BAKER HUGHES INCORPORATED
`AND BAKER HUGHES OILFIELD
`OPERATIONS, INC.
`Exhibit 1009
`BAKER HUGHES INCORPORATED
`AND BAKER HUGHES OILFIELD
`OPERATIONS, INC. v. PACKERS
`PLUS ENERGY SERVICES, INC.
`IPR2016-00598
`
`Page 1 of 10
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`

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`U.S. Patent
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`Dec. 27, 1994
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`Sheet 1 of 4
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`5,375,662
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`Page 4 of 10
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`

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` U.S.Patent
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`Page 5 of 10
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`an
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`5,375,662
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`1
`
`HYDRAULIC SETTING SLEEVE
`
`CROSS-REFERENCE TO RELATED
`APPLICATIONS:
`
`This application is a continuation-in-part of applica-
`tion Ser. No. 08/001,020, filed Jan. 6, 1993, which is a
`continuation of U.S. application Ser. No. 07/743,792,
`filed Aug. 12, 1991, now U.S. Pat. No. 5,180,016.
`FIELD OF THE INVENTION
`
`This invention relates generally to apparatus for com-
`pleting downhole wells, and in particular to apparatus
`for setting hydraulic packers.
`BACKGROUND OF THE INVENTION
`
`In the course of completing an oil and/or gas well, it
`is common practice to run a string of protective easing
`into the well bore and then to run the production tubing
`inside the casing. At the well site, the casing is perfo-
`rated across one or more production zones to allow
`production fluids to enter the casing bore. During pro-
`duction of the formation fluid, formation sand is also
`swept into the flow path. The formation sand is rela-
`tively fine sand that erodes production components in
`the flow path.
`In some completions, however, the well bore is un-
`cased, and an open face is established across the oil or
`gas bearing zone. Such open bore hole (uncased) ar-
`rangements are utilized, for example, in water wells, test
`wells, highly deviated and horizontal well completions.
`One or more sand screens are installed in the flow path
`between the production tubing and the open, uncased
`well bore face. The packer and sand screens are run in
`place while water is pumped under high pressure
`through a float shoe to wash the uncased bore and re-
`move drill cuttings and clean well completion apparatus
`prior to placing the well into production. It is desirable
`that the wash job be performed as the completion appa-
`ratus is run into the well. After the armulus along the
`uncased well bore has been cleaned, the packer is cus-
`tomarily set to seal off the annulus in the zone where
`production fluids flow into the production tubing. In-
`flatable packers are preferred for use in sealing an un-
`cased well bore.
`
`DESCRIPTION OF THE PRIOR ART
`
`The float shoe contains multiple ports through which
`fluids are jetted to wash drill cuttings from a well bore
`while a packer, screen or other set of well completion
`tools are rim into the well bore. Because high differen-
`tial pressures may be created by the jets at the end of the
`float shoe,
`it has been difficult to run hydraulically
`operated down hole well tools, such as hydraulic pack-
`ers, in the same trip because of the potential for inadver-
`tent set of the tools as a result of the back pressures
`generated in the annulus during the jet cleaning opera-
`tion. Therefore, when such operations have been con-
`ducted previously, it has been necessary to first jet clean
`and clear the well bore, and then, in a separate trip, rim
`the completion apparatus and production tubing into
`the well.
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`In the course of preparing the well for production, a
`well packer and screen along with a service tool and
`other well completion tools are run into the well on a
`work string, with the packer being releasably anchored
`against the well bore. When the well bore is cased, a
`hydraulically set packer having compressible seal ele-
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`65
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`ments and radially extendible anchor slips are utilized.
`When an uncased well bore is completed, an inflatable
`packer is utilized. Both types of packers may be set by
`the application of hydraulic pressure through setting
`ports.
