CA2193290A1 - Packer with back-up retrieving method - Google Patents
Packer with back-up retrieving methodInfo
- Publication number
- CA2193290A1 CA2193290A1 CA 2193290 CA2193290A CA2193290A1 CA 2193290 A1 CA2193290 A1 CA 2193290A1 CA 2193290 CA2193290 CA 2193290 CA 2193290 A CA2193290 A CA 2193290A CA 2193290 A1 CA2193290 A1 CA 2193290A1
- Authority
- CA
- Canada
- Prior art keywords
- packer
- mandrel
- release
- abutment
- production tubing
- 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
Abstract
A packer or bridge plug is described which may be release by manipulation of the production tubing connected to it. If manipulation of the production tubing is unsuccessful in releasing the packer, the tensile strength of the production tubing need not be exceeded in attempting to remove the packer. Instead, the productiontubing is removed along with certain internal components of the packer. Thereaf-ter, heavy-wall tubing, with or without jars, can be lowered into the wellbore with a retrieving tool at the bottom of that string. The retrieving tool latches onto com-ponents of the packer to allow an alternative method of release which allows foruse of significantly higher tensile loads to liberate the packer from the wellbore.
Description
TITLE: PACKER WITH BACK-UP RETRIEVING METHOD
INVENTORS: WILLIAM D. HENDERSON and JEFFREY J. LEMBCKE
FIFT r~ OF THE INVFl~ION
The field of this invention relates to retrievable parlrPre, and more particu-larly to packers that may be retrieved in more than one way.
10 BACKGROUND OF T~F T~VF~ITION
Packers are frequently used in oil and gas production to isolate one portion of a wellbore from another. After being set in a wellbore for what could be as long as many years, these p~rlr~rs need to be retrieved. Several ~ei~e have beenincorporated in the past for retrievable packers. One such packer, known as a seal-15 bore-type packer, was run in on wireline. After setting the packer on wireline, tubing was run and cf~nnecte~l to the packer by means of an anchor. In order to retrieve this type of packer, the pro~lucfiQn tubing had to be ii.eco~n~cte~l from the packer and removed from the wellbore. A sep~ale trip into the wellbore was then required with a speci~lly designed retrieving tool that released the mech~nieme 20 within the packer to allow it to be unset and retrieved. Since the additional run of tubing was made with hca~vyweight drillpipe with or without jars, which allowed for tensile loads higher than the st~nd~rd production tubing, these types of packers were often used and easily retrieved. Often these packers, after reln~ining in the wellbore for many years, required the additional tensile loads that could be applied 25 through the heavy-wall tubing in combination with jars. These high-tensile loads were l~ecess~.~ due to parts corroding together or debris settling out around the packer. While this type of design allowed for retrieval, it was only at the expense of running the heavy-wall tubing into the hole on a separate run. Typical of such 2 1 932qO
packers are par~P-rs made by Baker Oil Tools under Product No. 646, also called RETRIEVA-D; RETRIEVA-DB; and RETRIEVA-DAB LOCK-SET retrievable packers.
Another type of packer previously used is referred to as a modified tubing-set packer. This particular type of packer could be set on a wireline. Part of the Pe,eembly of the packer included a seal nipple and an on/off tool. These compo-nents were connP~ted to the packer mandrel above the packer and were left in thewell when the packer was set. The production tubing was then run in and eng~ged with the on/off tool seal nipple. The packer was retrieved by manip~ ting the tubing in combination with rotation and tension to release the packer. The packer was then retrieved on the production tubing. While this technique was desirable beca~ee it did not le~lui~c an additional tubing run, as indicated with the previously descAbed seal-bore-type pac~Pre~ such pac~Pre have been found to be less reliable when it comes to retAeval than the seal-bore pae~P-rs, pAmaAly due to the tensile limits of the pro~uction tubing string, the on/off tool, and the packer mandrel.Typical of such ~es~Pmblies of the modified tubing-set packer are a wireline-setUni-Packer VI made by Guiber.eon ~VA, a division of Dresser Tn-lnstries. Nippleswhich convert perm~nPnt or retAevable pacl~Prs into t,lnpol~r bridge plugs and which are carried in with the packer when it is set are known in the art and onesuch product is made by Baker Oil Tools, Model RS, Product No. 66548 Seffln~
Nipple.
Ac~ordiJlgly, an objective of the preselll invention is to provide a packer or bridge plug which can be tubing-rele~ce~l but if such mode of release for any reason does not function to release the packer or bridge plug, a back-up method of release with a rele~eing tool is also available for the same packer. The alterna-tive method of release functions akin to the operation of the seal-bore-type pac~e-rs and requires the ad~liti~m~l run into the wellbore with heavy-wall tubing to be used. Accoldil~gly, the objective of the invention is to give a greater confi~len~
level to operators beyond that previously e~ri~on~ed with using only a modified tubing-set packer. Now, with the plesent invention, if the modified tubing-set packer with the production tubing string fails to release, an ~ltçnl~tive release me~h~ m is available.
