Patent Document

PRIORITY CLAIM 
   This application is a divisional application claiming priority from U.S. patent application Ser. No. 10/944,322, filed on Sep. 17, 2004, which is a divisional application claiming priority from U.S. patent application Ser. No. 10/456,271, filed on Jun. 6, 2003, now U.S. Pat. No. 7,044,231, which is a divisional application claiming priority from U.S. patent application Ser. No. 10/117,521, filed on Apr. 5, 2002, which claims the benefit of U.S. Provisional Application No. 60/344,314, filed on Dec. 20, 2001. 

   FIELD OF THE INVENTION 
   The field of this invention relates to packers and more particularly to packers that can be set by expansion and more particularly incorporating an anchoring feature to engage the surrounding tubular upon physical expansion of the packer. 
   BACKGROUND OF THE INVENTION 
   Traditional packers comprised of a sealing element having anti-extrusion rings on both upper and lower ends and a series of slips above or/and below the sealing element. Typically a setting tool would be run with the packer to set it. The setting could be accomplished hydraulically due to relative movement created by the setting tool when subjected to applied pressure. This relative movement would cause the slips to ride up cones and extend into the surrounding tubular. At the same time, the sealing element would be compressed into sealing contact with the surrounding tubular. The set could be held by a body lock ring, which would prevent reversal of the relative movement, which caused the packer to set in the first instance. 
   As an alternative to pressure through the tubing to the setting tool to cause the packer to set, another alternative was to run the packer in on wire line with a known electrically operated setting tool such as an E-4 made by Baker Oil Tools. In this application, a signal fires the E-4 causing the requisite relative movement for setting the packer. Some of these designs were retrievable. A retrieving tool could be run into the set packer and release the grip of the lock ring so as to allow a stretching out of the slips back down their respective cone and for the sealing element to expand longitudinally while contracting radially so that the packer could be removed from the well. 
   In the past, sealing has been suggested between an inner and an outer tubular with a seal material in between. That technique, illustrated in U.S. Pat. No. 6,098,717, required the outer tubular or casing to be expanded elastically and the inner tubular to be expanded plastically. The sealing force arose from the elastic recovery of the casing being greater than the elastic recovery of the inner tubular, thus putting a net compressive force on the inner tubular and the seal. Other expansion techniques, described in U.S. Pat. Nos. 5,348,095; 5,366,012; and 5,667,011 simply related to expansion of slotted tubulars, serving as a liner in open hole, as a completion technique. U.S. Pat. No. 4,069,573 illustrates the use of expansion to form a tubular casing patch. 
   The present invention relates to packers that can be expanded into sealing position. The surrounding tubular does not need to be expanded to set the packer of the present invention. Rather, an anchor such as slips is used to support the expanded sealing element and hold it in a set position. Preferably, existing setting tools, with minor modifications can be used to expand the packer of the present invention. Similarly releasing tools can be employed to remove the packer from its set position. The running string can be exposed to lower pressures than the packer through the use of pressure intensifiers. The expansion force can be pinpointed to the area of the packer, thus avoiding subjecting the formation or the running string to undue pressures during setting of the packer. Alternatively, the inner tubular may simply be an anchor for another tool or a liner string. The anchoring can be ridges on the exterior of the inner tubing directly or on a ring mounted over the inner tubular being expanded. The ring can be slotted to reduce the required expansion force. 
   The setting tool can be delivered through tubing on slick line or wire line or run into the well on rigid or coiled tubing or wire line, among other techniques. The release tool can be likewise delivered and when actuated, stretches the packer or anchor out so that it can be removed from the wellbore. Conventional packers, that have their set held by lock rings, can be released with the present invention, by literally pushing the body apart as opposed to cutting it downhole as illustrated in U.S. Pat. No. 5,720,343. 
   These and other advantages of the present invention will be more readily understood from a review of the description of the preferred embodiment, which appears below. 
   SUMMARY OF THE INVENTION 
   An expandable packer or anchor is disclosed. It features a gripping device integral to or mounted in a sleeve over the mandrel. Upon expansion, a sealing element engages an outer tubular and the gripping device, such as wickers on slips, preferably digs into the outer tubular. The expansion is preferably by pressure and can incorporate pressure intensifiers delivered by slick line or wire line. Release is accomplished by a release tool, which is delivered on slick line or wire line. It stretches the anchor or packer longitudinally, getting it to retract radially, for release. The release tool can be combined with packers or anchors that have a thin walled feature in the mandrel, to release by pulling the mandrel apart. 