`Conventional hydraulic setting mechanisms have
`open ports which can allow the packer to be inadver-
`tently set while running the packer and clearing drilling
`debris from the armulus with the float shoe. A build-up
`of hydraulic pressure might cause premature setting
`while pumping through the work string and circulating
`out through the armulus to remove debris. If the annulus
`or float shoe clogs up below the hydraulic setting mech-
`anism, the pressure may build to a level which will
`cause the packer to set, allowing the elements to expand
`and engage the well bore. Some inflatable packers em-
`ploy a check valve which prevents release of the pres-
`sure, and most hydraulically settable packers which
`include anchor slips have ratchet couplings that prevent
`retraction of the anchor slips. A prematurely set packer
`is typically required to be retrieved and then re-run.
`OBJECTS OF THE INVENTION
`
`The principal object of the present invention is to
`provide an improved hydraulic setting apparatus for use
`in combination with hydraulic settable completion
`equipment such as hydraulic packers which are run into
`a well simultaneously with the washing of the well bore
`without risk of causing the premature or unintentional
`operation of the hydraulically settable equipment.
`A related object of the invention is to provide a hy-
`draulic setting apparatus of the character described
`which maintains a hydraulic setting port in sealed con-
`dition during running operations, which may be selec-
`tively opened when it is desired to set the packer, and
`which automatically seals the hydraulic setting port
`after the tool has been set and/or the setting device is
`expended.
`SUMMARY OF THE INVENTION
`
`The foregoing objects are achieved according to the
`present invention in which a hydraulic setting apparatus
`has an isolation sleeve which covers setting ports and
`prevents entry of hydraulic setting pressure into a pres-
`sure settable tool such as an inflatable packer or a hy-
`draulic packer. The setting apparatus has a production
`mandrel adapted for coupling and flow registration
`with the flow bore of the pressure settable completion
`tool. The setting apparatus mandrel is mechanically
`coupled to the mandrel of the pressure settable comple-
`tion tool by a guide tube member which provides an
`enlarged counterbore chamber. The guide tube is inter-
`sected by radial setting ports which permit the entry of
`pressurized fluid for pressurizing a hydraulic pressure
`chamber in the completion tool.
`In one embodiment, the hydraulic pressure chamber
`provides driving pressure for a piston actuated, hydrau-
`lically set packer. In an alternative embodiment, the
`pressure chamber is coupled in fluid communication
`with the pressure chamber of an inflatable packer. In
`both embodiments, a shiftable isolation sleeve opens the
`setting ports. A radially outwardly biased split C-ring is
`engaged against the bore of the isolation sleeve. Longi-
`tudinal travel of the split C-ring is limited by a shear
`collar which is releasably pinned to the isolation sleeve.
`In one embodiment, the isolation sleeve is pinned to
`the guide tube by hollow shear pins. The packer is set
`
`Page 6 of 10
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`5,375,662
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`3
`by flowing a drop ball down the work string until it
`engages the seating surface provided by the C-ring. The
`hydraulic pressure is increased until the hollow shear
`pins shear and separate, and the isolation sleeve is
`shifted longitudinally through the bore to the open port
`position. After the packer has been set, the drop ball is
`still engaged against the C-ring seat. The hydraulic
`pressure is increased until the shear pins on the shear
`collar shear and separate, permitting the shear collar to
`shift toward an extended open position, with the out-
`wardly biased split C-ring being shifted into the coun-
`terbore of the isolation sleeve. As this occurs, the isola-
`tion sleeve expands radially outwardly, thus permitting
`the drop ball to be shifted through the flow production -
`bore to the next packer. At this point, the bore of the
`setting apparatus is no longer restricted which will
`allow passage of a tool string.
`Consequently, it will be appreciated that the setting
`ports remained sealed by the isolation sleeve while rim-
`ning the packer and completion apparatus into the well
`bore, while circulating debris by high pressure jet flow
`from the annulus to the surface. Since the setting ports
`are sealed until the drop ball is flowed into place, the jet
`washing may proceed and there is no risk of prema-
`turely setting the packer, even though the annulus may
`become blocked by debris.
