US007762323B2
`
`(12) United States Patent
`Frazier
`
`(10) Patent N0.:
`(45) Date of Patent:
`
`US 7,762,323 B2
`Jul. 27, 2010
`
`(54)
`
`(75)
`
`COMPOSITE CEMENT RETAINER
`
`Inventor: W. Lynn Frazier, 713 Snug Harbor,
`Corpus Christi, TX (US) 78409
`
`(73)
`
`Assignee: W. Lynn Frazier, Corpus Christi, TX
`(Us)
`
`(*)
`
`Notice:
`
`Subject to any disclaimer, the term of this
`patent is extended or adjusted under 35
`U.S.C. 154(b) by 49 days.
`
`(21)
`
`(22)
`
`(65)
`
`(60)
`
`(51)
`
`(52)
`
`(58)
`
`(56)
`
`Appl. No.: 11/851,520
`
`Filed:
`
`Sep. 7, 2007
`
`Prior Publication Data
`
`US 2008/0073074 A1
`
`Mar. 27, 2008
`
`Related US. Application Data
`
`Provisional application No. 60/846,984, ?led on Sep.
`25, 2006.
`
`Int. Cl.
`(2006.01)
`E21B 33/12
`US. Cl. ..................... .. 166/126; 166/133; 166/138;
`166/135; 166/142;166/332.4
`Field of Classi?cation Search ............... .. 166/ 123,
`166/126,133,138,118,129,135,142,146,
`166/185, 194, 216, 332.1, 332.4, 334.1
`See application ?le for complete search history.
`
`References Cited
`
`U.S. PATENT DOCUMENTS
`
`2,368,428
`3,275,080
`3,289,762
`3,289,769
`3,292,707
`3,298,437
`3,298,440
`3,306,362
`3,995,692
`
`A
`A
`A
`A
`A
`A
`A
`A
`A
`
`1/1945
`9/1966
`12/1966
`12/1966
`12/1966
`1/1967
`1/1967
`2/1967
`12/1976
`
`Saurenman
`Nelson et al.
`Schell et al.
`Nelson et al.
`Nelson et al.
`Conrad
`
`Current .................... .. 277/340
`Urbano sky
`Seitz et al.
`
`5/1979 Sullaway
`4,151,875 A
`4,176,717 A 12/1979 HiX
`4,427,071 A
`1/1984 Carmody
`4,444,266 A
`4/1984 Pringle
`4,457,376 A
`7/1984 Carmody et al.
`4,478,286 A 10/1984 Fineberg
`4,583,596 A
`4/1986 Davis
`4,637,468 A
`1/1987 Derrick
`4,708,202 A 11/1987 Sukup et a1.
`4,784,226 A 11/1988 Wyatt
`4,813,481 A
`3/1989 Sproul et al.
`
`4,834,184 A *
`5,012,867 A
`5,224,540 A
`
`5/1989 Streich et a1. ............. .. 166/376
`5/1991 Kilgore
`7/1993 Streich et a1.
`
`(Continued)
`OTHER PUBLICATIONS
`
`Garry Gar?eld, “Composite Bridge Plug Technique for Multizone
`Commingled Gas Wells” in Society of Petroleum Engineers Inc.,
`Mar. 24-27, 2001, Oklahoma City, Oklahoma.
`
`Primary ExamineriDavid J Bagnell
`Assistant ExamineriElizabeth C Gottlieb
`(74) Attorney, Agent, or FirmiEdmonds & Nolte, PC.
`
`(57)
`
`ABSTRACT
`
`A doWnhole plug that can include a body and an element
`system disposed about the body. The plug can further include
`a ?rst and second back-up ring member having tWo or more
`tapered Wedges. The tapered Wedges can be at least partially
`separated by tWo or more converging grooves. First and sec
`ond cones can be disposed adjacent the ?rst and second back
`up ring members.