   
     BRIEF DESCRIPTION OF THE DRAWINGS 
       FIG. 1  is a section through the packer of the present invention in the run in position; 
       FIG. 2  is the view of  FIG. 1  with the packer in the set position; 
       FIG. 3  is an outside view of the packer showing the slips on a ring with recesses; 
       FIGS. 4   a – 4   d  show the packer schematically prior to expansion using a pressure intensifier; 
       FIGS. 5   a – 5   d  show the packer of  FIGS. 4   a – 4   d  in the set position with the through tubing pressure intensifier removed; 
       FIGS. 6   a – 6   b  show schematically how force is to be applied to release the packer; 
       FIGS. 7   a – 7   b  show the released position of the packer after applying the forces shown in  FIGS. 6   a – 6   b;    
       FIGS. 8   a – 8   b  show one version of a release tool for the packer where the release tool is tubing delivered to latch to the top of the packer; 
       FIGS. 9   a – 9   b  show a through tubing release tool, which can be delivered on wire line or slick line; 
       FIGS. 10   a – 10   d  show a packer with a mandrel having a thin wall segment with a release tool inserted through tubing and the packer in the set position; 
       FIGS. 11   a – 11   d  show the packer of  FIGS. 10   a – 10   d  in the released position. 
       FIGS. 12   a – 12   e  show the packer run in with a wire line or hydraulic setting tool in the run in position; 
       FIGS. 13   a – 13   e  show the packer of  FIGS. 12   a – 12   e  in the set position with the setting tool released. 
   

   DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT 
   Referring to  FIG. 1 , the packer P has a mandrel  10  with an upper thread  12  and a lower thread  14 . Upper slip ring  16  attaches at thread  12  and has extending slips  18 . As shown in  FIG. 3 , slips  18  are fingers of preferably metal separated by slots  34 . One purpose of the slots  34  is to decrease resistance to expansion. Another is to allow the wickers  32  to be hardened. If the slips were to be continuous and have hardened wickers  32 , the brittleness would cause the slips to crack on expansion. Lower slip ring  20  attaches at thread  14  and has finger like slips  22  extending from it. Slips  18  and  22  each have wickers or some other surface sharpness  32  designed to dig in for a supporting bite into the casing C upon expansion of the mandrel  10 . A sealing element  24  having backup rings  26  and  28  is disposed between slips  18  and  22 . Those skilled in the art will appreciate that the slips  18  and  22  can be formed as an integral part of the mandrel, thus eliminating the threads  12  and  14  as well as the rings  16  and  20 . In that event, the slips  18  and  22  can be a series of finger shaped protrusions from the outer surface of the mandrel  10 . These protrusions can be integral, welded, or attached in some other way. Although a packer has been described, the sealing element  24  can be eliminated and the slips  18  and  22 , regardless of how they are attached, can be used to anchor a tubing string (not shown) or a tool (not shown) attached to the mandrel  10 , when the wickers  32  dig into the surrounding casing C. Conceivably, the expansion of the wickers  32  into the casing or outer tubular C can accomplish not only a support function but also a sealing function. Sealing is possible without having to appreciably expand the casing C or even without expanding the casing C at all. The invention can be effective with a single or multiple rings of slips, regardless of their attachment mode, and with a variety of known designs for the sealing element  24 . 
   The clear advantage of the present invention is that cones are not required to drive the slips outwardly. This means that for a given outside diameter for run in, the packer or anchor P of  FIG. 1  will have a larger internal bore diameter than a design relying on cones to ramp slips out. The larger bore possible in the mandrel  10  comes with no significant reduction of the pressure rating of the packer P. 
   The wickers  30  and  32  are preferably hardened to facilitate penetration into the casing. The sealing element  24  is preferably Nitrile but can also be made from other materials such as Teflon or PEEK. The backup rings  26  and  28  are preferably ductile steel and serve the function of keeping the sealing element  24  out of the slots  34  between the slips  18  and  22 . Rather than slots  34  to facilitate expansion of the slips  18  and  22 , the sleeve that holds the slips can be made thinner or have other openings, such as holes, to reduce its resistance to expansion. The expansion itself can be carried out with known expansion tools such as roller expanders, swages, or cones. Alternatively, an inflatable can be used to expand the mandrel  10  or a pressure technique, as illustrated in  4   a – 4   d ,  5   a – 5   d ,  12   a – 12   e ,and  13   a – 13   e.    
