrel having at least one fluid flow port extending through the sidewall; and
a rupture disk positioned in the fluid flow port of the mandrel;
sealing the tubing string; and
pressurizing the tubing string to a sufficient pressure to rupture the rupture disk of the packer washout sub so as to place the fluid passage of the mandrel in fluid communication with the annulus to permit fluid to pass through the fluid port from the mandrel to the annulus and thereby circulate fluid over the top of the packer so as to wash debris from the top of the packer.
12. A method for removing debris from the top of a packer sealed against a well bore, comprising:
providing a tubing string in the well bore so that the tubing string forms an annulus with the well bore, the tubing string having a packer interposed therein, the packer sealed against the interior of the well bore and the packer having an upper end and a lower end, the tubing string further having a packer washout sub, the packer washout sub comprising:
a mandrel having an upper end connected to the tubing string, a lower end connected to the upper end of the packer, and a sidewall extending from the upper end to the lower end, the sidewall defining a fluid passage extending from the upper end to the lower end, the mandrel having at least one fluid flow port extending through the sidewall; and
a rupture disk positioned in the fluid flow port of the mandrel;
sealing the tubing string; and
pressurizing the tubing string to a sufficient pressure to rupture the rupture disk of the packer washout sub so as to place the fluid passage of the mandrel in fluid communication with the annulus to permit fluid to pass through the fluid port from the mandrel to the annulus and thereby circulate fluid over the top of the packer so as to wash debris from the top of the packer.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/229,781 US20070062690A1 (en) | 2005-09-16 | 2005-09-16 | Packer washout assembly |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/229,781 US20070062690A1 (en) | 2005-09-16 | 2005-09-16 | Packer washout assembly |
Publications (1)
Publication Number | Publication Date |
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US20070062690A1 true US20070062690A1 (en) | 2007-03-22 |
Family
ID=37882913
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US11/229,781 Abandoned US20070062690A1 (en) | 2005-09-16 | 2005-09-16 | Packer washout assembly |
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Cited By (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20070284109A1 (en) * | 2006-06-09 | 2007-12-13 | East Loyd E | Methods and devices for treating multiple-interval well bores |
US20090211759A1 (en) * | 2006-06-09 | 2009-08-27 | East Jr Loyd E | Methods and Devices for Treating Multiple-Interval Well Bores |
US20090250226A1 (en) * | 2008-04-02 | 2009-10-08 | Saudi Arabian Oil Company | Method for hydraulic rupturing of downhole glass disc |
US20110198082A1 (en) * | 2010-02-18 | 2011-08-18 | Ncs Oilfield Services Canada Inc. | Downhole tool assembly with debris relief, and method for using same |
US20110247828A1 (en) * | 2010-04-08 | 2011-10-13 | Schlumberger Technology Corporation | Fluid displacement methods and apparatus for hydrocarbons in subsea production tubing |
WO2013007025A1 (en) * | 2011-07-14 | 2013-01-17 | 四川宏华石油设备有限公司 | Valve |
US20130025875A1 (en) * | 2011-07-26 | 2013-01-31 | Chevron U.S.A. Inc. | Pipe-in-pipe apparatus, and methods and systems |
US8881802B2 (en) | 2011-11-30 | 2014-11-11 | Baker Hughes Incorporated | Debris barrier for packer setting sleeve |
US20140374096A1 (en) * | 2013-06-24 | 2014-12-25 | Team Oil Tools, Lp | Method and apparatus for smooth bore toe valve |
US8931559B2 (en) | 2012-03-23 | 2015-01-13 | Ncs Oilfield Services Canada, Inc. | Downhole isolation and depressurization tool |
US9010414B2 (en) | 2011-11-30 | 2015-04-21 | Baker Hughes Incorporated | Differential pressure control device for packer tieback extension or polished bore receptacle |
US20150292285A1 (en) * | 2013-02-19 | 2015-10-15 | Halliburton Energy Services, Inc. | Fluid flow during landing of logging tools in bottom hole assembly |
US11519235B1 (en) | 2021-08-18 | 2022-12-06 | Saudi Arabian Oil Company | Downhole ceramic disk rupture by jetting with fluids and solids |
CN115653543A (en) * | 2022-10-27 | 2023-01-31 | 中国石油天然气集团有限公司 | Oil well sand washing and well washing conversion device, oil well sand washing and well washing system and method |
US11702904B1 (en) | 2022-09-19 | 2023-07-18 | Lonestar Completion Tools, LLC | Toe valve having integral valve body sub and sleeve |
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US20070284109A1 (en) * | 2006-06-09 | 2007-12-13 | East Loyd E | Methods and devices for treating multiple-interval well bores |
US7478676B2 (en) * | 2006-06-09 | 2009-01-20 | Halliburton Energy Services, Inc. | Methods and devices for treating multiple-interval well bores |
US20090211759A1 (en) * | 2006-06-09 | 2009-08-27 | East Jr Loyd E | Methods and Devices for Treating Multiple-Interval Well Bores |
US7874365B2 (en) | 2006-06-09 | 2011-01-25 | Halliburton Energy Services Inc. | Methods and devices for treating multiple-interval well bores |
US20090250226A1 (en) * | 2008-04-02 | 2009-10-08 | Saudi Arabian Oil Company | Method for hydraulic rupturing of downhole glass disc |
US7661480B2 (en) * | 2008-04-02 | 2010-02-16 | Saudi Arabian Oil Company | Method for hydraulic rupturing of downhole glass disc |
US20110198082A1 (en) * | 2010-02-18 | 2011-08-18 | Ncs Oilfield Services Canada Inc. | Downhole tool assembly with debris relief, and method for using same |
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