`
`14 Claims, 7 Drawing Sheets
`
`300
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`US 7,762,323 B2
`Page 2
`
`US. PATENT DOCUMENTS
`
`6/1994 Baker
`5,318,131 A
`2/1995 Jacobi et a1. .............. .. 166/184
`5,390,737 A *
`7/1996 Branchet 91-
`5,540,279 A
`5564502 A 10/1996 Crow @191
`5,701,959 A 12/1997 Hushbeck et a1.
`5,819,846 A 10/1998 B01911
`5,839,515 A 11/1998 Yuan eta1~
`5904207 A
`5/1999 Rubbo eta1~
`5,924,696 A
`7/1999 Frazier
`5,984,007 A 11/1999 Yuan et a1.
`6,131,656 A 10/2000 Jani
`6,167,963 B1
`1/2001 McMahan etal.
`6,196,261 B1
`3/2001 Dennistoun
`6,220,349 B1
`4/2001 vargus et a1,
`6,227,299 B1
`5/2001 Dennistoun
`6,328,112 B1
`12/2001 Malone
`6,386,288 B1
`5/2002 Snider et a1‘
`6,481,496 B1
`110002 Jackson et a1‘
`6,491,108 B1
`12/2002 Slup et al.
`
`3/2003 Snider
`6,536,524 B1
`4/2003 Tolman etal.
`6,543,538 B2
`5/2003 Budde
`6,561,270 B1
`6/2003 Demon
`6,575,249 B2
`6/2003 Zimmerman et al.
`6,581,681 B1
`6,712,153 B2* 3/2004 Turley et a1. .............. .. 166/387
`6,732,803 B2
`5/2004 Garcia et all‘
`6,796,376 B2
`9/2004 Frazier
`6,808,020 B2 10/2004 Garcia et a1.
`6,957,699 B2 10/2005 Feluch et al.
`6,997,263 B2
`2/2006 Campbell et a1.
`7,086,481 B2
`8/2006 Hosie et a1.
`2002/0125011 A1
`9/2002 Snideretal.
`2003/0047315 A1
`3/2003 Allamon
`2004/0177952 A1
`9/2004 Turleyetal.
`2005/0087335 A1
`4/2005 Vick, Jr.
`2006/0048936 A1
`3/2006 FriPP etal
`2006/0070744 A1
`4/2006 Smith
`2006/0124310 A1
`6/2006 Lopez de Cardenas et a1.
`2006/0124311 A1
`6/2006 Lopez de Cardenas et a1.
`* cited by examiner
`
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`

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`US. Patent
`
`Jul. 27, 2010
`
`Sheet 1 of7
`
`US 7,762,323 B2
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`100
`k
`
`110
`
`160
`165
`180
`182
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`140
`
`130
`
`170
`165
`120
`
`125
`
`145
`
`185
`
`FIG. 1
`
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`US. Patent
`
`Jul. 27, 2010
`
`Sheet 2 of7
`
`US 7,762,323 B2
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`2A ‘— 230
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`MEGCO Ex. 1023
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`US. Patent
`
`Jul. 27, 2010
`
`Sheet 3 of7
`
`US 7,762,323 B2
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`100
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`175
`160
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`180
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`140
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`120
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`150
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`185
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`US. Patent
`
`Jul. 27, 2010
`
`Sheet 4 of7
`
`US 7,762,323 B2
`
`2405
`
`240A
`
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`

`

`U.S. Patent
`
`Jul. 27, 2010
`
`Sheet 5 of 7
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`US 7,762,323 B2
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`
`Jul. 27, 2010
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`US. Patent
`
`Jul. 27, 2010
`
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`US 7,762,323 B2
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`

`US 7,762,323 B2
`
`1
`COMPOSITE CEMENT RETAINER
`
`REFERENCE TO RELATED APPLICATIONS
`
`This application claims bene?t of Us. Provisional Patent
`Application having Ser. No. 60/846,984, ?led on Sep. 25,
`2006, Which is incorporated by reference herein.
`
`BACKGROUND OF THE INVENTION
`
`1. Field of the Invention
`Embodiments of the present invention generally relate to a
`composite doWnhole tool for hydrocarbon production and
`method for using same. More particularly, embodiments of
`the present invention generally relate to a composite cement
`retainer and method for using same.