SUMMA~Y OF THF INVF~TION
A packer or bridge plug is described which may be released by manipulation of the produr,tion tubing conr~ted to it. If manipulation of the production tubing is rncllcc~s~irul in rele~cing the packer, the tensile strength of the production tubing need not be excee~led in attempting to remove the packer. Tn~tead the productiontubing is removed along with certain intern~l compollents of the packer. Thereaf-ter, heavy-wall tubing, with or without jars, can be lowered into the wellbore with a retrieving tool at the bottom of that string. The lehiGvillg tool latches onto com-poll~n~ of the packer to allow an ~ltçr l~tive method of release which allows for use of significantly higher tensile loads to liberate the packer from the wellbore.
nFT~n~Fn nF~CRlPIlON OF TE~F n~WI~GS
Figures la-d illustrate the packer of the preselll invention in the run-in position.
Figures 2a-d illu~hate the packer in the set position.
Figures 3a-d illu~h~te the packer in the set position with the washover shoe of the on/off tool latched into a J-slot.
Figures 4a-d illustrate the fully retrieved position using the washover shoe of the on/off tool latched into the l-slot.
Figures 5a-d illustrate the tool in the set position after rotation off of the lower end of the mandrel.
Figures 6a-d are similar to the view of Sa-d except showing the mandrel sheared.
Figures 7a-d show the ~lt~Prn~tive retrieval using a retrieving tool.
nFT~l~ Fn nF~CRTPllON OF T~F pRFFFRRFn Fl~RODIl~IF~T
Referring to Figures la-d, the app&,alus of the lJles~nt invention is illus-trated. Since many of the fealules of the packer are st~n~l~rd collll~onents, they will 10 be described only very briefly. Packers or bridge plugs generally have a series of slips 10 and se~ling elements 12. The slips 10 anchor the packer, while the sc~ling elements 12 seal off around the periphery. The slips 10 are cammed outwardly along ta~red s~ ec 14, while the s~P~ling elements 12 e~p~n~l radially oulw~dly by beco.lling comp.essed between rings 16 and 18. Ring 18 is connectP~ to a set-15 ting sleeve 20. A setting tool S of the type well-known in the art has components that move in opposile directions to create the nec~P-ss~ relat*e movement to urge the slips 10 along the tapered snrf~c~e 14, followed by the setting of the sealing elemP-nte 12 as rings 16 and 18 approach each other.- A lock ring 22 holds the set of the e~ling elements 12 after co.llples~ion has oc~ulled, as seen by co.~-p~ g20 Figure lc to Figure 2c. The setting tool S has a du~lw~dly moving sleeve 24, which bears on setting sleeve 20 but is otherwise not physically connect~P~ thereto.
Another pOniOn of the setting tool S includes a sleeve 26 which is secured to a mandrel 28 by a shear pin 30. Sup~lled by mandrel 28 is a known b1~nlcing plug 32 which is run in with the entire ~sembly so as to seal off an internal bore 34 in 25 the packer, using seal 36.
2 1 ~3290 Not shown in the drawings is the wireline ~uppoll for the setting tool S
which allows the proper positioning of the packer in the wellbore. The setting tool S is ~stn~t~P~ in known ways to create dirr~.enlial movement between sleeves 24 and 26 such that sleeve 24 moves dow-l~dly, while sleeve 26 moves u~v~dly 5 to ac~omplish the setting~ as indicated by the arrows in Figure 2a. This dilr~ nlial movement cams the slips 10 oulw~-dly~ as shown in Figure 2c. C~ntinl~P~ differ-ential movement brings rings 16 and 18 closer together, while the lock ring 22, using r~trheting teeth 23, retains the position of all the components, as shown in Figure 2c. Shear pin 30 is sheared after full setting force is applied. This allows 10 the setting tool S to be removed. At this point, the setting tool S can be removed and the pro-luction tubing run in the hole, coupled with a washover shoe 38 (seeFigure 3a). The washover shoe 38 has a J-slot arrangement 40 which latches onto lug 42, which is part of the mandrel ~c.cernbly 28. It can also be secured by other means. Seals 44 effectively seal between the washover shoe 38 and the mandrel 15 28. Once that task is ac~omplished, the bl~nking plug 32 is removed by wireline.
It should be noted that the production tubing 46 :iUppOlk~ the washover shoe 38 until the J-slot 40 c~tchP~ the lug 42. At that time, the production tubing string 46 is sP~lin~ly engaged to the mandrel 28 and, upon removal of the bl~nking plug32, production through the packer P can commPnce in a known ...~ -r.
When it comes time to release the packer, Figures 4a-d illu~llale one tech-nique. In this technique, a rotational forc~ is applied to the production tubing 46.
This rotation undoes thread 48, which is shown in Figure 4b already s~ aled.