     FIGS. 4   a – 4   d  illustrate a thru-tubing approach to setting where either a slick line or a wire line can be used to deliver a pressure intensifier  36  to a desired position where it will latch in the tubing  37  adjacent the packer or anchor P. The packer or anchor P is illustrated schematically as is the connection at the top of the intensifier  36 . Pressure applied into tubing  37  enters ports  39  and  40 . Pistons  42 ,  44 , and  46  are connected together for tandem movement. Pressure from ports  39  and  40  enters cavities  48  and  50  to apply downward forces on pistons  42 ,  44 , and  46 . Additional pistons can be used for greater force amplification. The use of intensifier  36  allows a lower pressure to be used at the wellhead in case it has a low pressure rating and the expansion force desired at the packer or anchor P exceeds the rated wellhead pressure. Downhole movement of piston  46  forces fluid out of port  52  to expand the packer or anchor P. The intensifier  36  is retrieved after expansion with a known fishing tool, which engages a fishing neck in the top of the intensifier. As shown in  FIGS. 5   a – 5   d , the packer or anchor P is set against tubular or casing C and the intensifier is removed from the tubing  37 . 
   Another way to deliver and set the packer or anchor P is shown in  FIGS. 12   a – 12   e  and  13   a – 13   e . In these figures the packer or anchor P is delivered on a hydraulic or wire line setting tool, as opposed to the through-tubing techniques previously described. The setting tool is schematically illustrated to cover the use of both hydraulic or wire line setting. A sleeve  54  abuts the top of the packer or anchor P ( FIG. 12   d ). A gripping sleeve  56  retains the packer or anchor P until the shear stud  58  fails. Circulation is possible when using the hydraulic setting tool until an object is dropped to allow pressure buildup to ultimately move piston  60  to set the packer or anchor P. Upward movement of the piston  60  breaks the shear stud  58  after delivering the required pressure for expansion through port  62  to the packer or anchor P. The hydraulic setting tool can incorporate pressure intensifiers so as to limit the surface pressure applied to get the desired expansion, in the event the wellhead has a low pressure rating. Breaking the shear stud  58  allows removal of the setting tool and a subsequent tagging the packer with production tubing. The pressure intensifier can have more or fewer pistons to get the desired pressure amplification. Hydrostatic pressure can be employed to do the expanding instead of or in conjunction with surface applied pressure. Various ways can be used to connect the tubing to the packer. The expansion tool can be released from the packer by rotation. Known setting tools can be employed such as those made by Baker Oil Tools under model numbers BH, BHH, B-2 and J with only slight adaptations. 
   In a wire line variation, the setting tool would be electrically actuated to set off an explosive charge to create the needed pressure for expansion of the packer or anchor P in the manner previously described with the possibility of integrating a pressure intensifier. Once the packer or anchor P is expanded, an automatic release from the setting tool occurs so that it could be removed. Known wire line setting tools like the E-4 made by Baker Oil Tools can be used, or others. The expansion concept is the same, stroking a piston with a pressure source and, if necessary a pressure intensifier, creates the pressure for expansion of the packer or anchor P to expand it into position against the tubular or casing C and to trigger an automatic release for retrieval of the settling tool. After the setting tool is pulled out, tubing is tagged into the expanded packer or anchor. 
   Release of the packer or anchor P is schematically illustrated in  FIGS. 6   a – 6   b . The technique is longitudinal extension as illustrated by opposed arrows  64  and  66 . This longitudinal extension results in radial contraction, shown schematically as arrow  68 . What actually occurs is that the wickers  30  and  32  (shown in  FIG. 1 ), which had dug into the casing C on expansion, are pulled or sheared out of the casing. The longitudinal extension also draws back the sealing element  24  as the mandrel under it radially contracts.  FIGS. 7   a – 7   b  show the released position. 