`2. Description of the Related Art
`A Wellbore is drilled to some depth beloW the surface to
`recover hydrocarbons from subterranean formations. The
`Wellbore can be lined With tubulars or casing to strengthen the
`Walls of the borehole. To further strengthen the Walls of the
`borehole, the annular area formed betWeen the casing and the
`borehole can be ?lled With cement to permanently set the
`casing in the Wellbore.
`Cement is typically pumped from the surface through the
`casing and forced out from the bottom of the casing and
`upWardly into the annulus betWeen the casing and the bore
`hole. To facilitate the cementing process, a ?oat shoe and/ or a
`?oat collar is inserted in or adjacent the bottom of the casing.
`The ?oat shoe and/or ?oat collar are essentially check vales
`Which alloW the ?oW of cement from inside of the casing to
`the annular space betWeen the casing and the borehole and
`prevent opposite ?oW therethrough.
`Once the ?oat shoe and/or ?oat collar are located at the
`bottom of the casing, a bottom plug is then pumped through
`the casing by the cement. After a su?icient amount of cement
`has been introduced into the casing, a top plug is places on top
`of the column of cement. The cement that is bound betWeen
`the top plug and the bottom plug is pumped doWn the casing,
`eg by drilling mud, until the bottom plug lands on the ?oat
`shoe and/or ?oat collar. When the bottom plug lands on the
`?oat shoe and/or ?oat collar, the pressure on the top plug is
`increased until a diaphragm in the bottom plug ruptures
`thereby alloWing the cement to pass through the ?oat shoe
`and/ or ?oat collar and ?oW around the bottom of the casing
`and upWardly through the annular space betWeen the casing
`and the Wellbore. After the cement has set, the top plug,
`bottom plug and any cement set in the casing are drilled out to
`form a clear path through the Wellbore.
`The valves and cement in the casing are typically destroyed
`With a rotating milling or drilling device. As the mill contacts
`the valves and cement, the valves and cement are “drilled up”
`or reduced to small pieces that are either Washed out or simply
`left at the bottom of the Wellbore. The more metal parts
`making up the valves, the longer the milling operation takes.
`Metallic components also require numerous trips in and out
`of the Wellbore to replace Worn out mills or drill bits. Depend
`ing on the types (i.e. hardness) of the metals in the valves, the
`drilling removal operation can be extremely timely and
`expensive for a Well operator.
`Once the casing is set in the Wellbore and the ?oat shoe and
`?oat collar have been removed from the Wellbore, the casing
`is then perforated to alloW production ?uid to enter the Well
`bore and be retrieved at the surface of the Well.
`During production, tools With sealing capability are typi
`cally placed Within the Wellbore to isolate the production ?uid
`or to manage production ?uid ?oW through the Wellbore. The
`
`20
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`2
`tools, such as plugs or packers for example, typically have
`external gripping members and sealing members disposed
`about a body. Such body and gripping members are typically
`made of metallic components that dif?cult to drill or mill. The
`sealing member is typically made of a composite or synthetic
`rubber material Which seals off an annulus Within the Well
`bore to prevent the passage of ?uids. The sealing member is
`compressed, thereby expanding radially outWard from the
`tool to sealingly engage the surrounding casing or tubular. For
`example, bridge plugs and frac-plugs are placed Within the
`Wellbore to isolate upper and loWer sections of production
`Zones, and packers are used to seal-off an annulus betWeen
`tWo tubulars Within the Wellbore.
`In Workover operations, cement retainers or cement
`retainer plugs are typically used to close leaks or perforated
`casing. Certain cement retainers have similar external grip
`ping and sealing members to seal and grip the surrounding
`Well bore or casing, and a valve Which canbe used to open and
`close off cementing ports. The retainer is run on either a
`Wireline or a tubing string, and the gripping and sealing
`members are actuated to seal off the annular space Within the
`Wellbore betWeen the retainer and the surrounding casing.