With thread 48 un~1onP., an u~v~d force is applied on the producti~ tubing 46, brin~ing up mandrel 28. Packer mandrel 29 is ret~inP~l in a fi~ed position due to m~ting teeth 72 and 74. At its lower end 52, mandrel segment or sleeve 28 has a lug 54 which is secured to sleeve 50 by shear pin 56. Below lug 54 is ring 58, which is c~m~-cte~l to sleeve 28 at thread 60.
As shown in Figure 3d, the set position of the slips 10 and se~ling elements 12 is also lel~ ~l by collet fingers 70, which have teeth 72 which engage teeth 74 S on bottom sub 76. The position of the fingers 70 is secured by a ring 78 which is secured to the fingers 70 by a shear pin 80. Those skilled in the art will a~ple~;iate that a multiplicity of fingers 70, each with teeth 72, are employed, all of which engage the teeth 74 on the bottom sub 76.
Referring now to Figure 4d, it can be seen that after the thread 48 is undone and an u~w~J pull is applied to the tubing string 46, lug 54 bears on ring 78 toultimately break shear pin 80. When shear pin 80 breaks, the ring 78 can move u~w~dly, thus allowing the fingers 70 to flex radially inwardly so as to allow the teeth 72 to sep~ate from the teeth 74. When this occurs, the ~esemhly that holdsthe slips 10 and the se~ling ele.m~-nt 12 in a co.,-~leseed state can be e~tPn~le~l by 15 c~ g the u~,w~d pull on the production string 46.
Ultimately, as shown in Figure 4c, the slips 10 ride down the tapered s~R~e 14 and are retracted. A co~ u~w~ pull on the production string 46 will move ring 18 away from ring 16 to allow the sealing elements 12 to relax to the poeitinln shown in Figure lc. As shown in Figure 4c, the fingers 70 have had their 20 teeth 72 move completely away from the interengAging teeth 74 as a result of the breaking of shear pin 80. Lug 54 then ~uppolls ring 78 when there is further u~w~d pulling on the production string 46. Ring 78 is shaped so that it cannot fall off of fingers 70, even after shear pin 80 is broken bec~se it c~tclle~e shoulder 81.
With lug 54 in contact with ring 78, the entire weight of the packer shifts to the 25 production string 46 and it can then be removed, ~ .n~ g that no complications develop.
2 i 93290 However, esreci~lly for paCL-~re that have been in the wellbore for many years, the motions previously described may not be sufficient to release the packer from the wellbore. Thus, despite the undoing of thread 48 and the exertion of anu~d force within the limits of the tensile loads which can be applied through S the production tubing 46, the assembly for a multiplicity of reasons just fails to give way to allow the slips 10 or the se~ling elements 12 to relax.
If this should occur, the appalalus of the plesent invention has a backup method of removal of the packer, which is illustrated in Figures Sa-d through 7a-d.
Figure Sb shows thread 48 ntlon~ after rotation of the washover shoe 38, as previously described. Now, since the packer will not release, further rotation occurs from the position shown in Figure 4d. The lug 54 can be released with respect to the sleeve 28 by breaking the shear pin 56 if it has not already beenbroken. The tubing string 46 is then rotated to undo thread 60. This leaves ring58, as well as lug 54, resting on shoulder 82, as shown in Figure Sd. With thread 60 now sep~aled as shown in Figure Sd, the pro~ ction tubing 46 can be pulled out of the hole, taking with it the ~e~mbly co~n~ g the washover shoe 38 as well as the sleeve 28.
This having been accomplished, heavy-wall tubing 83, with or without jars, can be made up at the surface and run into the hole on top of a known release tool R, as illu~ ted in Figures 7b-c. At this point in time, the ring 78 is eng~ged by the release tool R, as shown in Figure 7c. Now, with the heavy-wall tubing 83 inplace and jars, if desired, in place, further efforts applying an even greater force can be made to release the packer and retrieve it from the wellbore.
Figures 6a-d illu~ te yet another way of removing sleeve 28 from the wellbore so as to expose the ring 78 for ultimate engagement with the release tool 2~ 93290 R In Figure 6c-d, the sleeve 28 actually shears in two pieces, leaving behind a piece 28' resting on shoulder 82. The sleeve 28 is ~1P-S;~P~ to have a weak section 84 which, prior to deliberate failure, is cor~necte~ to weak section 84' such that upon an u~,w~rd force on the production tubing 46, a break occurs between S ~g~ L~i 84 and 84', as shown in Figure 6d. In this ~ltern~tive de-~i~, shear pin 56 breaks first and the connection between weak sections 84 and 84' fails after the shear pin breaks, with the result that the segment 28' merely falls dowll~dly until it is caught by shoulder 82. Even in this embodiment, ring 52 can still berotated off before she~rin~ 84 from 84'.
