BAKER HUGHES INCORPORATED
`Exhibit 1001
`Page 1 of 19
`
`

`
`US007543634B2
`
`(12) United States Patent
`Fehr et a].
`
`(10) Patent No.:
`(45) Date of Patent:
`
`US 7,543,634 B2
`*Jun. 9, 2009
`
`(54) METHOD AND APPARATUS FOR
`WELLBORE FLUID TREATMENT
`
`(75) Inventors: Jim Fehr, Edmonton (CA); Daniel Jon
`Themig, Cochrane (CA)
`
`(73) Assignee: Packers Plus Energy Services Inc.,
`Calgary (CA)
`
`( * ) Notice:
`
`Subject to any disclaimer, the term of this
`patent is extended or adjusted under 35
`U.S.C. 154(b) by 0 days.
`
`This patent is subject to a terminal dis
`claimer.
`
`(21) Appl.No.: 11/550,863
`
`(22) Filed:
`
`Oct. 19, 2006
`
`(65)
`
`Prior Publication Data
`
`US 2007/0151734 A1
`
`Jul. 5, 2007
`
`Related US. Application Data
`
`(60) Continuation of application No. 11/104,467, ?led on
`Apr. 13, 2005, noW Pat. No. 7,134,505, Which is a
`division of application No. 10/299,004, ?led on Nov.
`19, 2002, noW Pat. No. 6,907,936.
`(60) Provisional application No. 60/331,491, ?led on Nov.
`19, 2001, provisional application No. 60/404,783,
`?led on Aug. 21, 2002.
`
`(51) Int. Cl.
`(2006.01)
`E21B 43/14
`(2006.01)
`E21B 33/124
`(2006.01)
`E21B 34/14
`(52) US. Cl. ..................... .. 166/191; 166/313; 166/373;
`166/147; 166/318
`
`(58) Field of Classi?cation Search ............... .. 166/387,
`166/386, 373, 374, 142, 146, 147, 184, 185,
`166/194, 318, 269, 126, 127, 131, 191, 305.1,
`166/306, 313; 175/237, 317
`See application ?le for complete search history.
`
`(56)
`
`References Cited
`
`U.S. PATENT DOCUMENTS
`
`1,956,694 A *
`2,227,539 A *
`2,737,244 A
`3,054,415 A
`4,099,563 A
`4,516,879 A
`4,520,870 A
`4,569,396 A *
`4,794,989 A *
`4,893,678 A
`4,949,788 A
`
`5/1934 Parrish ..................... .. 277/342
`1/1941 Dorton ...................... .. 166/70
`3/1956 Baker et a1.
`9/1962 Baker et a1.
`7/1978 Hutchinson et al.
`5/1985 Berry et al.
`6/1985 Pringle
`2/1986 Brisco ................... .. 166/305.1
`1/1989 Mills ........................ .. 166/387
`1/1990 Stokley et al.
`8/1990 SZarka et al.
`(Continued)
`OTHER PUBLICATIONS
`http://WWW.packersplus.com/rockseal%202.htm description of open
`hole packer, available prior to Nov. 19, 2001.
`(Continued)
`Primary ExamineriKenneth Thompson
`(74) Attorney, Agent, or FirmiBennett Jones LLP
`
`(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.
`
`25 Claims, 9 Drawing Sheets
`
`Page 1 of 19
`
`

`
`US 7,543,634 B2
`Page 2
`
`4/2006 Themig
`7,021,384 B2
`8/2006 Weng et al.
`7,096,954 B2
`9/2006 Jones
`7,108,060 B2
`9/2006 Themig et al.
`7,108,067 B2
`7,134,505 B2 * 11/2006 Fehr et a1. ................. .. 166/387
`7,267,172 B2
`9/2007 Hofman
`
`OTHER PUBLICATIONS
`
`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.
`151-156.
`
`* cited by examiner
`
`11/1990
`12/1995
`3/1996
`6/1996
`7/1996
`4/1999
`10/1999
`4/2000
`7/2001
`9/2002
`10/2002
`7/2004
`6/2005
`
`US. PATENT DOCUMENTS
`Murray
`Kennedy et al.
`Lee
`Jordan, Jr. et a1.
`Jordan, Jr. et a1.
`Wiemers et al.
`Allamon et al.
`Zeltmann et al.
`Carmichael et al.
`Zemlak et al.
`BraithWaite et a1.
`Cavender
`Fehr et a1. ................. .. 166/387
`
`A
`A
`A
`A
`A
`A
`A
`A
`B1
`B1
`
`4,967,841
`5,472,048
`5,499,687
`5,526,880
`5,533,573
`5,894,888
`5,960,881
`6,047,773
`6,253,861
`6,446,727
`6,460,619
`6,763,885
`6,907,936
`
`Page 2 of 19
`
`

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`US. Patent
`
`Jun. 9, 2009
`
`Sheet 1 of9
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`US 7,543,634 B2
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`
`Page 3 of 19
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`Jun. 9, 2009
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`US 7,543,634 B2
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`Page 4 of 19
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`Page 5 of 19
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`Page 7 of 19
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`Jun. 9, 2009
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`Jun. 9, 2009
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`Page 11 of 19
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`

