`Exhibit 1014
`
`Page 1 of 20
`
`
`
`US 7,861,774 B2
`Page 2
`
`U.S. PATENT DOCUMENTS
`
`2007/0151734 A1
`
`7/2007 Fehr et al. ................. .. 166/318
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`2,841,007
`2,860,489
`3,038,542
`3,054,415
`3,122,205
`3,153,845
`3,154,940
`3,158,378
`3,165,918
`3,165,919
`3,165,920
`3,193,917
`3,194,310
`3,195,645
`3,199,598
`3,311,169
`4,099,563
`4,279,306
`4,498,536
`4,516,879
`4,519,456
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`4,552,218
`4,567,944
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`4,967,841
`5,103,901
`5,152,340
`5,186,258
`5,197,547
`5,454,430
`5,472,048
`5,499,687
`5,526,880
`5,533,573
`5,542,473
`5,701,954
`5,775,429
`5,791,414
`5,894,888
`5,960,881
`6,041,858
`6,047,773
`6,112,811
`6,131,663
`6,253,861
`6,446,727
`6,460,619
`6,543,545
`6,763,885
`6,907,936
`7,021,384
`7,096,954
`7,108,060
`7,108,067
`7,134,505
`7,198,110
`7,231,987
`7,267,172
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`
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`1/1989
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`
`Loomis ................. .. 73/40.5 R
`
`Townsend
`
`. 405/269
`
`OTHER PUBLICATIONS
`
`Loomis .................... .. 166/187
`Baker et al.
`Brown et al. .............. .. 166/122
`Loomis
`Loomis
`Loomis
`Loomis
`Loomis
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`.
`He?ey et al. .............. .. 166/120
`Hutchison et al.
`Weitz ....................... .. 166/312
`
`Ross et al. ................ .. 166/312
`Berry et al.
`Cochron ................... .. 166/312
`
`Pringle
`Ross et al. ................ .. 166/321
`
`Zunkel et al. ............. .. 166/120
`Brisco
`
`Evans .......... ..
`Barrington et al.
`
`. 166/128
`. 166/ 135
`
`Evans .......... ..
`
`. 166/134
`
`Dech ..... ..
`. 166/3 80
`Mohaupt .
`166/305.1
`Gentry ........ ..
`166/313
`Greenlee et al. .......... .. 166/387
`Mills
`Stokley et al.
`Szarka et al.
`Murray
`Greenlee .................. .. 166/ 120
`
`Clark et al. ............... .. 166/122
`Wood et al. .
`166/387
`Morgan .................... .. 166/181
`Kennedy et al. ............ .. 166/50
`Kennedy et al.
`Lee
`Jordan, Jr. et al.
`Jordan, Jr. et al.
`Pringle ..................... .. 166/ 120
`Kilgore et al. ............ .. 166/119
`Arizmendi et al.
`166/206
`Skinner et al. ............ .. 166/187
`Wiemers et al.
`Allamon et al.
`
`Arizmendi ................ .. 166/187
`Zeltmann et al.
`Kilgore et al. ............ .. 166/120
`Henley et al. ............. .. 166/373
`Carmichael et al.
`Zemlak et al.
`Braithwaite et al.
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`Fehr et al. ................. .. 166/387
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`Weng et al.
`Jones
`Themig et al.
`Fehr et al. ................. .. 166/387
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`Kilgore et al. ............ .. 166/134
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`Kilgore et al. ............ .. 166/134
`Hofman
`Depiak et al. ............. .. 166/185
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`Halliburton “Halliburton Guiberson® G-77 Hydraulic-Set Retriev
`able Packer,” 6 pages.
`Baker Oil Tools, “Retrievable Packer Systems,” product brochure, 1
`page.
`Drawings, Packer Installation Plan, PACK 05543, 5 pages, 1997.
`Guiberson'AVA & Dresser, Retrievable Packer Systems, “Tandem
`Packer,” 1 page.
`Halliburton, “Hydraulic-Set GuibersonTM Wizard Packer®,” 1 page.
`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, 1998.
`Packers Plus Energy Services, Inc. “5.1 RockSealTM II Open Hole
`Packer Series,” 2 pages, 2004.
`Halliburton Guiberson G-77 Hydraulic-Set Retrievable Packer pre
`sentation, 6 pages.
`Owen Oil Tools Mechanical Gun Release; 2-3/8" & 2-7/8" product
`description, 1 page.
