CA1181681A - Packer tool for use in a wellbore - Google Patents
Packer tool for use in a wellboreInfo
- Publication number
- CA1181681A CA1181681A CA000407887A CA407887A CA1181681A CA 1181681 A CA1181681 A CA 1181681A CA 000407887 A CA000407887 A CA 000407887A CA 407887 A CA407887 A CA 407887A CA 1181681 A CA1181681 A CA 1181681A
- Authority
- CA
- Canada
- Prior art keywords
- tool
- mandrel
- well casing
- packer
- slips
- 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.)
- Expired
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Abstract
ABSTRACT OF THE DISCLOSURE
A packer tool, and method for permanently setting the tool, in a packed off position, in a well casing, is disclosed. The tool includes lower slips which are slideable upwardly on a lower cone, and upper slips which are slideable downwardly on an upper cone.
The lower slips are set against the casing wall first by applying downward force against the lower cone.
After the lower slips have been set, additional downward force is applied against the packer tool to set the upper slips against the casing wall.
A packer tool, and method for permanently setting the tool, in a packed off position, in a well casing, is disclosed. The tool includes lower slips which are slideable upwardly on a lower cone, and upper slips which are slideable downwardly on an upper cone.
The lower slips are set against the casing wall first by applying downward force against the lower cone.
After the lower slips have been set, additional downward force is applied against the packer tool to set the upper slips against the casing wall.
Description
PACKER TOOL FOR USE IN A WELLBORE
The invention relates to a packer tool for plugging of~ a well casing. More specifically, the invention covers a packer tool of the permanent type.
In the produc-tion of oil and gas there are various downhole operations which re~uire plugging off the well casing at a given point, or at more than one point. Examples of such operations are hydraulic frac-turing of a producing zone, and placing of propping materials, such as sand, in the fracture opening. When such operations are to be performed, the well casing is usually plugged off with a packer tool, either a permanent--type packer, or a retrievable packer.
The packer tools now available are not entirely satisfactory because of various problems. A major problem is in the "setting" of the packer in the casing.
When force is applied from the wellhead, to "set" the tool in place, the teeth of the upper and lower slips on the tool grip into the casing wall simultaneously.
At the same time, the rubber packing elements are only partly compressed, so that they do not set tightly against the casing wall. As additional force is applied, 27,066A-F
6~
to further set the packing elements, the packer tool moves down and the slips drag along the casing wall.
This causes -the slip teeth to become dull in a very short time, and -the packer is then unable to form a good fluid-tight plug in the casing.
The packer tool of this invention, which is designed to be permanently set in a well casing, avoids the problem described above. This tool is designed such that the lower slips are set first, followed by setting of the upper slips, with only a slight movement of the packer in the casing during the setting operation.
The tools described in U.S. Patents 2,753,941 (Hebard et al.), 3,061,013 (Williams), and 3,517,742 (Thomas) are representative of prior art packers and bridging plugs which are used in plugging off a well casing to perform a downhole operation. Although the tools described in these references are suita~le for plugging off a well casing, the structure and opera-tion of each tool is substantially different than the packer tool of the present invention. In particular, none of the prior tools have the capability for setting the slip members in the manner of the present packer, to avoid the drag problem described above.
The packer tool of this invention is adapted to be permanently set, in a packed off position, inside a well casing, the tool comprising:
an elongate mandrel which has a teeth section defined on its outer surface, an upper cone member slideable downwardly on the mandrel, a sleeve member fastened to the mandrel and to the upper cone member, a set of upper slip 27,066A-F -2-~3--member~ which seat against the upper sleeve and which are movable down~ardly and outwardly on the upper conP
member for locking engagement with the well casing, and means fastened to the upper cone membPr for locking the upper cone on the mandrel;
a lower cone member secured to the mandrel, and a set o~ lower 51ip members movable upwardly and outwardly on the lower cone member for locking engage-ment wi~h the well casing; and -10 a set of packing elements positioned on the mandrel between the upper and the lower cone members.