Regardless of which technique is used as between the twist-off technique shown in Figure Sd or the shear technique in Figure 6d, the final step is to run in the hole with the retrieving tool R, which has a series of collets 86 supported by a body 88. The collets 86 are spring-loaded using a spring or springs 90. The collets 86 are deflected ~gain~t the spring 90 and flex toward the body 88 to get lS past the ring 78. After pPC~ing the ring 78, the assembly is picked up and the collets 86 are trapped ~gainct body 88 as shown in Figure 7c. Upward pulling on the heavy-wall tubing or use of the jar combined with u~d pulling ultimately results in the retrieval of the packer.
Those skilled in the art can readily see that a packer design has been pro-20 vided which allows for release with the production tubing without an extra trip into the wellbore. Hu..~ ~, if the release t~ht~ ue using the production tubing 46 proves ineffective to liberate the packer from the wellbore, a bafflp release technique is provided. The production tubing 46 must be removed from the wellbore. Ho~ , such removal effectively takes with it sufficient components 25 so as to expose the lug or ring 78 so that on a second trip with heavy-wall tubing and/or jar eq~ ment~ the lug 78 can be .~c~s.ce~ for even greater applied forces than could be applied using the production tubing 46. While a second trip into the wellbore is required if the production tubing 46 does not dislodge the.packer, o~r~to.~ can have greater confidenr~ in the removability of their parl~P-r~ by knowing that a backup terhnique for removal of the packer exists. Thus, e~peneive S and time-co ~Q- ming mi11in~ operations can be avoided since the backup technique allows the application of subst~nti~lly greater extraction forces than could be applied using the production tubing 46.
The foregoing disclosure and description of the invention are illustrative and explanatory thereof, and various c~l~nges in the size, shape and materials, as well 10 as in the details of the ill~ ted con~lluction, may be made without d~alling from the spirit of the invention.
INVENTORS: WILLIAM D. HENDERSON and JEFFREY J. LEMBCKE
FIFT r~ OF THE INVFl~ION
The field of this invention relates to retrievable parlrPre, and more particu-larly to packers that may be retrieved in more than one way.
10 BACKGROUND OF T~F T~VF~ITION
Packers are frequently used in oil and gas production to isolate one portion of a wellbore from another. After being set in a wellbore for what could be as long as many years, these p~rlr~rs need to be retrieved. Several ~ei~e have beenincorporated in the past for retrievable packers. One such packer, known as a seal-15 bore-type packer, was run in on wireline. After setting the packer on wireline, tubing was run and cf~nnecte~l to the packer by means of an anchor. In order to retrieve this type of packer, the pro~lucfiQn tubing had to be ii.eco~n~cte~l from the packer and removed from the wellbore. A sep~ale trip into the wellbore was then required with a speci~lly designed retrieving tool that released the mech~nieme 20 within the packer to allow it to be unset and retrieved. Since the additional run of tubing was made with hca~vyweight drillpipe with or without jars, which allowed for tensile loads higher than the st~nd~rd production tubing, these types of packers were often used and easily retrieved. Often these packers, after reln~ining in the wellbore for many years, required the additional tensile loads that could be applied 25 through the heavy-wall tubing in combination with jars. These high-tensile loads were l~ecess~.~ due to parts corroding together or debris settling out around the packer. While this type of design allowed for retrieval, it was only at the expense of running the heavy-wall tubing into the hole on a separate run. Typical of such 2 1 932qO
packers are par~P-rs made by Baker Oil Tools under Product No. 646, also called RETRIEVA-D; RETRIEVA-DB; and RETRIEVA-DAB LOCK-SET retrievable packers.
Another type of packer previously used is referred to as a modified tubing-set packer. This particular type of packer could be set on a wireline. Part of the Pe,eembly of the packer included a seal nipple and an on/off tool. These compo-nents were connP~ted to the packer mandrel above the packer and were left in thewell when the packer was set. The production tubing was then run in and eng~ged with the on/off tool seal nipple. The packer was retrieved by manip~ ting the tubing in combination with rotation and tension to release the packer. The packer was then retrieved on the production tubing. While this technique was desirable beca~ee it did not le~lui~c an additional tubing run, as indicated with the previously descAbed seal-bore-type pac~Pre~ such pac~Pre have been found to be less reliable when it comes to retAeval than the seal-bore pae~P-rs, pAmaAly due to the tensile limits of the pro~uction tubing string, the on/off tool, and the packer mandrel.Typical of such ~es~Pmblies of the modified tubing-set packer are a wireline-setUni-Packer VI made by Guiber.eon ~VA, a division of Dresser Tn-lnstries. Nippleswhich convert perm~nPnt or retAevable pacl~Prs into t,lnpol~r bridge plugs and which are carried in with the packer when it is set are known in the art and onesuch product is made by Baker Oil Tools, Model RS, Product No. 66548 Seffln~
Nipple.