`Sapex Oil Tools Ltd. Downhole Completions catalog, 24 pages.
`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.
`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, 23 8th Judicial District 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 II Hydraulic Set Retrievable Packer Tech
`Manual, Apr. 1998.
`Dresser Oil Tools, catalog, Multilateral Completion Tools Section.
`Dresser Oil Tools, catalog, Technical Section, title page and page 18,
`Nov. 1997.
`Berryman, William, First Supplemental Expert Report in Cause No.
`CV-44964, 23 8th Judicial District of Texas.
`Brown Oil Tools, catalog page, entitled “Brown Hydraulic Set Pack
`ers.”
`Brown Oil Tools, catalog page, entitled “Brown HS-16-1 Hydraulic
`Set Retrievable Packers.”
`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, 2008.
`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.
`
`Page 2 of 20
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`
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`US 7,861,774 B2
`Page 3
`
`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.
`Design and Installation of a Cost-Effective Completion System for
`Horizontal Chalk Wells Where Multiple Zones Require Acid Stimu
`lation, D. W. Thompson, SPE Drilling & Completion, Sep. 1998, pp.
`1 5 l - l 56.
`http://WWW.packersplus.com/rockseal%202.htrn description of open
`hole packer, available prior to Nov. 19, 2001.
`
`* cited by examiner
`
`Page 3 of 20
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`
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`US. Patent
`
`Jan. 4, 2011
`
`Sheet 1 019
`
`US 7,861,774 B2
`
`[ID Surface
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`20b
`
`16b
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`Page 4 of 20
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`US. Patent
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`Jan. 4, 2011
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`Sheet 2 0f9
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`US 7,861,774 B2
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`Page 5 of 20
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`Page 7 of 20
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`US. Patent
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`Jan. 4, 2011
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`Sheet 5 0f9
`
`US 7,861,774 B2
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`Page 8 of 20
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`US. Patent
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`Jan. 4, 2011
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`Sheet 6 0f 9
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`US. Patent
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`Jan. 4, 2011
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`Sheet 7 0f9
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`US 7,861,774 B2
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`US. Patent
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`Jan. 4, 2011
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`Sheet 9 0f9
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`US 7,861,774 B2
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`
`Page 12 of 20
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`US 7,861,774 B2
`
`1
`METHOD AND APPARATUS FOR
`WELLBORE FLUID TREATMENT
`
`CROSS REFERENCE TO RELATED
`APPLICATIONS
`
`This is a continuation application of US. application Ser.
`No. 11/550,863 ?led Oct. 19, 2006, now US. Pat. No. 7,543,
`634, issued Jun. 9, 2009, which is a continuation of US.
`application Ser. No. 11/104,467, ?led Apr. 13, 2005, now
`US. Pat. No. 7,134,505, issued Nov. 14, 2006, which is a
`divisional of US. application Ser. No. 10/299,004, ?led Nov.
`19, 2002, now US. Pat. No. 6,907,936, issued Jun. 21, 2005.
`The parent applications and the present application claim
`priority from US. provisional application 60/331,491, ?led
`Nov. 19, 2001 and US. provisional application 60/404,783,
`?led Aug. 21, 2002.
`
`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.
`
`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 wellbom 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 pressure
`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
`
`20
`
`25
`
`30
`
`35
`
`40
`
`45
`
`50
`
`55
`
`60
`
`65
`
`2
`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
`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 port 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
`
`Page 13 of 20
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`
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`US 7,861,774 B2
`
`3
`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
`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, C02, nitrogen and any of these ?uids containing prop
`pants, such as for example, sand or bauxite. The method can
`be conducted in an open hole or in a cased hole. In a cased
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`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.
`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
`
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`US 7,861,774 B2
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`5
`the wellbore; setting the packers; conveying the means for
`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
`
`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
`?uid ?ow through the tubing string. The device engages
`against the sleeve, in this case ball 24e engages against sleeve
`22e, and, when pressure is applied through the tubing string
`inner bore 18 from surface, ball 24e seats against and creates
`
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`7
`a pressure differential above and below the sleeve which
`drives the sleeve toward the lower pressure side.
`In the illustrated embodiment, the inner surface of each
`sleeve which is open to the inner bore of the tubing string
`de?nes a seat 26e onto which an associated ball 24e, when
`launched from surface, can land and seal thereagainst. When
`the ball seals against the sleeve seat and pressure is applied or
`increased from surface, a pressure differential is set up which
`causes the sliding sleeve on which the ball has landed to