US00757l765B2
`
`(12) Ulllted States Patent
`Themig
`
`(10) Patent N0.:
`(45) Date of Patent:
`
`US 7,571,765 B2
`Aug. 11, 2009
`
`(54) HYDRAULIC OPEN HOLE PACKER
`
`(76) Inventor: Daniel Jon Themig, 52 Glenhill Drive,
`Cochrane, AB (CA) T4C 1G9
`
`6/1938 Baker
`2,121,002 A
`2,618,340 A ll/l952 Lynd
`2,715,444 A
`g/1955 Fewel
`2,731,827 A
`1/1956 Loomis
`
`*
`
`(
`
`_
`
`_
`
`) Not1ce.
`
`_
`
`_
`
`_
`
`_
`
`Subject' to any (31153121111165, the tiermgfthls
`$1518 1155222311); 0 3y: Juste un er 35
`
`2,737,244 A
`
`3/1956 Baker et a1.
`
`2/1957 Loom-S
`2,780,294 A
`2,807,955 A 10/1957 Loomis
`
`'
`
`'
`
`'
`
`'
`
`2,836,250 A
`
`5/1958 Brown
`
`(22) Filed:
`
`Mar. 28, 2008
`(Under 37 CFR 147)
`
`(65)
`
`Prior Publication Data
`US 2008/02771 10 A1
`Nov. 13,2008
`
`2,860,489 A * 11/1958 Townsend ................. .. 405/269
`3,038,542 A
`6/1962 LOOmiS
`3,054,415 A
`9/1962 Baker et a1.
`3,122,205 A
`2/1964 Brown
`3,153,845 A 10/1964 Loomis
`i
`£00K"?
`
`,
`
`,
`
`OOIIllS
`
`Related US. Application Data
`
`3,165,918 A
`
`1/1965 LOOIIliS
`
`(60) Continuation of application No. 11/ 550,863, ?led on
`Oct. 19, 2006, Which is a continuation of application
`NO. 11/104,467, ?led On Apr. 13, 2005, noW Pat. NO.
`
`_
`(Commued)
`
`
`
`7,134,505, 10/299,004, ?led on Nov. 19, 2002, noW Pat. No. 15 a division Of application NO.
`
`
`
`6,907,936.
`
`Halliburton Retrievable Service Tools, product brochure, 15 pages,
`
`1' N 60/331 491 ?l d N
`1'
`1
`'
`(60) P '
`rov1s1ona app 1ca 1on o.
`,
`,
`e on ov.
`19, 2001, provisional application No. 60/404,783,
`?led on Aug. 21, 2002.
`
`(51) Int_ CL
`(2006.01)
`E21B 23/06
`(2006.01)
`E21B 33/124
`(52) US. Cl. ....................... .. 166/191; 166/50; 166/313;
`
`277637
`_
`_
`_
`(58) Field of Classl?catlon Search ............... .. 166/ 191,
`16660’ 245’ 313’ 387’ 185’ 186; 277622’
`_
`277637’ 342’ 338
`_
`See apphcanon ?le for Complete Search hlstory'
`References Cited
`
`(56)
`
`US. PATENT DOCUMENTS
`
`undated‘
`
`(Continued)
`Primary ExamineriKenneth Thompson
`(74) Attorney, Agent, or FirmiSmith IP Services, P.C.
`
`(57)
`
`ABSTRACT
`
`A tubing string assembly is disclosed for ?uid treatment of a
`Wellbore The tubing String can be used for Staged Wellbore
`?uid treatment Where a selected segment of the Wellbore is
`treated, While other segments are sealed off. The tubing string
`can also be used Where a ported tubing string is required to be
`run in in a pressure tight condition and later is needed to be in
`an open-port condition.
`
`1,956,694 A *
`
`5/1934 Parrish ..................... .. 277/342
`
`49 Claims, 9 Drawing Sheets
`
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`US 7,571,765 B2
`Page 2
`
`US. PATENT DOCUMENTS
`
`1/1965 Loomis
`3,165,919 A
`1/1965 Loomis
`3,165,920 A
`7/1965 Loomis
`3,193,917 A
`7/1965 Loomis
`3,194,310 A
`7/1965 Loomis
`3,195,645 A
`8/1965 Loomis
`3,199,598 A
`3/1967 He?ey
`3,311,169 A
`7/1978 Hutchison et al.