`Cement is then pumped through the tubing string, through the
`interior of the retainer, and out the cementing ports to repair
`the surrounding casing. Such retainers are also constructed of
`metallic components Which must be milled or drilled up to
`remove the retainer from the Wellbore once the cementing j ob
`is complete.
`There is a need, therefore, for a non-metallic plug that can
`effectively seal off an annulus Within a Wellbore and is easier
`and faster to mill. There is also a need for a non-metallic
`cement retainer that can effectively seal off an annulus for
`cementing operations and is easier and faster to mill.
`
`SUMMARY OF THE INVENTION
`
`A non-metallic sealing system, tool, cement retainer, and
`method for using the same are provided. In at least one spe
`ci?c embodiment, the plug includes a body and an element
`system disposed about the body. The plug further includes a
`?rst and second back-up ring member having tWo or more
`tapered Wedges. The tapered Wedges are at least partially
`separated by tWo or more converging grooves. First and sec
`ond cones are disposed adjacent the ?rst and second back-up
`ring members.
`In at least one other speci?c embodiment, the plug includes
`a body; an element system disposed about a ?rst end of the
`body; a ?rst and second back-up ring member having tWo or
`more tapered Wedges, Wherein the tapered Wedges are at least
`partially separated by tWo or more converging grooves; a ?rst
`and second cone disposed adjacent the ?rst and second back
`up ring members; a collet valve assembly disposed about a
`second end of the body. The collet valve assembly includes a
`housing having a ?rst and second shoulder disposed on an
`inner surface thereof and one or more ports formed there
`through; a collet disposed Within the housing, the collet hav
`ing a body and tWo or more ?ngers disposed thereon, the
`?ngers having a ?rst end With an enlarge outer diameter
`adapted to engage the ?rst shoulder of the housing, Wherein
`the body includes a section having an enlarged outer diameter
`adapted to engage the second shoulder of the housing.
`In at least one speci?c embodiment, the composite cement
`retainer includes a housing having a ?rst and second shoulder
`disposed on an inner surface thereof and one or more ports
`formed therethrough; and a collet disposed Within the hous
`ing, the collet having a body and tWo or more ?ngers disposed
`thereon. The ?ngers include a ?rst end having an enlarged
`
`MEGCO Ex. 1023
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`US 7,762,323 B2
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`3
`outer diameter adapted to engage the ?rst shoulder of the
`housing. The body includes a section having an enlarged
`outer diameter adapted to engage the second shoulder of the
`housing.
`
`BRIEF DESCRIPTION OF THE DRAWINGS
`
`So that the manner in Which the above recited features of
`the present invention can be understood in detail, a more
`particular description of the invention, brie?y summarized
`above, can be had by reference to embodiments, some of
`Which are illustrated in the appended draWings. It is to be
`noted, hoWever, that the appended draWings illustrate only
`typical embodiments of this invention and are therefore not to
`be considered limiting of its scope, for the invention can
`admit to other equally effective embodiments.
`FIG. 1 depicts a partial section vieW of an illustrative
`non-metallic, doWnhole tool in accordance With one or more
`embodiments described.
`FIG. 2 depicts a plan vieW of an illustrative back up ring
`according to one or more embodiments described.
`FIG. 2A depicts a cross sectional vieW of the back up ring
`shoWn in FIG. 2 along lines 2A-2A.
`FIG. 3 depicts a plan vieW ofthe back up ring of FIG. 2 in
`an expanded or actuated position.
`FIG. 3A depicts a cross sectional vieW of the actuated back
`up ring shoWn in FIG. 3 along lines 3A-3A.
`FIG. 4 depicts a partial section vieW of the plug of FIG. 1
`located Within a Wellbore or borehole.
`FIG. 5 depicts a partial section vieW of the plug of FIG. 4
`actuated in the Wellbore or borehole.
`FIG. 6 depicts an illustrative isometric of the back-up ring
`of FIG. 2 in an expanded or actuated position.
`FIG. 7 depicts a partial section vieW of an illustrative
`bridge plug having an illustrative collet valve assembly
`attached thereto, in accordance With one or more embodi
`ments described.