The present invention further resides in the method for permanently setting a packer tool, in a.
packed off position, inside of a wëll casing, the packer ¦ 15 tool including a mandrel, à set-of lower slips slideable - outwardly rom ~he mand~el, a set of upper slips slideable outwardly from thP mandrel-, expandable packing elements positioned between the lower a~d upper slips, and a setting tool adapted for,attachment to the packer tool, the method comprising the ~teps of:
attaching the setting tool to the packer tool and lowering the packer ~ool into the well casing to a prede~ermined position;
. applying a first downward force~ through the setting...tool, to the packing elements; thereby causing the packing elements to expand outwardly and pu~h against the innèr wall surface of the well casing;
causing the lower slips to slide outwardly and-engage the inner wall ~urface of the well casing;
applying a second downward force, through the setting tool I ~o the packing elements; thereby .
.-1 27,066A-F -3 .
~3a--causing the packing elements to expand further outwardly and push against the inner wall surface of the well casing; and causing the lower slips to slide outwardly and engage the inner wall surface of the casing.
When the packer tool is being run into the well casing, that is, befoxe the slips are set, the upper cone i5 positioned on ~he mandrel such that it ! can slide downwardly. The upper sleeve is fa~tened to the mandrel and to the upper cone. The upper slips, which are slideable downwardly on the upper cone, are seated against the upper sleeve prior to setting of these slips. The lower cone is secured to the mandrel;
and~~he lower slips, which are slideable upwardly on the lower cone, are seated against a lower guide on the man~rel prior to setting of these slips.
.
Dur~ng setting of the upper and lower slips, the packing elements are compressed, such that they i expand outwardly and push against the well casing to ; 20 form a fluid-tight seal. In the setting operation, the lower ~lips are set against the well casing first, and the low~r cone is locked against the mandrel, in a given position, by the lock means. Thereafter, the upper slips are set against the casing and the upper cone moves to a second position on the mandrel, where it is held in place by the lock means.
.
i 1 27,066A-F -3a-,. ~=. _ . .. ~ . ........ .
Figure lA is a par-tial view, in front eleva-tion, and partly in section, which illustrates the upper part of the present packer tool. Figure lB illustrates the lower part of the tool. In these Figures, the tool is shown in its running-in position.
Figure 2A is a partial view, in front elevation, and partly in section, showing only the upper part of the packer tool after the lower slips have been set.
Figure 2B shows only the lower part of the tool after setting the lower slips.
Figure 3A is a partial view, in front elevation, and partly in section, showing only the upper part of the packer tool after both the lower and upper slips have been set. Figure 3~ shows only the lower part of the tool after setting of the lower and upper slips.
In the drawings, the letter T generally indi-cates the packer tool of this invention. The basic tool is made up of a hollow, elongate mandrel 10. The mandrel includes a section o~ teeth 11, which is machined ~0 into the outer wall surface of the mandrel near the middle of this component. A lower guide member 12 is threaded onto the bottom end of the mandrel 10 and held in place by a set screw 13. A sleeve member 14 is fitted to the mandrel 10 just below the top of the mandrel. The sleeve member is held in place on the mandrel by several shear screws, indicated by numeral 15.
An upper cone 16 is fitted to the mandrel 10 and held in place by several shear screws 17, which are ~7,066A-F -4-threaded through the sleeve member 14. A set of upper slips 18 are ~itted to the cone 16, such tha-t they can slide downwardly along the cone. A lock ring 19 is threaded onto the upper cone 16. The inside of this ring has a teeth section (not numbered) which engages the teeth section 11 on mandrel 10. Ring l9 is also fastened to the cone 16 by a set screw 20.
An expanding gage ring 21 is fitted to mandrel 10 below the upper cone 160 Farther down on mandrel 10 is a similar gage ring 22. Between the two gage rings is a set of packer elements which fit around the mandrel.
These elements are made up of -two outer packer elements, 23 and 24, and a center element 25. A lower cone 26 fits around the mandrel below the gage riny 22 and the cone is secured to the mandrel by several set screws, indicated by numeral 27. Means for setting the lower part of the packer tool T is provided by a set of lower slips 28, which are positioned to slide upwardly along cone 26.