`4,099,563 A
`7/1981 WeitZ
`4,279,306 A
`2/1985 Ross et al.
`4,498,536 A
`5/1985 Cochran ................... .. 166/312
`4,519,456 A *
`6/1985 Pringle
`4,520,870 A
`4,552,218 A 11/1985 Ross et al.
`4,567,944 A
`2/1986 Zunkelet al.
`4,569,396 A *
`2/1986 Brisco ................... .. 166/305.1
`4,590,995 A
`5/1986 Evans
`4,646,829 A
`3/1987 Barrington et al.
`4,657,084 A
`4/1987 Evans
`4,714,117 A * 12/1987 Dech ........................ .. 166/380
`4,716,967 A
`1/1988 Mohaupt
`4,754,812 A
`7/1988 Gentry
`4,791,992 A 12/1988 Greenlee et al.
`4,794,989 A *
`1/1989 Mills ........................ .. 166/387
`4,893,678 A
`1/1990 Stokley et al.
`4,967,841 A 11/1990 Murray
`5,103,901 A
`4/1992 Greenlee
`5,152,340 A 10/1992 Clark et al.
`5,197,547 A
`3/1993 Morgan
`5,454,430 A * 10/1995 Kennedy et al. ............ .. 166/50
`5,472,048 A 12/1995 Kennedy et al.
`5,499,687 A
`3/1996 Lee
`5,526,880 A
`6/1996 Jordan, Jr. et a1.
`5,533,573 A
`7/1996 Jordan, Jr. et al.
`5,542,473 A *
`8/1996 Pringle ..................... .. 166/120
`5,701,954 A 12/1997 Kilgore et al.
`5,775,429 A
`7/1998 AriZmendi et al.
`5,791,414 A
`8/1998 Skinner
`5,960,881 A 10/1999 Allamon et al.
`3/2000 AriZmendi ................ .. 166/187
`6,041,858 A *
`A
`4/2000 Zeltmann et al.
`6,047,773
`9/2000 Kilgore et al.
`6,112,811
`A
`6,131,663 A * 10/2000 Henley et al. ............. .. 166/373
`6,253,861 B1
`7/2001 Carmichael et al.
`6,543,545 B1
`4/2003 Chatterji et al.
`6,907,936 B2
`6/2005 Fehr
`7,134,505 B2 11/2006 Fehr
`7,198,110 B2
`4/2007 Kilgore et al.
`7,231,987 B2
`6/2007 Kilgore et al.
`2002/0162660 A1* 11/2002 Depiak et al. ............. .. 166/308
`2007/0151734 A1
`7/2007 Fehr et al.
`
`OTHER PUBLICATIONS
`
`Halliburton “Halliburton Guiberson® G-77 Hydraulic-Set Retriev
`able Packer,” 6 pages, undated.
`Baker Oil Tools, “Retrievable Packer Systems,” product brochure, 1
`page, undated.
`Drawings, Packer Installation Plan, PACK 05543, 5 pages, 1997.
`Guiberson'AVA & Dresser, Retrievable Packer Systems, “Tandem
`Packer,” 1 page, undated.
`Halliburton, “Hydraulic-Set GuibersonTM Wizard Packer®,” 1 page,
`undated.
`D.W. Thomson, “Design and Installation of a Cost-Effective
`Completion System for Horizontal Chalk Wells Where Multiple
`Zones Require Acid Stimulation,” SPE Drilling & Completion, Sep.
`1998, pp. 151-156.
`Packers Plus Energy Services, Inc. “5.1 RockSealTM 11 Open Hole
`Packer Series,” 2 pgs., dated 2004.
`Halliburton Guiberson G-77 Hydraulic-Set Retrievable Packer pre
`sentation, 6 pages, undated.
`
`Owen Oil Tools Mechanical Gun Release; 2-3/8“ & 2-7/8“ product
`description, 1 page, undated.