`FIG. 8 depicts a partial section vieW of the collet valve
`assembly in a closed or run-in position.
`FIG. 8A depicts a section vieW of the collet shoWn in FIG.
`8. The collet ?ngers are depicted in an expanded/valve-closed
`position.
`FIG. 9 depicts a partial section vieW of the collet valve
`assembly in an open or operating position.
`FIG. 9A depicts a section vieW of the collet shoWn in FIG.
`9. The collet ?ngers are depicted in a retracted/valve-opened
`position.
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`DETAILED DESCRIPTION OF THE PREFERRED
`EMBODIMENT
`
`50
`
`A detailed description Will noW be provided. Each of the
`appended claims de?nes a separate invention, Which for
`infringement purposes is recogniZed as including equivalents
`to the various elements or limitations speci?ed in the claims.
`Depending on the context, all references beloW to the “inven
`tion” can in some cases refer to certain speci?c embodiments
`only. In other cases it Will be recogniZed that references to the
`“invention” Will refer to subject matter recited in one or more,
`but not necessarily all, of the claims. Each of the inventions
`Will noW be described in greater detail beloW, including spe
`ci?c embodiments, versions and examples, but the inventions
`are not limited to these embodiments, versions or examples,
`Which are included to enable a person having ordinary skill in
`the art to make and use the inventions, When the information
`in this patent is combined With available information and
`technology.
`
`55
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`60
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`65
`
`As used herein, the terms “connect , connection , con
`nected”, “in connection With”, and “connecting” refer to “in
`direct connection With” or “in connection With via another
`element or member.”
`The terms “up” and “doWn”; “upper” and “loWer”;
`“upWardly” and doWnWardly”; “upstream” and “doWn
`stream”; “above” and “beloW”; and other like terms as used
`herein refer to relative positions to one another and are not
`intended to denote a particular direction or spatial orientation.
`In one or more embodiments, a non-metallic sealing sys
`tem for a doWnhole tool is provided. FIG. 1 depicts a partial
`schematic of an illustrative doWnhole tool in accordance With
`one or more embodiments described. The non-metallic seal
`ing system can be used on either a metal or more preferably,
`a non-metallic mandrel or body. The non-metallic sealing
`system can also be used With a holloW or solid mandrel. For
`example, the non-metallic sealing system can be used With a
`bridge plug and frac-plug to seal off a Wellbore and the
`sealing system can be used With a packer to pack-off an
`annulus betWeen tWo tubulars disposed in a Wellbore.
`In one or more embodiments, the doWnhole tool can be a
`single assembly (i.e. one tool or plug), as depicted in FIG. 1,
`or tWo or more assemblies (i.e. tWo or more tools or plugs)
`disposed Within a Work string or otherWise connected thereto
`that is run into a Wellbore on a Wireline, slickline, production
`tubing, coiled tubing or any technique knoWn or yet to be
`discovered in the art. For simplicity and ease of description,
`the tool of the present invention Will be further described With
`reference to a bridge plug 100.
`Referring to FIG. 1, the bridge plug 100 includes a mandrel
`(“body”) 110, ?rst and second back-up ring members 120,
`125, ?rst and second slip members 140, 145, element system
`150, ?rst and second lock rings 160, 170, and support rings
`180, 185. Each ofthe members, rings and elements 120, 125,
`140, 145, 150, 160, and 170 are disposed about the body 110.
`One or more of the body, members, rings, and elements 110,
`120, 125, 140, 145, 150, 160, 170, 180, 185 can be con
`structed of a non-metallic material, preferably a composite
`material, and more preferably a composite material described
`herein. In one or more embodiments, each of the members,
`rings and elements 120,125, 140, 145, 150, 180, and 185 are
`constructed of a non-metallic material.
`FIG. 2 depicts a plan vieW of an illustrative back up ring
`member 120, 125 according to one or more embodiments
`described. FIG. 2A depicts a cross sectional vieW of the back
`up ring member 120, 125 shoWn in FIG. 2 along lines 2A-2A.