Ac~ordiJlgly, an objective of the preselll invention is to provide a packer or bridge plug which can be tubing-rele~ce~l but if such mode of release for any reason does not function to release the packer or bridge plug, a back-up method of release with a rele~eing tool is also available for the same packer. The alterna-tive method of release functions akin to the operation of the seal-bore-type pac~e-rs and requires the ad~liti~m~l run into the wellbore with heavy-wall tubing to be used. Accoldil~gly, the objective of the invention is to give a greater confi~len~
level to operators beyond that previously e~ri~on~ed with using only a modified tubing-set packer. Now, with the plesent invention, if the modified tubing-set packer with the production tubing string fails to release, an ~ltçnl~tive release me~h~ m is available.
SUMMA~Y OF THF INVF~TION
A packer or bridge plug is described which may be released by manipulation of the produr,tion tubing conr~ted to it. If manipulation of the production tubing is rncllcc~s~irul in rele~cing the packer, the tensile strength of the production tubing need not be excee~led in attempting to remove the packer. Tn~tead the productiontubing is removed along with certain intern~l compollents of the packer. Thereaf-ter, heavy-wall tubing, with or without jars, can be lowered into the wellbore with a retrieving tool at the bottom of that string. The lehiGvillg tool latches onto com-poll~n~ of the packer to allow an ~ltçr l~tive method of release which allows for use of significantly higher tensile loads to liberate the packer from the wellbore.
nFT~n~Fn nF~CRlPIlON OF TE~F n~WI~GS
Figures la-d illustrate the packer of the preselll invention in the run-in position.
Figures 2a-d illu~hate the packer in the set position.
Figures 3a-d illu~h~te the packer in the set position with the washover shoe of the on/off tool latched into a J-slot.
Figures 4a-d illustrate the fully retrieved position using the washover shoe of the on/off tool latched into the l-slot.
Figures 5a-d illustrate the tool in the set position after rotation off of the lower end of the mandrel.
Figures 6a-d are similar to the view of Sa-d except showing the mandrel sheared.
Figures 7a-d show the ~lt~Prn~tive retrieval using a retrieving tool.
nFT~l~ Fn nF~CRTPllON OF T~F pRFFFRRFn Fl~RODIl~IF~T
Referring to Figures la-d, the app&,alus of the lJles~nt invention is illus-trated. Since many of the fealules of the packer are st~n~l~rd collll~onents, they will 10 be described only very briefly. Packers or bridge plugs generally have a series of slips 10 and se~ling elements 12. The slips 10 anchor the packer, while the sc~ling elements 12 seal off around the periphery. The slips 10 are cammed outwardly along ta~red s~ ec 14, while the s~P~ling elements 12 e~p~n~l radially oulw~dly by beco.lling comp.essed between rings 16 and 18. Ring 18 is connectP~ to a set-15 ting sleeve 20. A setting tool S of the type well-known in the art has components that move in opposile directions to create the nec~P-ss~ relat*e movement to urge the slips 10 along the tapered snrf~c~e 14, followed by the setting of the sealing elemP-nte 12 as rings 16 and 18 approach each other.- A lock ring 22 holds the set of the e~ling elements 12 after co.llples~ion has oc~ulled, as seen by co.~-p~ g20 Figure lc to Figure 2c. The setting tool S has a du~lw~dly moving sleeve 24, which bears on setting sleeve 20 but is otherwise not physically connect~P~ thereto.
Another pOniOn of the setting tool S includes a sleeve 26 which is secured to a mandrel 28 by a shear pin 30. Sup~lled by mandrel 28 is a known b1~nlcing plug 32 which is run in with the entire ~sembly so as to seal off an internal bore 34 in 25 the packer, using seal 36.
2 1 ~3290 Not shown in the drawings is the wireline ~uppoll for the setting tool S
which allows the proper positioning of the packer in the wellbore. The setting tool S is ~stn~t~P~ in known ways to create dirr~.enlial movement between sleeves 24 and 26 such that sleeve 24 moves dow-l~dly, while sleeve 26 moves u~v~dly 5 to ac~omplish the setting~ as indicated by the arrows in Figure 2a. This dilr~ nlial movement cams the slips 10 oulw~-dly~ as shown in Figure 2c. C~ntinl~P~ differ-ential movement brings rings 16 and 18 closer together, while the lock ring 22, using r~trheting teeth 23, retains the position of all the components, as shown in Figure 2c. Shear pin 30 is sheared after full setting force is applied. This allows 10 the setting tool S to be removed. At this point, the setting tool S can be removed and the pro-luction tubing run in the hole, coupled with a washover shoe 38 (seeFigure 3a). The washover shoe 38 has a J-slot arrangement 40 which latches onto lug 42, which is part of the mandrel ~c.cernbly 28. It can also be secured by other means. Seals 44 effectively seal between the washover shoe 38 and the mandrel 15 28. Once that task is ac~omplished, the bl~nking plug 32 is removed by wireline.
It should be noted that the production tubing 46 :iUppOlk~ the washover shoe 38 until the J-slot 40 c~tchP~ the lug 42. At that time, the production tubing string 46 is sP~lin~ly engaged to the mandrel 28 and, upon removal of the bl~nking plug32, production through the packer P can commPnce in a known ...~ -r.