`Sapex Oil Tools Ltd. Downhole Completions catalog, 24 pages,
`undated.
`Halliburton, catalog, pp. 51-54, 1957.
`Baker Hughes, catalog, pp. 66-73, 1991.
`Trahan, Kevin, Af?davit, May 19, 2008.
`Trahan, Kevin, Af?davit Exhibit C, May 19, 2008.
`Trahan, Kevin, Af?davit Exhibit E, May 19, 2008.
`Trahan, Kevin, Af?davit Exhibit G, May 19, 2008.
`Baker Oil Tools, catalog, p. 29, Model “C” Packing Element Circu
`lating Washer, Product No. 470-42, Mar. 1997.
`Guiberson-AVA Dresser, catalog, front page and pp. 1 & 20, 1994.
`Baker Oil Tools, catalog, p. 38, Twin Seal Submersible Pumppacker,
`undated.
`Halliburton, Plaintiff’ s Fourth Amended Petition in Cause No.
`CV-44964, 238th Judicial District of Texas, Aug. 13, 2007.
`Packers Plus, Second Amended Original Answer in Cause No.
`CV-44964, 238th Judicial District of Texas, Feb. 13, 2007.
`Packers Plus, Original Answer in Cause No. CV-44964, 23 8th Judi
`cial District of Texas, Feb. 13, 2007.
`Guiberson AVA, Packer Installation Plan, Aug. 26, 1997.
`Guiberson AVA, Packer Installation Plan, Sep. 9, 1997.
`Guiberson AVA, Packer Installation Plan, Nov. 11, 1997.
`Guiberson AVA, Wizard 11 Hydraulic Set Retrievable Packer Tech
`Manual, Apr. 1998.
`Dresser Oil Tools, catalog, Multilateral Completion Tools Section,
`undated.
`Dresser Oil Tools, catalog, Technical Section, title page and p. 18,
`Nov. 1997.
`Berryman, William, First Supplemental Expert Report in Cause No.
`CV-44964, 23 8th Judicial District of Texas, undated.
`Brown Oil Tools, catalog page, entitled “Brown Hydraulic Set Pack
`ers,” undated.
`Brown Oil Tools, catalog page, entitled “Brown HS-16-1 Hydraulic
`Set Retrievable Packers,” undated.
`Brown Oil Tools General Catalog 1962-63, Hydraulic Set Packers
`and Hydraulic Set Retrievable Packers, pp. 870-871.
`First Supplemental Expert Report of Kevin Trahan, Case No.
`CV-44,964, 238th Judicial District, Midland County, Texas, Aug. 21,
`2008, 28 pages.
`Order of Dismissal, Case No. CV-44,964, 238th Judicial District,
`Midland County, Texas, Oct. 14, 2008, 1 page.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit 6,
`Deposition of Daniel Jon Themig, Calgary, Alberta, Canada, dated
`Jan. 17, 2006, parts 1 and 2 total for atotal of82 pages with redactions
`from p. 336, Line 10 through all ofp. 337.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit 7,
`Deposition of Daniel Jon Themig, Calgary, Alberta, Canada, dated
`Jan. 8, 2007, 75 pages with redactions from p. 716, Line 23 through
`p. 726, Line 22.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit 8,
`Deposition of Daniel Jon Themig, Calgary, Alberta, Canada, dated
`Jan. 9, 2007,46 pages with redactions on p. 850, Lines 13-19.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit 9,
`Cross-examination of Daniel Jon Themig, In the Court of Queen’s
`Bench of Alberta, Canada, dated Mar. 14, 2005, 67 pages.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit
`10, Deposition of William Sloane Muscroft, Edmonton, Alberta,
`Canada, dated Mar. 31, 2007, parts 1 and 2 for a total of 111 pages.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit
`1 1, Email from William Sloane Muscroft to Peter Krabben dated Jan.
`27, 2000, 1 page.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit
`12, Email from William Sloane Muscroft to Daniel Jon Themig dated
`Feb. 1, 2000, 1 page.
`238th District Court, Midland, Texas, Case No. CV44964, Exhibit
`13, Email from Daniel Jon Themig to William Sloane Muscroft dated
`Jun. 19, 2000, 2 pages.