~he basic operation of the present packer tool will now be described to illustrate the practice of this invention. In a typical down hole operation, the top of the mandrel 10 is connected to a wire line setting tool, which, in turn, is fastened to the bottom ~5 end of a tubing string. The setting tool and the tubing string are not shown in the drawing. The packer tool T is then lowered on the string into the well casing 29, until it reaches the point where the casing is to be packed off. At this point, the tool is in its running in position, as sho~m in Figures lA and lB.
The next step is to set the lower slips 28, as shown in Figures 2A and 2B (the slips appear only in Figure 2B).
27,066A-F -5---6~
A sleeve (not shown) on the set-ting tool seats against the sleeve member 14. The resulting downward force against the sleeve member shears off the screws 15, so that sleeve member 14 moves downwardly on the mandrel lO. Upper cone 16 also moves downwardly along with sleeve member 14, because the cone is held securely to the mandrel by the larger shear screws 17.
As con~ 16 moves down, the inside teeth on the lock ring 19 "ratchet" downwardly on the mandrel teeth ll.
When cone 16 reaches its lowest point of travel, the ring l9 locks the cone against the mandrel 10, to prevent undesired upward movement of the packer components.
The dow~ward movement of upper cone 16 com~
presses the packer elemen-ts 23, 24 and 25 between cone 16 and the lower cone 26. This causes the packer elements to expand outwardly and push against the outside wall of the casing 29, to form a fluid-tight seal at this point in the casing. The compression of the packer elements also forces the expandin~ yage ring 22 to push down on lower cone 26, with ~nough force to shear off the screws 27. As cone 26 moves down, the lower slips 28 ride upwardly on the cone and move outwardly until they grip into the wall of casing 29.
The lower slips are then in the fully set position shown in Flgure 2B.
The next step is to set the upper slips 18, as illustrated in Figures 3A and 3B (the slips appear only in Figure 3B). This sequence is started by applying enough additional downward force, through the 27,066A-F -6-setting tool, to shear off the larger shear screws 17, which secure the sleeve member 14 to the upper cone 16.
When the screws 17 are sheared off, the sleeve member 14 moves downwardly on the upper cone. At the same time, the sleeve member pushes the upper slips 18 downwardly on the upper cone. This causes the upper slips to move outwardly until they grip into the wall of casing 29. The upper slips are then in the fully set position shown in Figure 3B.
The next step is to release the setting tool from the packer tool. This is done by applying enough additional downward force against the setting tool to shear the connection which fastens the setting tool to the~ top of mandrel 10. This connection is not shown in the drawings. When the connec-tion is broken,-the tubing string and setting tool are then pulled out of the casing, so that the packer tool is left in the casing as a permanent structure.
Adequate clearance is required between the lock ring 19 and the upper cone 16 to allow the lock ring to ratchet and advance on the mandrel threads 11.
A slotted back-up ring 21A is positioned between the packer element 23 and the expanding gage ring 21. A similar back-up ring 22A is positioned between the packer element 24 and the gage ring 22.
The purpose of the back-up rings is to cover the enlarged slots of the expanded gage rings and to thereby prevent extrusion of the packer elements past the openings in the expanded gage rings during compression of the packer elements and after setting of the lower and upper slips. The purpose is conveniently 27,066A-F -7-achieved by positioning the back-up rings in such a way that the slo-ts in the back up ring are staggered rela-tive to the slots in the expanding gage ring. Usually the slots in the expanding gage rings are uniformly posi-tioned around the rings and also around the back-up rings.
The number of slots in the expanding gage rings is no-t critical, but Applicant has found an even number of slots to be convenient. Likewise, the number of slots in the back-up rings is not critical, but Applicant has found it convenient to use the same number of slots in the back-up ring as is used in the associated expanding gage ring. For example, if the expanding gage ring contains 6 slots uniformly posi-tioned around the ring (which is typical3, then normally the back-up ring would also contain 6 slots uniformly positioned around its circumference; however, other combinations could obviously be used (e.g., 12 slots in the expanding gage ring and 6 slots in the back-up ring, or 6 slots in the expanding gage ring and 3 slots in the back-up ring.
27,066A-F -8
The invention relates to a packer tool for plugging of~ a well casing. More specifically, the invention covers a packer tool of the permanent type.