`Operational features and advantages of the invention
`will be understood by those skilled in the art upon read-
`ing the detailed description which follows with refer-
`ence to the attached drawings.
`BRIEF DESCRIPTION OF THE DRAWINGS
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`FIG. 1 is a simplified, sectional view which illustrates
`installation of the setting apparatus of the present inven-
`tion, as part of an expandable packer and well screens in
`a horizontal, uncased well bore;
`FIG. 2 is a view similar to FIG. 1 in which the inflat-
`able packer is inflated;
`FIG. 3 is a longitudinal sectional view, partially bro-
`ken away, of an hydraulic setting sleeve showing its
`components in the closed port, run position;
`FIG. 4 is a view similar to FIG. 3 with the compo-
`nents of the hydraulic setting apparatus being shown in
`the open port, fill position;
`FIG. 5 is a view similar to FIG. 4 with the compo-
`nents of the hydraulic setting apparatus being shown in
`the open port, fully inflated position;
`FIG. 6 is a view similar to FIG. 5 with the compo-
`nents of the hydraulic setting apparatus being shown in
`the closed port, set position;
`FIG. 7 is an elevational view, partially in section,
`showing the components of an alternative embodiment
`of a hydraulic setting apparatus in the rim-in, sealed
`port position; and
`FIG. 8 is a view similar to FIG. 5 in which the com-
`ponents of the hydraulic setting apparatus are in the
`open port, set position.
`DETAILED DESCRIPTION OF THE
`PREFERRED EMBODIMENT
`
`In the description which follows, like parts are indi-
`cated throughout the specification and drawings with
`the same reference numerals, respectively. The draw-
`ings are not necessarily to scale and the proportions of
`certain parts have been exaggerated to better illustrate
`details of the invention.
`Referring now to FIG. 1 and FIG. 2, multiple sand
`screens 10 are shown installed in an uncased well bore
`
`4
`12 which penetrates horizontally through an unconsoli-
`dated formation 14. Multiple screen sections 10 are
`assembled together, with the screen assembly being
`terminated by a float shoe 16.
`The screens 10 are coupled to a work string 18 by a
`running tool 20 and an inflatable packer 22. As the
`completion equipment is run through the horizontal
`bore 12, water is pumped through the work string 18
`and the production mandrels of the setting tool 20, the
`inflatable packer 22 and screens 10, where it is dis-
`charged through the float shoe 16 for washing the bore
`and circulating drill cuttings, filter cake and lost circula-
`tion material from the annulus 24 upwardly for recov-
`ery at the surface as indicated by the arrows. While the
`wash and circulation are proceeding, the packer 20 is in
`its deflated condition as shown in FIG. 1. It will be
`appreciated that the annulus 24 may become blocked by
`an accumulation of debris, particularly in the elbow
`transition region of the horizontal well bore. If that
`should occur, the packer 22 may inadvertently be set
`and seized against the uncased well bore, if the setting
`ports of the packer are exposed to the high pressure
`hydraulic fluctuations produced by operation of the
`float shoe 16.
`
`Inadvertent set of the inflatable packer 22 is pre-
`vented, according to the present invention, by an isola-
`tion sleeve 26 which is shiftable from a sealing position,
`as shown in FIG. 3, in which a hydraulic setting port 28
`is sealed, to a set position in which the setting port 28 is
`uncovered, as shown in FIG. 4.
`The setting apparatus 20 has a tubular mandrel 30
`with a longitudinal flow bore 32. The setting tool man-
`drel 3D is coupled to the mandrel 34 of the inflatable
`packer 22 by a guide tube 36. The guide tube 36 has a
`smooth bore 38 which is radially offset with respect to
`the setting tool flow bore 32.
`.
`The inflatable packer 22 includes an expandable blad-
`der 40 which is secured and sealed by a coupling collar
`42 and set screws 44, which secure the end of the blad-
`der 40 onto a shoulder 46 formed on the guide tube 36.