`
`* cited by examiner
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`Aug. 11,2009
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`Sheet 3 of9
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`US 7,571,765 B2
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`US. Patent
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`Sheet 4 0f9
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`US. Patent
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`Aug. 11, 2009
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`US. Patent
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`Sheet 6 of9
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`US. Patent
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`Aug. 11, 2009
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`US 7,571,765 B2
`
`1
`HYDRAULIC OPEN HOLE PACKER
`
`CROSS-REFERENCE TO RELATED
`APPLICATIONS
`
`This application is a continuation of prior application Ser.
`No. 11/550,863 ?led on Oct. 19,2006 Which is a continuation
`of application Ser. No. 11/104,467 ?led on Apr. 13, 2005
`(now US. Pat. No. 7,134,505) Which is a division ofapplica
`tion Ser. No. 10/299,004 ?led onNov. 19, 2002 (now US. Pat.
`No. 6,907,936) Which claims priority to provisional applica
`tion Ser. No. 60/331,491 ?led on Nov. 19, 2001 and to pro
`visional application Ser. No. 60/404,783 ?led Aug. 21, 2002.
`The entire disclosures of these prior applications are incor
`porated herein by this reference for all purposes.
`
`FIELD OF THE INVENTION
`
`The invention relates to a method and apparatus for Well
`bore ?uid treatment and, in particular, to a method and appa
`ratus for selective communication to a Wellbore for ?uid
`treatment.
`
`20
`
`BACKGROUND OF THE INVENTION
`
`An oil or gas Well relies on in?oW of petroleum products.
`When drilling an oil or gas Well, an operator may decide to
`leave productive intervals uncased (open hole) to expose
`porosity and permit unrestricted Wellbore in?oW of petro
`leum products. Alternately, the hole may be cased With a liner,
`Which is then perforated to permit in?oW through the open
`ings created by perforating.
`When natural in?oW from the Well is not economical, the
`Well may require Wellbore treatment termed stimulation. This
`is accomplished by pumping stimulation ?uids such as frac
`turing ?uids, acid, cleaning chemicals and/or proppant laden
`?uids to improve Wellbore in?oW.
`In one previous method, the Well is isolated in segments
`and each segment is individually treated so that concentrated
`and controlled ?uid treatment can be provided along the
`Wellbore. Often, in this method a tubing string is used With
`in?atable element packers thereabout Which provide for seg
`ment isolation. The packers, Which are in?ated With pressure
`using a bladder, are used to isolate segments of the Well and
`the tubing is used to convey treatment ?uids to the isolated
`segment. Such in?atable packers may be limited With respect
`to pressure capabilities as Well as durability under high pres
`sure conditions. Generally, the packers are run for a Wellbore
`treatment, but must be moved after each treatment if it is
`desired to isolate other segments of the Well for treatment.
`This process can be expensive and time consuming. Further
`more, it may require stimulation pumping equipment to be at
`the Well site for long periods of time or for multiple visits.
`This method can be very time consuming and costly.
`Other procedures for stimulation treatments use foam
`diverters, gelled diverters and/or limited entry procedures
`through tubulars to distribute ?uids. Each of these may or may
`not be effective in distributing ?uids to the desired segments
`in the Wellbore.
`The tubing string, Which conveys the treatment ?uid, can
`include ports or openings for the ?uid to pass therethrough
`into the borehole. Where more concentrated ?uid treatment is
`desired in one position along the Wellbore, a small number of
`larger ports are used. In another method, Where it is desired to
`distribute treatment ?uids over a greater area, a perforated
`tubing string is used having a plurality of spaced apart perfo
`rations through its Wall. The perforations can be distributed
`
`25
`
`30
`
`35
`
`40
`
`45
`
`50
`
`55
`
`60
`
`65
`
`2
`along the length of the tube or only at selected segments. The
`open area of each perforation can be pre-selected to control
`the volume of ?uid passing from the tube during use. When
`?uids are pumped into the liner, a pressure drop is created
`across the siZed ports. The pressure drop causes approximate
`equal volumes of ?uid to exit each polt in order to distribute
`stimulation ?uids to desired segments of the Well. Where
`there are signi?cant numbers of perforations, the ?uid must
`be pumped at high rates to achieve a consistent distribution of
`treatment ?uids along the Wellbore.