`Referring to FIGS. 2 and 2A, the back up ring member 120,
`125 can be and is preferably constructed of one or more
`non-metallic materials. In one or more embodiments, the
`back up ring members 120, 125 can be one or more annular
`members having a ?rst section 210 of a ?rst diameter that
`steps up to a second section 220 of a second diameter. A
`recessed groove or void 225 can be disposed or de?ned
`betWeen the ?rst and second sections 210. As Will be
`explained in more detail beloW, the groove or void 225 alloWs
`the ring member 120, 125 to expand.
`The ?rst section 210 can have a sloped or tapered outer
`surface as shoWn. In one or more embodiments, the ?rst
`section 210 can be a separate ring or component that is con
`nected to the second section 220, as is the ?rst back up ring
`member 120 depicted in FIG. 1. In one or more embodiments,
`the ?rst and second sections 210, 220 can be constructed from
`a single component, as is the second back up ring member 125
`depicted in FIG. 1. If the ?rst and second sections 210, 220 are
`separate components, the ?rst section 210 can be threadably
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`US 7,762,323 B2
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`5
`connected to the second section 220. As such, the tWo non
`metallic components (?rst and second sections 210, 220) are
`threadably engaged.
`In one or more embodiments, the back up ring members
`120, 125 can include tWo or more tapered pedals or Wedges
`230 (eight are shoWn in this illustration). The tapered Wedges
`230 are at least partially separated by tWo or more converging
`grooves or cuts 240. The grooves 240 are preferably located in
`the second section 220 to create the Wedges 230 therebe
`tWeen. The number of grooves 240 can be determined by the
`siZe of the annulus to be sealed and the forces exerted on the
`back up ring 120, 125.
`Considering the grooves 240 in more detail, the grooves
`240 each include at least one radial cut or groove 240A and at
`least one circumferential cut or groove 240B. By “radial” it is
`meant that the cut or groove traverses a path similar to a radius
`of a circle. In one or more embodiments, the grooves 240 each
`include at least tWo radial grooves 240A and at least one
`circumferential groove 240B disposed therebetWeen, as
`shoWn in FIGS. 2 and 3 . As shoWn, the circumferential groove
`240B intersects or otherWise connects With both of the tWo
`radial grooves 240A located at opposite ends thereof.
`In one or more embodiments, the intersection of the radial
`grooves 240A and circumferential grooves 240B form an
`angle of from about 30 degrees to about 150 degrees. In one
`or more embodiments, the intersection of the radial grooves
`240A and circumferential grooves 240B form an angle of
`from about 50 degrees to about 130 degrees. In one or more
`embodiments, the intersection of the radial grooves 240A and
`circumferential grooves 240B form an angle of from about 70
`degrees to about 110 degrees. In one or more embodiments,
`the intersection of the radial grooves 240A and circumferen
`tial grooves 240B form an angle of from about 80 degrees to
`about 100 degrees. In one or more embodiments, the inter
`section of the radial grooves 240A and circumferential
`grooves 240B form an angle of about 90 degrees.
`In one or more embodiments, the one or more Wedges 230
`of the ring member 120, 125 are angled or tapered from the
`central bore therethrough toWard the outer diameter thereof,
`ie the Wedges 230 are angled outWardly from a center line or
`axis of the back up ring 120, 125. Preferably the tapered angle
`ranges from about 10 degrees to about 30 degrees.
`As Will be explained beloW in more detail, the Wedges 230
`are adapted to hinge or pivot radially outWard and/ or hinge or
`pivot circumferentially. The groove or void 225 is preferred to
`facilitate such movement. The Wedges 230 pivot, rotate or
`otherWise extend radially outWard to contact an inner diam
`eter of the surrounding tubular or borehole (not shoWn). The
`radial extension increases the outer diameter of the ring mem
`ber 120, 125 to engage the surrounding tubular or borehole,
`and provides an increased surface area to contact the sur
`rounding tubular or borehole. Therefore, a greater amount of
`frictional force can be generated against the surrounding
`tubular or borehole, providing a better seal therebetWeen.