In the produc-tion of oil and gas there are various downhole operations which re~uire plugging off the well casing at a given point, or at more than one point. Examples of such operations are hydraulic frac-turing of a producing zone, and placing of propping materials, such as sand, in the fracture opening. When such operations are to be performed, the well casing is usually plugged off with a packer tool, either a permanent--type packer, or a retrievable packer.
The packer tools now available are not entirely satisfactory because of various problems. A major problem is in the "setting" of the packer in the casing.
When force is applied from the wellhead, to "set" the tool in place, the teeth of the upper and lower slips on the tool grip into the casing wall simultaneously.
At the same time, the rubber packing elements are only partly compressed, so that they do not set tightly against the casing wall. As additional force is applied, 27,066A-F
6~
to further set the packing elements, the packer tool moves down and the slips drag along the casing wall.
This causes -the slip teeth to become dull in a very short time, and -the packer is then unable to form a good fluid-tight plug in the casing.
The packer tool of this invention, which is designed to be permanently set in a well casing, avoids the problem described above. This tool is designed such that the lower slips are set first, followed by setting of the upper slips, with only a slight movement of the packer in the casing during the setting operation.
The tools described in U.S. Patents 2,753,941 (Hebard et al.), 3,061,013 (Williams), and 3,517,742 (Thomas) are representative of prior art packers and bridging plugs which are used in plugging off a well casing to perform a downhole operation. Although the tools described in these references are suita~le for plugging off a well casing, the structure and opera-tion of each tool is substantially different than the packer tool of the present invention. In particular, none of the prior tools have the capability for setting the slip members in the manner of the present packer, to avoid the drag problem described above.
The packer tool of this invention is adapted to be permanently set, in a packed off position, inside a well casing, the tool comprising:
an elongate mandrel which has a teeth section defined on its outer surface, an upper cone member slideable downwardly on the mandrel, a sleeve member fastened to the mandrel and to the upper cone member, a set of upper slip 27,066A-F -2-~3--member~ which seat against the upper sleeve and which are movable down~ardly and outwardly on the upper conP
member for locking engagement with the well casing, and means fastened to the upper cone membPr for locking the upper cone on the mandrel;
a lower cone member secured to the mandrel, and a set o~ lower 51ip members movable upwardly and outwardly on the lower cone member for locking engage-ment wi~h the well casing; and -10 a set of packing elements positioned on the mandrel between the upper and the lower cone members.
The present invention further resides in the method for permanently setting a packer tool, in a.
packed off position, inside of a wëll casing, the packer ¦ 15 tool including a mandrel, à set-of lower slips slideable - outwardly rom ~he mand~el, a set of upper slips slideable outwardly from thP mandrel-, expandable packing elements positioned between the lower a~d upper slips, and a setting tool adapted for,attachment to the packer tool, the method comprising the ~teps of:
attaching the setting tool to the packer tool and lowering the packer ~ool into the well casing to a prede~ermined position;
. applying a first downward force~ through the setting...tool, to the packing elements; thereby causing the packing elements to expand outwardly and pu~h against the innèr wall surface of the well casing;
causing the lower slips to slide outwardly and-engage the inner wall ~urface of the well casing;
applying a second downward force, through the setting tool I ~o the packing elements; thereby .
.-1 27,066A-F -3 .
~3a--causing the packing elements to expand further outwardly and push against the inner wall surface of the well casing; and causing the lower slips to slide outwardly and engage the inner wall surface of the casing.
When the packer tool is being run into the well casing, that is, befoxe the slips are set, the upper cone i5 positioned on ~he mandrel such that it ! can slide downwardly. The upper sleeve is fa~tened to the mandrel and to the upper cone. The upper slips, which are slideable downwardly on the upper cone, are seated against the upper sleeve prior to setting of these slips. The lower cone is secured to the mandrel;
and~~he lower slips, which are slideable upwardly on the lower cone, are seated against a lower guide on the man~rel prior to setting of these slips.
.
Dur~ng setting of the upper and lower slips, the packing elements are compressed, such that they i expand outwardly and push against the well casing to ; 20 form a fluid-tight seal. In the setting operation, the lower ~lips are set against the well casing first, and the low~r cone is locked against the mandrel, in a given position, by the lock means. Thereafter, the upper slips are set against the casing and the upper cone moves to a second position on the mandrel, where it is held in place by the lock means.