   One way to accomplish the release as described above is shown in  FIGS. 8   a – 8   b . The release tool  70  is run into the well after the production tubing is pulled. It is secured downhole to the packer at connection  72 , which can be a variety of configurations. A ball seat  74  is retained by shear pins  76  and accepts a ball  78  dropped from the surface. Built up pressure pushes down of piston  80  and piston  82  through port  84 . Piston  80  bears down on piston  82 . Piston  82  bears on shoulder  86  on the packer or anchor P. Thus the packer or anchor P is subjected to a longitudinal extension from an uphole force at connection  72  and a downhole force at shoulder  86 . The resulting radial retraction allows removal of the packer or anchor P with the tubing  72 . 
     FIGS. 9   a – 9   b  show a thru-tubing variation of the release technique. The release tool  88  can be run in on slick line or wire line to latch into latch  90 . Pressure is developed on pistons  92 ,  94 , and  96 . Ports  98  and  100  allow access to pistons  94  and  96  respectively. Piston  92  bears on piston  94 , which in turn bears on piston  96 . Piston  96  rests on shoulder  102  on the anchor or packer P while the other end of the release tool  88  is latched at latch  90 . Ports  104  and  106  allow pistons  92  and  94 , respectively to move by allowing fluid to pass. Accordingly, applied pressure in tubing  108  or generated pressure from an electric line setting tool such as an E-4 made by Baker Oil Tools, stretches the packer or anchor P to get the slips  18  and  22  (see  FIG. 1 ) to let go of their grip of the tubular or casing C in the manner previously described. 
     FIGS. 10   a – 10   d  and  11   a – 11   d  show a packer of known construction except that it has a narrow portion  110  in its mandrel  112 . It has a sealing element  114  and slips  116  extendable with cones  118  and  120 . The set is held by a lock ring  122 . In the past, the packer could be released by releasing the lock ring by cutting the mandrel of the set packer downhole, as illustrated in U.S. Pat. No. 5,720,343. However this technique had its uncertainties due to doubts about placement of the cutter and knowledge as to if the cut was completed. The release technique for such packers of the present invention, removes such uncertainties. The release tool  122  can be run thru-tubing on slick line or wire line and latched at latch  124 . A pressure intensifier  126  of the type previously described rests on shoulder  128  of the packer or anchor P. Application of pressure from the surface or the electric line tool puts opposing forces at latch  124  and shoulder  128  until the narrow portion  110  fails in tension. This releases the hold of the set position by the lock ring  122  and allows extension and radial retraction of the slips  116  and the sealing element  114 . The break  130  is shown in  FIG. 1   d . If there are multiple packers or anchors P in the well, the process can be repeated for each one that is needed to be released. As well, the setting process can be repeated to set in any order desired, other packers or anchors P to isolate a desired zone for example. The release tool can be delivered through the production tubing or on wire line or slick line after the production tubing has been removed. 
   Other downhole tools can be expanded and extended for release in the manner described above other than packers or anchors. Some examples are screens and perforated liners. 
   The techniques described above will also allow for expansion and extension of a variety of tools more than a single time, should that become necessary in the life of the well. Extension of the downhole tool for release does not necessarily have to occur to the extent that failure is induced, as described in conjunction with  FIGS. 10 and 11 . The extension of a tool such as the packer or anchor P an embodiment of which is shown in  FIG. 1 , can allow it to be re-expanded with the variety of tools described above. 
   Tubing itself can also be expanded and extended for release using the techniques described above. 
   Although the retrieving tool has been illustrated as abutting a shoulder to obtain the extension, the shoulder can be provided in a variety of configurations or can be replaced with a gripping mechanism such as slips on the release tool. The slips could alternatively replace the latching notch while still putting a downhole force on the lower shoulder. The mandrel can also have an undercut and collets can engage the undercut to put the requisite extension force on the mandrel body. 
   Selected zones can be isolated or opened for flow with the techniques previously described. Pressure intensifiers of various designs and pressure magnifications can be used or, alternatively, no pressure magnification device can be used. 
   If the through-tubing tool is used with the explosive charge as the pressure source, then it will need to be removed and the charge replenished before it is used to expand another device in the well. The hydraulically operated through-tubing tool can simply be repositioned and re-pressurized to expand another downhole packer, tubular or other tool. 
   The various forms of the release tools can be used with conventional packers that set with longitudinal compression of a sealing element and slips with the set held by a lock ring by extending that packer to the point of mandrel or other failure, which can release the set held by the lock ring. 
   The above description is illustrative of the preferred embodiment and many modifications may be made by those skilled in the art without departing from the invention whose scope is to be determined from the literal and equivalent scope of the claims below.

Technology Category: 0