When it comes time to release the packer, Figures 4a-d illu~llale one tech-nique. In this technique, a rotational forc~ is applied to the production tubing 46.
This rotation undoes thread 48, which is shown in Figure 4b already s~ aled.
With thread 48 un~1onP., an u~v~d force is applied on the producti~ tubing 46, brin~ing up mandrel 28. Packer mandrel 29 is ret~inP~l in a fi~ed position due to m~ting teeth 72 and 74. At its lower end 52, mandrel segment or sleeve 28 has a lug 54 which is secured to sleeve 50 by shear pin 56. Below lug 54 is ring 58, which is c~m~-cte~l to sleeve 28 at thread 60.
As shown in Figure 3d, the set position of the slips 10 and se~ling elements 12 is also lel~ ~l by collet fingers 70, which have teeth 72 which engage teeth 74 S on bottom sub 76. The position of the fingers 70 is secured by a ring 78 which is secured to the fingers 70 by a shear pin 80. Those skilled in the art will a~ple~;iate that a multiplicity of fingers 70, each with teeth 72, are employed, all of which engage the teeth 74 on the bottom sub 76.
Referring now to Figure 4d, it can be seen that after the thread 48 is undone and an u~w~J pull is applied to the tubing string 46, lug 54 bears on ring 78 toultimately break shear pin 80. When shear pin 80 breaks, the ring 78 can move u~w~dly, thus allowing the fingers 70 to flex radially inwardly so as to allow the teeth 72 to sep~ate from the teeth 74. When this occurs, the ~esemhly that holdsthe slips 10 and the se~ling ele.m~-nt 12 in a co.,-~leseed state can be e~tPn~le~l by 15 c~ g the u~,w~d pull on the production string 46.
Ultimately, as shown in Figure 4c, the slips 10 ride down the tapered s~R~e 14 and are retracted. A co~ u~w~ pull on the production string 46 will move ring 18 away from ring 16 to allow the sealing elements 12 to relax to the poeitinln shown in Figure lc. As shown in Figure 4c, the fingers 70 have had their 20 teeth 72 move completely away from the interengAging teeth 74 as a result of the breaking of shear pin 80. Lug 54 then ~uppolls ring 78 when there is further u~w~d pulling on the production string 46. Ring 78 is shaped so that it cannot fall off of fingers 70, even after shear pin 80 is broken bec~se it c~tclle~e shoulder 81.
With lug 54 in contact with ring 78, the entire weight of the packer shifts to the 25 production string 46 and it can then be removed, ~ .n~ g that no complications develop.
2 i 93290 However, esreci~lly for paCL-~re that have been in the wellbore for many years, the motions previously described may not be sufficient to release the packer from the wellbore. Thus, despite the undoing of thread 48 and the exertion of anu~d force within the limits of the tensile loads which can be applied through S the production tubing 46, the assembly for a multiplicity of reasons just fails to give way to allow the slips 10 or the se~ling elements 12 to relax.
If this should occur, the appalalus of the plesent invention has a backup method of removal of the packer, which is illustrated in Figures Sa-d through 7a-d.
Figure Sb shows thread 48 ntlon~ after rotation of the washover shoe 38, as previously described. Now, since the packer will not release, further rotation occurs from the position shown in Figure 4d. The lug 54 can be released with respect to the sleeve 28 by breaking the shear pin 56 if it has not already beenbroken. The tubing string 46 is then rotated to undo thread 60. This leaves ring58, as well as lug 54, resting on shoulder 82, as shown in Figure Sd. With thread 60 now sep~aled as shown in Figure Sd, the pro~ ction tubing 46 can be pulled out of the hole, taking with it the ~e~mbly co~n~ g the washover shoe 38 as well as the sleeve 28.
This having been accomplished, heavy-wall tubing 83, with or without jars, can be made up at the surface and run into the hole on top of a known release tool R, as illu~ ted in Figures 7b-c. At this point in time, the ring 78 is eng~ged by the release tool R, as shown in Figure 7c. Now, with the heavy-wall tubing 83 inplace and jars, if desired, in place, further efforts applying an even greater force can be made to release the packer and retrieve it from the wellbore.
Figures 6a-d illu~ te yet another way of removing sleeve 28 from the wellbore so as to expose the ring 78 for ultimate engagement with the release tool 2~ 93290 R In Figure 6c-d, the sleeve 28 actually shears in two pieces, leaving behind a piece 28' resting on shoulder 82. The sleeve 28 is ~1P-S;~P~ to have a weak section 84 which, prior to deliberate failure, is cor~necte~ to weak section 84' such that upon an u~,w~rd force on the production tubing 46, a break occurs between S ~g~ L~i 84 and 84', as shown in Figure 6d. In this ~ltern~tive de-~i~, shear pin 56 breaks first and the connection between weak sections 84 and 84' fails after the shear pin breaks, with the result that the segment 28' merely falls dowll~dly until it is caught by shoulder 82. Even in this embodiment, ring 52 can still berotated off before she~rin~ 84 from 84'.