.
i 1 27,066A-F -3a-,. ~=. _ . .. ~ . ........ .
Figure lA is a par-tial view, in front eleva-tion, and partly in section, which illustrates the upper part of the present packer tool. Figure lB illustrates the lower part of the tool. In these Figures, the tool is shown in its running-in position.
Figure 2A is a partial view, in front elevation, and partly in section, showing only the upper part of the packer tool after the lower slips have been set.
Figure 2B shows only the lower part of the tool after setting the lower slips.
Figure 3A is a partial view, in front elevation, and partly in section, showing only the upper part of the packer tool after both the lower and upper slips have been set. Figure 3~ shows only the lower part of the tool after setting of the lower and upper slips.
In the drawings, the letter T generally indi-cates the packer tool of this invention. The basic tool is made up of a hollow, elongate mandrel 10. The mandrel includes a section o~ teeth 11, which is machined ~0 into the outer wall surface of the mandrel near the middle of this component. A lower guide member 12 is threaded onto the bottom end of the mandrel 10 and held in place by a set screw 13. A sleeve member 14 is fitted to the mandrel 10 just below the top of the mandrel. The sleeve member is held in place on the mandrel by several shear screws, indicated by numeral 15.
An upper cone 16 is fitted to the mandrel 10 and held in place by several shear screws 17, which are ~7,066A-F -4-threaded through the sleeve member 14. A set of upper slips 18 are ~itted to the cone 16, such tha-t they can slide downwardly along the cone. A lock ring 19 is threaded onto the upper cone 16. The inside of this ring has a teeth section (not numbered) which engages the teeth section 11 on mandrel 10. Ring l9 is also fastened to the cone 16 by a set screw 20.
An expanding gage ring 21 is fitted to mandrel 10 below the upper cone 160 Farther down on mandrel 10 is a similar gage ring 22. Between the two gage rings is a set of packer elements which fit around the mandrel.
These elements are made up of -two outer packer elements, 23 and 24, and a center element 25. A lower cone 26 fits around the mandrel below the gage riny 22 and the cone is secured to the mandrel by several set screws, indicated by numeral 27. Means for setting the lower part of the packer tool T is provided by a set of lower slips 28, which are positioned to slide upwardly along cone 26.
~he basic operation of the present packer tool will now be described to illustrate the practice of this invention. In a typical down hole operation, the top of the mandrel 10 is connected to a wire line setting tool, which, in turn, is fastened to the bottom ~5 end of a tubing string. The setting tool and the tubing string are not shown in the drawing. The packer tool T is then lowered on the string into the well casing 29, until it reaches the point where the casing is to be packed off. At this point, the tool is in its running in position, as sho~m in Figures lA and lB.
The next step is to set the lower slips 28, as shown in Figures 2A and 2B (the slips appear only in Figure 2B).
27,066A-F -5---6~
A sleeve (not shown) on the set-ting tool seats against the sleeve member 14. The resulting downward force against the sleeve member shears off the screws 15, so that sleeve member 14 moves downwardly on the mandrel lO. Upper cone 16 also moves downwardly along with sleeve member 14, because the cone is held securely to the mandrel by the larger shear screws 17.
As con~ 16 moves down, the inside teeth on the lock ring 19 "ratchet" downwardly on the mandrel teeth ll.
When cone 16 reaches its lowest point of travel, the ring l9 locks the cone against the mandrel 10, to prevent undesired upward movement of the packer components.
The dow~ward movement of upper cone 16 com~
presses the packer elemen-ts 23, 24 and 25 between cone 16 and the lower cone 26. This causes the packer elements to expand outwardly and push against the outside wall of the casing 29, to form a fluid-tight seal at this point in the casing. The compression of the packer elements also forces the expandin~ yage ring 22 to push down on lower cone 26, with ~nough force to shear off the screws 27. As cone 26 moves down, the lower slips 28 ride upwardly on the cone and move outwardly until they grip into the wall of casing 29.
The lower slips are then in the fully set position shown in Flgure 2B.