`The guide tube 36 is intersected by the radially setting
`ports 28, which provide flow communication with the
`pressure chamber 48 defined in the annulus between the
`packer mandrel 34 and the bladder 40.
`Referring now to FIG. 5, the isolation sleeve 26 is
`shiftable longitudinally along the smooth bore surface
`38 of the guide tube 36. During run-in, the isolation
`sleeve 26 is biased to the covered, closed port position
`as shown in FIG. 3 by a coil compression spring 50.
`Referring again to FIG. 3, a releasable seat is pro-
`vided for a drop ball by an outwardly biased split C-ring
`52. The C-ring 52 is received within the flow bore 54 of
`the isolation sleeve 26. Longitudinal displacement of the
`C-ring 52 is blocked by a shear collar 56. The shear
`collar 56 is received within a smooth counterbore 58
`which intersects the isolation sleeve 26. The shear collar
`56 is pinned to the isolation sleeve 26 by shear pins 60.
`The entrance to the setting port 28 is sealed by armular
`O-ring seals 62 and 64 so that the hydraulic expansion
`chamber 48 is sealed with respect to the flow bore 32
`during run-in. The O-ring seals 62 and 64 are longitudi-
`nally spaced in slidable, sealing engagement between
`the isolation sleeve 26 and the smooth bore 38 of the
`guide tube. The C-ring seals 62 and 64 thus seal the flow
`bore 32 with respect to the inflation chamber 48 when
`the isolation sleeve is in the covered (RUN) position as
`shown in FIG. 3.
`
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`5
`When it is desired to inflate the bladder 40, a drop ball
`66 is dropped into the bore of the work string, and is
`flowed into sealing engagement against the C-ring 52.
`The internal C-ring 52, which is compressed within the
`smooth bore 54 of the isolation sleeve, has a sloped
`shoulder 68 which is coated with a polymeric coating
`70. The coated shoulder 68 defines a valve seat for
`receiving and sealing against the drop ball 66.
`When it is desired to expand the bladder 40 and set
`the packer 22, hydraulic pressure is applied sufficient to
`compress the spring 50 and move the isolation sleeve 26
`from the covered position as shown in FIG. 3 to the
`uncovered position as shown in FIG. 4, thereby expos-
`ing the setting port 28. Hydraulic fluid is injected into
`the inflatable packer through the exposed setting port
`until the bladder 40 is fully expanded, as shown in FIG.
`5. The hydraulic pressure is then increased to cause
`shearing separation of the shear pins 60.
`When separation occurs, the shear collar 56 and the
`C-ring 52 are shifted longitudinally into the isolation
`sleeve counterbore 58, as shown in FIG. 5. When the
`C-ring 52 enters the counterbore 58, it expands radially
`into engagement with the counterbore surface, thereby
`releasing the drop ball 66 and permitting it to be flowed
`through the setting tool bore 32 into the packer mandrel
`bore 35. Simultaneously, the coil spring 50 will drive
`the isolation sleeve 26 back to the covered position so
`that the setting ports 28 are once again sealed and iso-
`lated. This will hold the hydraulic setting fluid in the
`packer expansion chamber 48 at the injection pressure.
`The packer mandrel bore 35 is also unrestricted since
`the C-ring ball seat has expanded radially into the isola-
`tion sleeve counterbore 58.
`The drop ball 66 is then pumped into the next inflat-
`able packer which is fitted with identical setting tool 20,
`and the setting process is repeated for setting the next
`packer.
`It will be appreciated that the spring 50 may not be
`required for use in combination with inflatable packers
`which are inflated through a check valve.
`The guide tube 36 is secured and sealed to the setting
`tool mandrel by a threaded union T, and its opposite
`end is secured and sealed to the packer mandrel 34 by a
`threaded union T.