`
`US 7,543,634 B2
`
`1
`METHOD AND APPARATUS FOR
`WELLBORE FLUID TREATMENT
`
`CROSS REFERENCE TO RELATED
`APPLICATIONS
`
`This is a continuation application of US. application Ser.
`No. 11/104,467, ?ledApr. 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.
`
`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 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 borc.
`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
`
`Page 12 of 19
`
`

`
`US 7,543,634 B2
`
`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, CO2, 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
`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.
`
`20
`
`25
`
`30
`
`35
`
`40
`
`45
`
`50
`
`55
`
`60
`
`65
`
`4
`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
`
`Page 13 of 19
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`US 7,543,634 B2
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`moving the sleeve to move the sleeve and increasing ?uid
`pressure to permit the ?oW of Wellbore treatment ?uid out
`through the port.
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`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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`BRIEF DESCRIPTION OF THE DRAWINGS
`
`DETAILED DESCRIPTION OF THE PRESENT
`INVENTION
`
`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
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`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
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`US 7,543,634 B2
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`7
`?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
`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 slide
`to an port-open position. When the ports of the ported interval
`16e are opened, ?uid can ?oW therethrough to the annulus
`betWeen the tubing string and the Wellbore and thereafter into
`contact With formation 10.
`Each of the plurality of sliding sleeves has a different
`diameter seat and therefore each accept different siZed balls.
`In particular, the loWer-most sliding sleeve 22e has the small
`est diameter D1 seat and accepts the smallest siZed ball 24e
`and each sleeve that is progressively closer to surface has a
`larger seat. For example, as shoWn in FIG. 1b, the sleeve 220
`includes a seat 260 having a diameter D3, sleeve 22d includes
`a seat 26d having a diameter D2, Which is less than D3 and
`sleeve 22e includes a seat 26e having a diameter D1, Which is
`less than D2. This provides that the loWest sleeve can be
`actuated to open ?rst by ?rst launching the smallest ball 24e,
`Which can pass though all of the seats of the sleeves closer to
`surface but Which Will land in and seal against seat 26e of
`sleeve 22e. Likewise, penultimate sleeve 22d can be actuated
`to move aWay from potted interval 16d by launching a ball
`24d Which is siZed to pass through all of the seats closer to
`surface, including seat 260, but Which Will land in and seal
`against seat 26d.
`LoWer end 1411 of the tubing string can be open, closed or
`?tted in various Ways, depending on the operational charac
`teristics of the tubing string Which are desired. In the illus
`trated embodiment, includes a pump out plug assembly 28.
`Pump out plug assembly acts to close off end 1411 during run
`in of the tubing string, to maintain the inner bore of the tubing
`string relatively clear. HoWever, by application of ?uid pres
`sure, for example at a pressure of about 3000 psi, the plug can
`be bloWn out to permit actuation of the loWer most sleeve 22e
`by generation of a pressure differential. As Will be appreci
`ated, an opening adjacent end 1411 is only needed Where
`pressure, as opposed to gravity, is needed to convey the ?rst
`ball to land in the loWer-most sleeve. Alternately, the loWer
`most sleeve can be hydraulically actuated, including a ?uid
`actuated piston secured by shear pins, so that the sleeve can be
`opened remotely Without the need to land a ball or plug
`therein.
`In other embodiments, not shoWn, end 1411 can be left open
`or can be closed for example by installation of a Welded or
`threaded plug.
`While the illustrated tubing string includes ?ve ported
`intervals, it is to be understood that any number of ported
`intervals could be used. In a ?uid treatment assembly desired
`to be used for staged ?uid treatment, at least tWo openable
`ports from the tubing string inner bore to the Wellbore must be
`provided such as at least tWo ported intervals or an openable
`end and one ported interval. It is also to be understood that any
`number of ports can be used in each interval.
`CentraliZer 29 and other standard tubing string attachments
`can be used.
`In use, the Wellbore ?uid treatment apparatus, as described
`With respect to FIGS. 1a and 1b, can be used in the ?uid
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`treatment of a Wellbore. For selectively treating formation 10
`through Wellbore 12, the above-described assembly is run
`into the borehole and the packers are set to seal the annulus at
`each location creating a plurality of isolated annulus Zones.
`Fluids can then pumped doWn the tubing string and into a
`selected Zone of the annulus, such as by increasing the pres
`sure to pump out plug assembly 28. Alternately, a plurality of
`open ports or an open end can be provided or loWer most
`sleeve can be hydraulically openable. Once that selected Zone
`is treated, as desired, ball 24e or another sealing plug is
`launched from surface and conveyed by gravity or ?uid pres
`sure to seal against seat 26e of the loWer most sliding sleeve
`22e, this seals off the tubing string beloW sleeve 22e and
`opens ported interval 16e to alloW the next annulus Zone, the
`Zone betWeen packer 20e an