`In many previous systems, it is necessary to run the tubing
`string into the bore hole With the ports or perforations already
`opened. This is especially true Where a distributed application
`of treatment ?uid is desired such that a plurality of ports or
`perforations must be open at the same time for passage there
`through of ?uid. This need to run in a tube already including
`open perforations can hinder the running operation and limit
`usefulness of the tubing string.
`
`SUMMARY OF THE INVENTION
`
`A method and apparatus has been invented Which provides
`for selective communication to a Wellbore for ?uid treatment.
`In one aspect of the invention the method and apparatus
`provide for staged injection of treatment ?uids Wherein ?uid
`is injected into selected intervals of the Wellbore, While other
`intervals are closed. In another aspect, the method and appa
`ratus provide for the running in of a ?uid treatment string, the
`?uid treatment string having ports substantially closed
`against the pas sage of ?uid therethrough, but Which are open
`able When desired to permit ?uid ?oW into the Wellbore. The
`apparatus and methods of the present invention can be used in
`various borehole conditions including open holes, cased
`holes, vertical holes, horiZontal holes, straight holes or devi
`ated holes.
`In one embodiment, there is provided an apparatus for ?uid
`treatment of a borehole, the apparatus comprising a tubing
`string having a long axis, a ?rst port opened through the Wall
`of the tubing string, a second port opened through the Wall of
`the tubing string, the second port offset from the ?rst port
`along the long axis of the tubing string, a ?rst packer operable
`to seal about the tubing string and mounted on the tubing
`string to act in a position offset from the ?rst port along the
`long axis of the tubing string, a second packer operable to seal
`about the tubing string and mounted on the tubing string to act
`in a position betWeen the ?rst port and the second port along
`the long axis of the tubing string; a third packer operable to
`seal about the tubing string and mounted on the tubing string
`to act in a position offset from the second port along the long
`axis of the tubing string and on a side of the second port
`opposite the second packer; a ?rst sleeve positioned relative
`to the ?rst port, the ?rst sleeve being moveable relative to the
`?rst port betWeen a closed port position and a position per
`mitting ?uid ?oW through the ?rst port from the tubing string
`inner bore and a second sleeve being moveable relative to the
`second port betWeen a closed port position and a position
`permitting ?uid ?oW through the second port from the tubing
`string inner bore; and a sleeve shifting means for moving the
`second sleeve from the closed port position to the position
`permitting ?uid ?oW, the means for moving the second sleeve
`selected to create a seal in the tubing string against ?uid ?oW
`past the second sleeve through the tubing string inner bore.
`In one embodiment, the second sleeve has formed thereon
`a seat and the means for moving the second sleeve includes a
`sealing device selected to seal against the seat, such that ?uid
`pressure can be applied to move the second sleeve and the
`sealing device can seal against ?uid passage past the second
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`US 7,571,765 B2
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`3
`sleeve. The sealing device can be, for example, a plug or a
`ball, Which can be deployed Without connection to surface.
`Thereby avoiding the need for tripping in a string or Wire line
`for manipulation.
`The means for moving the second sleeve can be selected to
`move the second sleeve Without also moving the ?rst sleeve.
`In one such embodiment, the ?rst sleeve has formed thereon
`a ?rst seat and the means for moving the ?rst sleeve includes
`a ?rst sealing device selected to seal against the ?rst seat, such
`that once the ?rst sealing device is seated against the ?rst seat
`?uid pressure can be applied to move the ?rst sleeve and the
`?rst sealing device can seal against ?uid passage past the ?rst
`sleeve and the second sleeve has formed thereon a second seat
`and the means for moving the second sleeve includes a second
`sealing device selected to seal against the second seat, such
`that When the second sealing device is seated against the
`second seat pressure can be applied to move the second sleeve
`and the second sealing device can seal against ?uid passage
`past the second sleeve, the ?rst seat having a larger diameter
`than the second seat, such that the second sealing device can
`move past the ?rst seat Without sealing thereagainst to reach
`and seal against the second seat.