`
`For hydraulic packers which utilize anchor slips and
`expandable seal elements and for those inflatable pack-
`ers which include check valve means coupled to the
`setting ports, the coil spring 50 is not needed. A packer
`setting tool with the hydraulic setting apparatus 72
`constructed without a coil spring is illustrated in FIG. 7
`and FIG. 8.
`
`The construction of the setting apparatus 72 as shown
`in FIGS. 7 and 8 is similar to that shown in FIGS. 3 and
`4, except that a bias spring is not needed. In that em-
`bodiment, the setting port 28 is releasably sealed by a
`shearable cup-like member or shear screw 74 which
`isolates pressure chamber 76 from bore 32 and pins the
`isolation sleeve 26 to the guide tube 36. The shear screw
`74 is intersected by a longitudinally blind bore or pocket
`which serves as an open flow passage through the body
`of the screw when the screw has been separated by a
`shearing force. Otherwise,
`the construction is essen-
`tially the same as that shown in FIGS. 3 and 4.
`Operation of the alternative setting tool embodiment
`72 is different in that the setting port 28 is not rescaled
`after it has been opened. This is not necessary when the
`setting tool 72 is used in combination with inflatable
`packers which are fitted with check valves, or when
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`used in combination with hydraulically set packers
`which include ratchet couplings for preventing retrac-
`tion of the anchor slips.
`In the alternative embodiment shown in FIG. 7, the
`setting port 28 provides flow communication between
`the flow bore 32 and a hydraulic pressure chamber 76.
`The hydraulic chamber 76 is formed in the annulus
`between the guide tube 36 and a pressure cylinder 78.
`Pressurization of the chamber 76 causes a piston 80 to
`be driven longitudinally along the setting tool mandrel
`84 for simultaneously applying a setting force to anchor
`slips and seal elements, for example as disclosed in U.S.
`Pat. No. 4,834,175 and U.S. Pat. No. 5,103,902, which
`are incorporated by reference. When it is desired to set
`the packer, the drop ball 66 is released and flowed into
`sealing engagement with the C-ring 52. The hydraulic
`pressure is increased until the hollow shear screws 74
`separate, thus opening the setting port 74 and permitting
`the isolation sleeve 26 to be shifted along the smooth
`bore of the guide tube 36 to the uncovered position as
`shown in FIG. 8.
`
`When the setting port 28 is opened, hydraulic fluid is
`pumped into the pressure chamber 76, thus causing the
`piston 80 to be driven longitudinally along the setting
`tool mandrel 84 for applying a setting force against the
`seal elements and anchor slips. After the seal elements
`and anchor slips have been set, the drop ball is still on
`the C-ring seat 70 and the shear collar 56 remains
`pinned to the isolation sleeve 26. The hydraulic pressure
`is increased until the shear pins 81 separate, thus permit-
`ting the C-ring 52 and the shear collar 56 to be shifted
`into the isolation sleeve counterbore 58. Upon entry
`into the counterbore, the C-ring 52 expands radially
`outwardly, thus releasing the drop ball 66 and permit-
`ting it to be flowed through the setting tool mandrel
`bore 85 to the next seat.
`
`It will be appreciated that high pressure jet washing
`operations may be carried out while the setting tool,
`packer and screens are being r11n into the well bore,
`without causing premature set of the packer. Moreover,
`since the C-ring seat remains coupled to the isolation
`sleeve, it eliminates the need for an additional ball seat
`to set the packer.