The next step is to set the upper slips 18, as illustrated in Figures 3A and 3B (the slips appear only in Figure 3B). This sequence is started by applying enough additional downward force, through the 27,066A-F -6-setting tool, to shear off the larger shear screws 17, which secure the sleeve member 14 to the upper cone 16.
When the screws 17 are sheared off, the sleeve member 14 moves downwardly on the upper cone. At the same time, the sleeve member pushes the upper slips 18 downwardly on the upper cone. This causes the upper slips to move outwardly until they grip into the wall of casing 29. The upper slips are then in the fully set position shown in Figure 3B.
The next step is to release the setting tool from the packer tool. This is done by applying enough additional downward force against the setting tool to shear the connection which fastens the setting tool to the~ top of mandrel 10. This connection is not shown in the drawings. When the connec-tion is broken,-the tubing string and setting tool are then pulled out of the casing, so that the packer tool is left in the casing as a permanent structure.
Adequate clearance is required between the lock ring 19 and the upper cone 16 to allow the lock ring to ratchet and advance on the mandrel threads 11.
A slotted back-up ring 21A is positioned between the packer element 23 and the expanding gage ring 21. A similar back-up ring 22A is positioned between the packer element 24 and the gage ring 22.
The purpose of the back-up rings is to cover the enlarged slots of the expanded gage rings and to thereby prevent extrusion of the packer elements past the openings in the expanded gage rings during compression of the packer elements and after setting of the lower and upper slips. The purpose is conveniently 27,066A-F -7-achieved by positioning the back-up rings in such a way that the slo-ts in the back up ring are staggered rela-tive to the slots in the expanding gage ring. Usually the slots in the expanding gage rings are uniformly posi-tioned around the rings and also around the back-up rings.
The number of slots in the expanding gage rings is no-t critical, but Applicant has found an even number of slots to be convenient. Likewise, the number of slots in the back-up rings is not critical, but Applicant has found it convenient to use the same number of slots in the back-up ring as is used in the associated expanding gage ring. For example, if the expanding gage ring contains 6 slots uniformly posi-tioned around the ring (which is typical3, then normally the back-up ring would also contain 6 slots uniformly positioned around its circumference; however, other combinations could obviously be used (e.g., 12 slots in the expanding gage ring and 6 slots in the back-up ring, or 6 slots in the expanding gage ring and 3 slots in the back-up ring.
27,066A-F -8
Claims (9)
1. A packer tool adapted to be permanently set, in a packed off position, inside a well casing, the tool comprising:
an elongate mandrel which has a teeth section defined on its outer surface, an upper cone member slideable downwardly on the mandrel, a sleeve member fastened to the mandrel and to the upper cone member, a set of upper slip members which seat against the upper sleeve and which are movable downwardly and outwardly on the upper cone member for locking engagement with the well casing, and means fastened to the upper cone member for locking the upper cone on the mandrel;
a lower cone member secured to the mandrel, and a set of lower slip members movable upwardly and outwardly on the lower cone member for locking engagement with the well casing; and a set of packing elements positioned on the mandrel between the upper and the lower cone members.
an elongate mandrel which has a teeth section defined on its outer surface, an upper cone member slideable downwardly on the mandrel, a sleeve member fastened to the mandrel and to the upper cone member, a set of upper slip members which seat against the upper sleeve and which are movable downwardly and outwardly on the upper cone member for locking engagement with the well casing, and means fastened to the upper cone member for locking the upper cone on the mandrel;
a lower cone member secured to the mandrel, and a set of lower slip members movable upwardly and outwardly on the lower cone member for locking engagement with the well casing; and a set of packing elements positioned on the mandrel between the upper and the lower cone members.
2. The tool of Claim 1 in which the locking means is a ring positioned between the upper cone member and the mandrel, means for securing the ring to the upper cone member, and a teeth section on the inner surface of the ring engageable with the teeth section on the outer surface of the mandrel.
3. The tool of Claim 1 in which the sleeve member is fastened to the mandrel by a first shear means and is slidable downwardly on the mandrel, to a first position, upon rupture of said shear means, and in which the sleeve member is fastened to the upper cone member by a second shear means and is slidable downwardly from the first position to a second position, upon rupture of said second shear means.