`In the closed port position, the ?rst sleeve can be positioned
`over the ?rst port to close the ?rst port against ?uid ?oW
`therethrough. In another embodiment, the ?rst port has
`mounted thereon a cap extending into the tubing string inner
`bore and in the position permitting ?uid ?oW, the ?rst sleeve
`has engaged against and opened the cap. The cap can be
`opened, for example, by action of the ?rst sleeve shearing the
`cap from its position over the port. In another embodiment,
`the apparatus further comprises a third port having mounted
`thereon a cap extending into the tubing string inner bore and
`in the position permitting ?uid ?oW, the ?rst sleeve also
`engages against the cap of the third port to open it.
`In another embodiment, the ?rst port has mounted there
`over a sliding sleeve and in the position permitting ?uid ?oW,
`the ?rst sleeve has engaged and moved the sliding sleeve
`aWay from the ?rst port. The sliding sleeve can include, for
`example, a groove and the ?rst sleeve includes a locking dog
`biased outWardly therefrom and selected to lock into the
`groove on the sleeve. In another embodiment, there is a third
`port With a sliding sleeve mounted thereover and the ?rst
`sleeve is selected to engage and move the third port sliding
`sleeve after it has moved the sliding sleeve of the ?rst port.
`The packers can be of any desired type to seal betWeen the
`Wellbore and the tubing string. In one embodiment, at least
`one of the ?rst, second and third packer is a solid body packer
`including multiple packing elements. In such a packer, it is
`desirable that the multiple packing elements are spaced apart.
`In vieW of the foregoing there is provided a method for ?uid
`treatment of a borehole, the method comprising: providing an
`apparatus for Wellbore treatment according to one of the
`various embodiments of the invention; running the tubing
`string into a Wellbore in a desired position for treating the
`Wellbore; setting the packers; conveying the means for mov
`ing the second sleeve to move the second sleeve and increas
`ing ?uid pressure to Wellbore treatment ?uid out through the
`second port.
`In one method according to the present invention, the ?uid
`treatment is borehole stimulation using stimulation ?uids
`such as one or more of acid, gelled acid, gelled Water, gelled
`oil, CO.sub.2, nitrogen and any of these ?uids containing
`proppants, such as for example, sand or bauxite. The method
`can be conducted in an open hole or in a cased hole. In a cased
`hole, the casing may have to be perforated prior to running the
`tubing string into the Wellbore, in order to provide access to
`the formation.
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`In an open hole, preferably, the packers include solid body
`packers including a solid, extrudable packing element and, in
`some embodiments, solid body packers include a plurality of
`extrudable packing elements.
`In one embodiment, there is provided an apparatus for ?uid
`treatment of a borehole, the apparatus comprising a tubing
`string having a long axis, a port opened through the Wall of the
`tubing string, a ?rst packer operable to seal about the tubing
`string and mounted on the tubing string to act in a position
`offset from the port along the long axis of the tubing string, a
`second packer operable to seal about the tubing string and
`mounted on the tubing string to act in a position offset from
`the port along the long axis of the tubing string and on a side
`of the port opposite the ?rst packer; a sleeve positioned rela
`tive to the port, the sleeve being moveable relative to the port
`betWeen a closed port position and a position permitting ?uid
`?oW through the port from the tubing string inner bore and a
`sleeve shifting means for moving the sleeve from the closed
`port position to the position permitting ?uid ?oW. In this
`embodiment of the invention, there can be a second port
`spaced along the long axis of the tubing string from the ?rst
`port and the sleeve can be moveable to a position permitting
`?oW through the port and the second port.
`As noted hereinbefore, the sleeve can be positioned in
`various Ways When in the closed port position. For example,
`in the closed port position, the sleeve can be positioned over
`the port to close the port against ?uid ?oW therethrough.
`Alternately, When in the closed port position, the sleeve can be
`offset from the port, and the port can be closed by other means
`such as by a cap or another sliding sleeve Which is acted upon,
`as by breaking open or shearing the cap, by engaging against
`the sleeve, etc., by the sleeve to open the port.