`Although the invention has been described with ref-
`erence to a horizontal completion, and with reference to
`particular preferred embodiments for setting packers,
`the foregoing description is not intended to be con-
`strued in a limiting sense. For example, the hydraulic
`setting apparatus of the present invention may also be
`used for injecting completion chemicals through the
`exposed port into the annulus surrounding the tubing
`string. This arrangement permits the corrosive well
`treatment fluids to be pumped into the formation while
`isolating and protecting the interior of the hydraulically
`settable well completion apparatus. The hydraulic set-
`ting apparatus.of the present invention may also be used
`to good advantage in alternative applications, for exam-
`ple, in oil wells, gas wells, environmental wells, includ-
`ing monitoring wells, recovery wells and disposal wells,
`and in combination with expandable packers as well as
`hydraulically set packers having anchor slips and other
`hydraulically operated tools which would benefit from
`selective hydraulic isolation. It is therefore contem-
`plated that the appended claims will cover any such
`applications which incorporate the hydraulic setting
`apparatus of the present invention.
`We claim:
`
`Page 8 of 10
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`5,375,662
`
`7
`1. Setting apparatus for selectively applying hydrau-
`lic pressure to a hydraulically operated well completion
`apparatus comprising, in combination:
`a tubular mandrel having a flow bore;
`a guide tube coupled to the tool mandrel, said guide
`tube having an internal bore which is radially offset
`with respect to the flow bore, said guide tube being
`adapted for coupling engagement with the mandrel
`of the well completion apparatus, and said guide
`tube being radially intersected by a setting port;
`an isolation sleeve disposed in sealing engagement
`against the bore of the guide tube;
`means coupled to the isolation sleeve and to the guide
`tube for sealing the setting port when the isolation
`sleeve is in a run-in position;
`an outwardly biased split C-ring having a bore pas-
`sage therethrough, said C-ring being disposed for
`longitudinal movement within the bore of the isola-
`tion sleeve; and,
`a shear collar coupled to said isolation sleeve for
`limiting longitudinal movement of the C-ring rela-
`tive to the isolation sleeve.
`
`2. Setting appa.ratus as defined in claim 1, said sealing
`means including first and second longitudinally spaced
`annular seal members disposed in sealing engagement
`between the isolation sleeve and the bore of the guide
`tube, said first and second annular seal members being
`disposed at longitudinally spaced locations on opposite
`sides of the setting ports when the isolation sleeve is in
`the covered position.
`3. Setting apparatus as defined in claim 1, wherein
`said shear collar is coupled to said isolation sleeve by a
`shear pin.
`4. Setting apparatus as defined in claim 1, wherein
`said isolation sleeve is intersected by a longitudinal
`counterbore, said shear collar being received within
`said counterbore.
`5. Setting apparatus as defined in claim 1, wherein
`said isolation sleeve is releasably coupled to the guide
`tube by a hollow shear screw, said hollow shear screw
`being received within said setting port.
`6. Setting apparatus as defined in claim 1, including a
`coiled compression spring received within the bore of
`the guide tube and disposed in engagement with the
`isolation sleeve for biasing the isolation sleeve for
`movement toward the covered position.
`7. A method of performing a downhole operation in
`a wellbore by pumping fluid through a tubing string
`located in the wellbore, comprising the steps of:
`isolating a port from the interior of the tubing string
`with an isolation sleeve;
`dropping a ball into the tubing string and landing the
`ball on a spring-loaded C-ring valve member;
`applying fluid pressure through the tubing string to
`move the isolation sleeve, and open the port to
`fluid flow;
`injecting fluid through the exposed port to perform a
`selected operation in the wellbore;
`increasing the fluid pressure to separate the shear ring
`and allow the C-ring valve member to expand into
`a recess;
`expending the ball through the bore of the expanded
`C-ring valve member; and
`releasing the spring-loaded C-ring valve member to
`return the isolation sleeve back to the closed posi-
`tion so that the port is isolated from the interior of
`the tubing string.
`
`8
`8. The method of claim 7, wherein the downhole
`operation is setting a packer, and wherein the step of
`injection fluid through the exposed port includes the
`step of injecting fluid through the exposed port to act
`against a piston to compress the packer seal element
`radially outward and set the packer.
`9. The method of claim 7, wherein the downhole
`operation is setting a packer, and wherein the step of
`injecting fluid through the exposed port includes the sep
`of injecting fluid through the exposed port and into the
`inflatable element of the packer to expand the inflatable
`element radially outward and set the packer.