4. The tool of Claim 3 wherein the first and second shear means on the sleeve member and the shear means on the lower cone member each comprise a plurality of shear pins, and wherein the first shear pins on the sleeve member and the shear pins on the lower cone member are designed to rupture upon the application of a pressure force to the sleeve member prior to rupture of the second shear pins on the sleeve member for moving the lower cone members against the lower slip members and for moving the lower slip members outwardly into locking engagement with the well casing and for compressing and expanding the packing elements into sealing engagement with the inner wall of the well casing.
5. The tool of Claim 4, wherein the second shear pins for securing the upper cone member to the sleeve member are of a larger size than the first shear pins such that rupture of the second shear pins takes place subsequent to rupture of the first shear pins and after engagement of the lower slip members and packing elements with the well casing, said rupture of the second shear pins causing the first slip members to move downwardly and outwardly on the upper cone member and into locking engagement with the inner wall of the well casing.
6. The tool of Claim 1 including a first expandable ring member positioned between the upper cone member and the packing elements and a second expandable ring member positioned between the lower cone member and the packing elements.
7. The tool of Claim 6 including a first slotted back-up ring positioned between the first expandable ring member and the packing elements and a second slotted back-up ring positioned between the second expandable ring member and the packing element, said back-up rings preventing extrusion of the packer elements past openings in the expanded ring members during compression of the packer elements.
8. The tool of Claim 1 including a setting means which can be attached to the tool, and which is adapted to cause the lower slips to engage and set against the well casing, and thereafter to cause the upper slips to engage and set against the well casing.
9. Method for permanently setting a packer tool, in a packed off position, inside of a well casing, the packer tool including a mandrel, a set of lower slips slideable outwardly from the mandrel, a set of upper slips slideable outwardly from the mandrel, expandable packing elements positioned between the lower and upper slips, and a setting tool adapted for attachment to the packer tool, the method comprising the steps of:
attaching the setting tool to the packer tool and lowering the packer tool into the well casing to a predetermined position;
applying a first downward force, through the setting tool, to the packing elements; thereby causing the packing elements to expand out-wardly and push against the inner wall surface of the well casing;
causing the lower slips to slide outwardly and engage the inner wall surface of the well casing;
applying a second downward force, through the setting tool, to the packing elements; thereby causing the packing elements to expand further outwardly and push against the inner wall surface of the well casing; and causing the lower slips to slide outwardly and engage the inner wall surface of the casing.
attaching the setting tool to the packer tool and lowering the packer tool into the well casing to a predetermined position;
applying a first downward force, through the setting tool, to the packing elements; thereby causing the packing elements to expand out-wardly and push against the inner wall surface of the well casing;
causing the lower slips to slide outwardly and engage the inner wall surface of the well casing;
applying a second downward force, through the setting tool, to the packing elements; thereby causing the packing elements to expand further outwardly and push against the inner wall surface of the well casing; and causing the lower slips to slide outwardly and engage the inner wall surface of the casing.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA000407887A CA1181681A (en) | 1982-07-23 | 1982-07-23 | Packer tool for use in a wellbore |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA000407887A CA1181681A (en) | 1982-07-23 | 1982-07-23 | Packer tool for use in a wellbore |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1181681A true CA1181681A (en) | 1985-01-29 |
Family
ID=4123270
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000407887A Expired CA1181681A (en) | 1982-07-23 | 1982-07-23 | Packer tool for use in a wellbore |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA1181681A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110630210A (en) * | 2019-10-16 | 2019-12-31 | 中国石油集团川庆钻探工程有限公司长庆钻井总公司 | Loess layer leakage-proof plugging tool and use method thereof |
-
1982
- 1982-07-23 CA CA000407887A patent/CA1181681A/en not_active Expired
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110630210A (en) * | 2019-10-16 | 2019-12-31 | 中国石油集团川庆钻探工程有限公司长庆钻井总公司 | Loess layer leakage-proof plugging tool and use method thereof |
| CN110630210B (en) * | 2019-10-16 | 2023-12-01 | 中国石油天然气集团有限公司 | Leakage-proof plugging tool for yellow soil layer and using method thereof |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MKEC | Expiry (correction) | ||
| MKEX | Expiry |