Regardless of which technique is used as between the twist-off technique shown in Figure Sd or the shear technique in Figure 6d, the final step is to run in the hole with the retrieving tool R, which has a series of collets 86 supported by a body 88. The collets 86 are spring-loaded using a spring or springs 90. The collets 86 are deflected ~gain~t the spring 90 and flex toward the body 88 to get lS past the ring 78. After pPC~ing the ring 78, the assembly is picked up and the collets 86 are trapped ~gainct body 88 as shown in Figure 7c. Upward pulling on the heavy-wall tubing or use of the jar combined with u~d pulling ultimately results in the retrieval of the packer.
Those skilled in the art can readily see that a packer design has been pro-20 vided which allows for release with the production tubing without an extra trip into the wellbore. Hu..~ ~, if the release t~ht~ ue using the production tubing 46 proves ineffective to liberate the packer from the wellbore, a bafflp release technique is provided. The production tubing 46 must be removed from the wellbore. Ho~ , such removal effectively takes with it sufficient components 25 so as to expose the lug or ring 78 so that on a second trip with heavy-wall tubing and/or jar eq~ ment~ the lug 78 can be .~c~s.ce~ for even greater applied forces than could be applied using the production tubing 46. While a second trip into the wellbore is required if the production tubing 46 does not dislodge the.packer, o~r~to.~ can have greater confidenr~ in the removability of their parl~P-r~ by knowing that a backup terhnique for removal of the packer exists. Thus, e~peneive S and time-co ~Q- ming mi11in~ operations can be avoided since the backup technique allows the application of subst~nti~lly greater extraction forces than could be applied using the production tubing 46.
The foregoing disclosure and description of the invention are illustrative and explanatory thereof, and various c~l~nges in the size, shape and materials, as well 10 as in the details of the ill~ ted con~lluction, may be made without d~alling from the spirit of the invention.
Claims (17)
1. A method of setting and releasing a packer downhole, comprising:
running in a packer to a desired depth;
setting at least one slip;
setting at least one sealing element;
locking the set of said sealing element with a locking assembly;
attaching production tubing to the packer;
moving a mandrel in the packer with said production tubing;
providing a first mode of release as a result of shifting said mandrel which unlocks said locking assembly;
removing said production tubing;
providing access to said locking assembly by said removal of said production tubing; and defeating said locking assembly by alternate means as a second mode of release for the packer.
running in a packer to a desired depth;
setting at least one slip;
setting at least one sealing element;
locking the set of said sealing element with a locking assembly;
attaching production tubing to the packer;
moving a mandrel in the packer with said production tubing;
providing a first mode of release as a result of shifting said mandrel which unlocks said locking assembly;
removing said production tubing;
providing access to said locking assembly by said removal of said production tubing; and defeating said locking assembly by alternate means as a second mode of release for the packer.
2. The method of claim 1, wherein providing said second mode of release further comprises:
removing said production tubing with sufficient portions of said mandrel to provide access to said locking assembly;
reengaging said locking assembly with a release tool supported by more rigid tubing than said production tubing; and defeating said locking assembly for removal of the packer.
removing said production tubing with sufficient portions of said mandrel to provide access to said locking assembly;
reengaging said locking assembly with a release tool supported by more rigid tubing than said production tubing; and defeating said locking assembly for removal of the packer.
3. The method of claim 2, further comprising:
providing at least one locking collet on said mandrel as a part of said locking assembly securing said mandrel to the packer body to hold the set of said slip and sealing element; and providing a lock ring to selectively secure said collet to the packer body.
providing at least one locking collet on said mandrel as a part of said locking assembly securing said mandrel to the packer body to hold the set of said slip and sealing element; and providing a lock ring to selectively secure said collet to the packer body.
4. The method of claim 3, further comprising:
disconnecting at least a portion of said mandrel from said packer body while said disconnected portion of said mandrel is supported by said production tubing;
engaging said lock ring with said disconnected portion of said man-drel; and attempting to move said lock ring and the remaining portions of said mandrel to secure the release of the packer with said production tubing.
disconnecting at least a portion of said mandrel from said packer body while said disconnected portion of said mandrel is supported by said production tubing;
engaging said lock ring with said disconnected portion of said man-drel; and attempting to move said lock ring and the remaining portions of said mandrel to secure the release of the packer with said production tubing.
5. The method of claim 4, further comprising:
providing a detachable abutment on said disconnected portion of mandrel to engage said lock ring;
selectively releasing said abutment if a predetermined force on said production tubing has failed to release the packer; and removing said mandrel which clears past said lock ring as a result of releasing said abutment.
providing a detachable abutment on said disconnected portion of mandrel to engage said lock ring;
selectively releasing said abutment if a predetermined force on said production tubing has failed to release the packer; and removing said mandrel which clears past said lock ring as a result of releasing said abutment.