`10. The method of claim 7, wherein the downhole
`operation is chemical injection, and wherein the step of
`injecting fluid through the exposed port includes the
`step of injecting chemicals through the exposed port
`into the armulus surrounding the tubing string.
`11. The method of claim 7, wherein the step of releas-
`ing the spring-loaded C-ring valve member to return
`the isolation sleeve back to the closed position allows a
`higher pressure to be exerted through the interior of the
`tubing string than was used to perform the operation.
`12. The method of claim 7, wherein the step of releas-
`ing the spring-loaded C-ring valve member to return
`the isolation sleeve back to the closed position isolates
`the interior of the tubing string from the device per-
`forming the downhole operation so that a corrosive
`fluid may be passed through the interior of the tubing
`string and remain isolated from the device.
`13. A method of setting a packer which is coupled to
`a tubing string, comprising the steps of:
`isolating a setting port from the interior of the tubing
`string with an isolation sleeve;
`dropping a ball into the tubing string and landing the
`ball on a spring-loaded C-ring valve member;
`applying fluid pressure through the tubing string to
`move the isolation sleeve and open the setting port
`to fluid flow;
`injecting fluid through the exposed port to set the
`packer;
`increasing the fluid pressure to separate the shear ring
`and allow the C-ring valve member to expand into
`a recess;
`expending the ball through the bore of the expanded
`C-ring valve member; and
`releasing the spring-loaded C-ring valve member to
`return the isolation sleeve back to the closed posi-
`tion so that the setting port is isolated from the
`interior of the tubing string.
`14. The method of claim 13, wherein the step of in-
`jecting fluid through the exposed port to set the packer
`includes the step of injecting fluid through the exposed
`port to act against a piston to compress the packer seal
`element radially outward to set the packer.
`15. The method of claim 14, wherein the step of in-
`jecting fluid through the exposed port to act against a
`piston to compress the packer seal element radially
`outward to set the packer includes the step of expanding
`a slip assembly radially outward to retain the packer in
`position in the wellbore.
`16. The method of claim 13, wherein the step of in-
`jecting fluid through the exposed port to set the packer
`includes the step of injecting fluid through the exposed
`port and into the inflatable element of the packer to
`expand the inflatable element radially outward to set the
`packer.
`17. A method for setting a packer having setting ports
`coupled to a tubing string comprising the steps:
`
`10
`
`15
`
`20
`
`25
`
`30
`
`35
`
`45
`
`50
`
`55
`
`60
`
`65
`
`Page 9 of 10
`Page 9 of 10
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`

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`9
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`5,375,662
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`10
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`covering setting ports with an isolation Sleeve;
`.
`.
`.
`.
`.
`
`.
`
`aroppwgagamhsstmggdnon
`
`a spring- oa e
`
`-nng v ve mem er;
`
`increasing the hydraulic setting pressure to shift the 5
`isolation sleeve and C-ring valve member to an
`uncovered port position;
`_
`_
`_
`_
`_
`_
`_
`.
`injecting the hydraulic setting fluid into the inflatable
`packer through the exposed port;
`
`10
`
`15
`
`20
`
`30
`
`35
`
`45
`
`50
`
`55
`
`65
`
`increasing the hydraulic setting pressure to separate
`th C-' ft
`lal
`th'lt'
`1
`d
`
`:‘:§a;;;“:iV:':em:;:°i: ::i‘;::::;::
`
`counterbore in the isolation sleeve; and,
`moving the ball through the bore of the expanded
`C‘1'iI1g Va1Ve membefi
`_
`_
`_
`_
`18. A method as defined in claim 17, including the
`step of biasing the isolation sleeve with a coil spring for
`movement toward the covered Position.
`*
`*
`*
`*
`*
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`Page 10 of 10
`Page 10 of 10