`There can be more than one port spaced along the long axis
`of the tubing string and the sleeve can act upon all of the ports
`to open them.
`The sleeve can be actuated in any Way to move into the
`position permitted ?uid ?oW through the port. Preferably,
`hoWever, the sleeve is actuated remotely, Without the need to
`trip a Work string such as a tubing string or a Wire line. In one
`embodiment, the sleeve has formed thereon a seat and the
`means for moving the sleeve includes a sealing device
`selected to seal against the seat, such that ?uid pressure can be
`applied to move the sleeve and the sealing device can seal
`against ?uid passage past the sleeve.
`The ?rst packer and the second packer can be formed as a
`solid body packer including multiple packing elements, for
`example, in spaced apart relation.
`In vieW of the forgoing there is provided a method for ?uid
`treatment of a borehole, the method comprising: providing an
`apparatus for Wellbore treatment including a tubing string
`having a long axis, a port opened through the Wall of the
`tubing string, a ?rst packer operable to seal about the tubing
`string and mounted on the tubing string to act in a position
`offset from the port along the long axis of the tubing string, a
`second packer operable to seal about the tubing string and
`mounted on the tubing string to act in a position offset from
`the port along the long axis of the tubing string and on a side
`of the port opposite the ?rst packer; a sleeve positioned rela
`tive to the port, the sleeve being moveable relative to the port
`betWeen a closed port position and a position permitting ?uid
`?oW through the port from the tubing string inner bore and a
`sleeve shifting means for moving the sleeve from the closed
`port position to the position permitting ?uid ?oW; running the
`tubing string into a Wellbore in a desired position for treating
`the Wellbore; setting the packers; conveying the means for
`
`13 of 21
`
`Ex. 2095
`IPR2016-01517
`
`

`

`US 7,571,765 B2
`
`5
`moving the sleeve to move the sleeve and increasing ?uid
`pressure to permit the ?oW of Wellbore treatment ?uid out
`through the port.
`
`BRIEF DESCRIPTION OF THE DRAWINGS
`
`01
`
`A further, detailed, description of the invention, brie?y
`described above, Will folloW by reference to the following
`draWings of speci?c embodiments of the invention. These
`draWings depict only typical embodiments of the invention
`and are therefore not to be considered limiting of its scope. In
`the draWings:
`FIG. 1a is a sectional vieW through a Wellbore having
`positioned therein a ?uid treatment assembly according to the
`present invention;
`FIG. 1b is an enlarged vieW of a portion of the Wellbore of
`FIG. 1a With the ?uid treatment assembly also shoWn in
`section;
`FIG. 2 is a sectional vieW along the long axis of a packer
`useful in the present invention;
`FIG. 3a is a sectional vieW along the long axis of a tubing
`string sub useful in the present invention containing a sleeve
`in a closed port position;
`FIG. 3b is a sectional vieW along the long axis of a tubing
`string sub useful in the present invention containing a sleeve
`in a position alloWing ?uid ?oW through ?uid treatment ports;
`FIG. 4a is a quarter sectional vieW along the long axis of a
`tubing string sub useful in the present invention containing a
`sleeve and ?uid treatment ports;
`FIG. 4b is a side elevation of a ?oW control sleeve posi
`tionable in the sub of FIG. 4a;
`FIG. 5 is a section through another Wellbore having posi
`tioned therein a ?uid treatment assembly according to the
`present invention;
`FIG. 6a is a section through another Wellbore having posi
`tioned therein another ?uid treatment assembly according to
`the present invention, the ?uid treatment assembly being in a
`?rst stage of Wellbore treatment;
`FIG. 6b is a section through the Wellbore of FIG. 6a With
`the ?uid treatment assembly in a second stage of Wellbore
`treatment;
`FIG. 60 is a section through the Wellbore of FIG. 6a With
`the ?uid treatment assembly in a third stage of Wellbore
`treatment;
`FIG. 7 is a sectional vieW along the long axis of a tubing
`string according to the present invention containing a sleeve
`and axially spaced ?uid treatment ports;
`FIG. 8 is a sectional vieW along the long axis of a tubing
`string according to the present invention containing a sleeve
`and axially spaced ?uid treatment ports;
`FIG. 9a is a section through another Wellbore having posi
`tioned therein another ?uid treatment assembly according to
`the present invention, the ?uid treatment assembly being in a
`?rst stage of Wellbore treatment;
`FIG. 9b is a section through the Wellbore of FIG. 9a With
`the ?uid treatment assembly in a second stage of Wellbore
`treatment;
`FIG. 90 is a section through the Wellbore of FIG. 9a With
`the ?uid treatment assembly in a third stage of Wellbore
`treatment; and
`FIG. 9d is a section through the Wellbore of FIG. 9a With
`the ?uid treatment assembly in a fourth stage of Wellbore
`treatment.