6. The method of claim 5, further comprising:
releasing said abutment by rotation of said mandrel.
releasing said abutment by rotation of said mandrel.
7. The method of claim 5, further comprising:
releasing said abutment by shearing off a portion of said mandrel supporting said abutment.
releasing said abutment by shearing off a portion of said mandrel supporting said abutment.
8. The method of claim 5, further comprising:
engaging said lock ring with said release tool after failing to secure removal of the packer with said abutment on said mandrel.
engaging said lock ring with said release tool after failing to secure removal of the packer with said abutment on said mandrel.
9. A releasable packer for use in a wellbore, comprising:
a body;
at least one slip on said body;
at least one sealing element on said body;
a mandrel selectively movable with respect to said body;
a locking assembly to secure at least a first portion of said mandrel to said body for securing the setting of the slip and sealing element;
the remaining second portion of said mandrel movable to selectively engage said locking assembly for defeat thereof as a first mode of release of the packer; and said second portion of said mandrel removable from said body to allow insertion of a release tool to engage said locking assembly as a second mode of release in the event a force of a predetermined value on said second portion of said mandrel fails to release the packer.
a body;
at least one slip on said body;
at least one sealing element on said body;
a mandrel selectively movable with respect to said body;
a locking assembly to secure at least a first portion of said mandrel to said body for securing the setting of the slip and sealing element;
the remaining second portion of said mandrel movable to selectively engage said locking assembly for defeat thereof as a first mode of release of the packer; and said second portion of said mandrel removable from said body to allow insertion of a release tool to engage said locking assembly as a second mode of release in the event a force of a predetermined value on said second portion of said mandrel fails to release the packer.
10. The packer of claim 9, wherein:
said locking assembly further comprises at least one collet on said first portion of said mandrel and a lock ring to secure a locked position of said collet; and said first and second portions of said mandrel movable unitarily to secure said collet in a position where said slip and sealing element are secured in the wellbore.
said locking assembly further comprises at least one collet on said first portion of said mandrel and a lock ring to secure a locked position of said collet; and said first and second portions of said mandrel movable unitarily to secure said collet in a position where said slip and sealing element are secured in the wellbore.
11. The packer of claim 9, wherein:
said first portion of said mandrel remains fixed by said collet and said second portion movable after detachment for selective engagement with said lock ring;
whereupon application of a sufficient force to said lock ring through said second portion of said mandrel, said collet becomes unsupported and first mode of release can be achieved.
said first portion of said mandrel remains fixed by said collet and said second portion movable after detachment for selective engagement with said lock ring;
whereupon application of a sufficient force to said lock ring through said second portion of said mandrel, said collet becomes unsupported and first mode of release can be achieved.
12. The packer of claim 11, wherein:
said second portion of said mandrel comprises an abutment selectively engageable with said lock ring, said abutment selectively detachable from said mandrel.
said second portion of said mandrel comprises an abutment selectively engageable with said lock ring, said abutment selectively detachable from said mandrel.
13. The packer of claim 12, wherein:
said abutment is detachable by rotating said second portion of said mandrel.
said abutment is detachable by rotating said second portion of said mandrel.
14. The packer of claim 12, wherein:
said abutment is detachable by shearing off said abutment from said second portion of said mandrel.
said abutment is detachable by shearing off said abutment from said second portion of said mandrel.
15. The packer of claim 12, wherein:
said mandrel, without said abutment, can clear past said lock ring for removal thereof from said body;
whereupon said lock ring is accessible by insertion of a removal tool as a second mode of releasing the packer.
said mandrel, without said abutment, can clear past said lock ring for removal thereof from said body;
whereupon said lock ring is accessible by insertion of a removal tool as a second mode of releasing the packer.
16. The packer of claim 11, wherein:
said second portion of said mandrel is supported by a production tubing string;
whereupon if application of a predetermined force on said production string fails to secure release of the packer, said production string with said second portion of said mandrel less said abutment is removable from the wellbore.
said second portion of said mandrel is supported by a production tubing string;
whereupon if application of a predetermined force on said production string fails to secure release of the packer, said production string with said second portion of said mandrel less said abutment is removable from the wellbore.
17. The packer of claim 16, wherein:
said release tool is supported by a tubing string of a heavier wall than said production tubing to allow application of a greater extractive force through said lock ring than was possible with said production tubing.
said release tool is supported by a tubing string of a heavier wall than said production tubing to allow application of a greater extractive force through said lock ring than was possible with said production tubing.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US58521495A | 1995-12-18 | 1995-12-18 | |
| US08/585,214 | 1995-12-18 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2193290A1 true CA2193290A1 (en) | 1997-06-19 |
Family
ID=24340490
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA 2193290 Abandoned CA2193290A1 (en) | 1995-12-18 | 1996-12-18 | Packer with back-up retrieving method |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2193290A1 (en) |
-
1996
- 1996-12-18 CA CA 2193290 patent/CA2193290A1/en not_active Abandoned
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| FZDE | Dead |