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`DETAILED DESCRIPTION OF THE PRESENT
`INVENTION
`
`Referring to FIGS. 1a and 1b, a Wellbore ?uid treatment
`assembly is shoWn, Which can be used to effect ?uid treatment
`of a formation 10 through a Wellbore 12. The Wellbore assem
`bly includes a tubing string 14 having a loWer end 1411 and an
`upper end extending to surface (not shoWn). Tubing string 14
`includes a plurality of spaced apart ported intervals 16a to 16e
`each including a plurality of ports 17 opened through the
`tubing string Wall to permit access betWeen the tubing string
`inner bore 18 and the Wellbore.
`A packer 20a is mounted betWeen the upper-most ported
`interval 16a and the surface and furtherpackers 20b to 20e are
`mounted betWeen each pair of adjacent ported intervals. In
`the illustrated embodiment, a packer 20f is also mounted
`beloW the loWer most ported interval 16e and loWer end 1411
`of the tubing string. The packers are disposed about the tubing
`string and selected to seal the annulus betWeen the tubing
`string and the Wellbore Wall, When the assembly is disposed in
`the Wellbore. The packers divide the Wellbore into isolated
`segments Wherein ?uid can be applied to one segment of the
`Well, but is prevented from passing through the annulus into
`adjacent segments. As Will be appreciated the packers can be
`spaced in any Way relative to the ported intervals to achieve a
`desired interval length or number of ported intervals per seg
`ment. In addition, packer 20f need not be present in some
`applications.
`The packers are of the solid body-type With at least one
`extrudable packing element, for example, formed of rubber.
`Solid body packers including multiple, spaced apart packing
`elements 21a, 21b on a single packer are particularly useful
`especially for example in open hole (unlined Wellbore) opera
`tions. In another embodiment, a plurality of packers are posi
`tioned in side by side relation on the tubing string, rather than
`using one packer betWeen each ported interval.
`Sliding sleeves 220 to 22e are disposed in the tubing string
`to control the opening of the ports. In this embodiment, a
`sliding sleeve is mounted over each ported interval to close
`them against ?uid ?oW therethrough, but can be moved aWay
`from their positions covering the ports to open the ports and
`alloW ?uid ?oW therethrough. In particular, the sliding
`sleeves are disposed to control the opening of the ported
`intervals through the tubing string and are each moveable
`from a closed port position covering its associated ported
`interval (as shoWn by sleeves 22c and 22d) to a position aWay
`from the ports Wherein ?uid ?oW of, for example, stimulation
`?uid is permitted through the ports of the ported interval (as
`shoWn by sleeve 22e).
`The assembly is run in and positioned doWnhole With the
`sliding sleeves each in their closed port position. The sleeves
`are moved to their open position When the tubing string is
`ready for use in ?uid treatment of the Wellbore. Preferably, the
`sleeves for each isolated interval betWeen adjacent packers
`are opened individually to permit ?uid ?oW to one Wellbore
`segment at a time, in a staged, concentrated treatment pro
`cess.
`Preferably, the sliding sleeves are each moveable remotely
`from their closed port position to their position permitting
`through-port ?uid ?oW, for example, Without having to run in
`a line or string for manipulation thereof. In one embodiment,
`the sliding sleeves are each actuated by a device, such as a ball
`24e (as shoWn) or plug, Which can be conveyed by gravity or
`
`14 of 21
`
`Ex. 2095
`IPR2016-01517
`
`

`

`US 7