`In one or more embodiments, the Wedges 230 are adapted
`to extend and/or expand circumferentially as the one or more
`back up ring members 120, 125 are compressed and
`expanded. The circumferential movement of the Wedges 230
`provides a sealed containment of the element system 150
`therebetWeen. The angle of taper and the orientation of the
`grooves 240 maintain the ring members 120, 125 as a solid
`structure. For example, the grooves 240 can be milled,
`grooved, sliced or otherWise cut at an angle relative to both the
`horizontal and vertical axes of the ring members 120, 135 so
`that the Wedges 230 expand or blossom, remaining at least
`partially connected and maintain a solid shape against the
`element system 150 (i.e. provide con?nement). Accordingly,
`
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`the element system 150 is restrained and/ or contained by the
`ring members 120, 125 and not able to leak or otherWise
`traverse the rings members 120, 125.
`FIG. 3 depicts a plan vieW ofthe back up ring of FIG. 2 in
`an expanded or actuated position, and FIG. 3A depicts a cross
`sectional vieW of the back up ring shoWn in FIG. 3 along lines
`3A-3A. Referring to FIGS. 3 and 3A, the Wedges 230 are
`adapted to pivot or otherWise move axially Within the void
`225, thereby hinging the Wedges 230 radially and increasing
`the outer diameter of the ring member 120, 125. The Wedges
`230 are also adapted to rotate or otherWise move radially
`relative to one another. Such movement can be seen in this
`vieW, depicted by the narroWed space Within the grooves 240.
`As mentioned above, the back up ring members 120, 125
`can be one or more separate components. In one or more
`embodiments, at least one end of the ring member 120, 125 is
`conical shaped or otherWise sloped to provide a tapered sur
`face thereon. In one or more embodiments, the tapered por
`tion of the ring members 120, 125 can be a separate cone 130
`disposed on the ring member 120, 125 having the Wedges 230
`disposed thereon, as depicted in FIG. 1 With reference to the
`ring member 120. The cone 130 can be secured to the body
`110 by a plurality of shearable members such as screWs or
`pins (not shoWn) disposed through one or more receptacles
`133.
`In one or more embodiments, the cone 130 or tapered
`member includes a sloped surface adapted to rest underneath
`a complimentary sloped inner surface of the slip members
`140, 145. As Will be explained in more detail beloW, the slip
`members 140, 145 travel about the surface of the cone 130 or
`ring member 125, thereby expanding radially outWard from
`the body 110 to engage the inner surface of the surrounding
`tubular or borehole.
`Each slip member 140, 145 can include a tapered inner
`surface conforming to the ?rst end of the cone 130 or sloped
`section of the ring member 125. An outer surface of the slip
`member 140, 145 can include at least one outWardly extend
`ing serration or edged tooth, to engage an inner surface of a
`surrounding tubular (not shoWn) if the slip member 140, 145
`moves radially outWard from the body 110 due to the axial
`movement across the cone 130 or sloped section of the ring
`member 125.
`The slip member 140, 145 can be designed to fracture With
`radial stress. In one or more embodiments, the slip member
`140, 145 can include at least one recessed groove 142 milled
`therein to fracture under stress alloWing the slip member 140,
`145 to expand outWards to engage an inner surface of the
`surrounding tubular or borehole. For example, the slip mem
`ber 140, 145 can include tWo or more, preferably four, sloped
`segments separated by equally spaced recessed grooves 142
`to contact the surrounding tubular or borehole, Which become
`evenly distributed about the outer surface of the body 110.
`The element system 150 can be one or more separate com
`ponents. Three components are shoWn in FIG. 1. The element
`system 150 can be constructed of any one or more malleable
`materials capable of expanding and sealing an annulus Within
`the Wellbore. The element system 150 is preferably con
`structed of one or more synthetic materials capable of With
`standing high temperatures and pressures. For example, the
`element system 150 can be constructed of a material capable
`of Withstanding temperatures up to 4500 F., and pressure
`differentials up to 15,000 psi. Illustrative materials include
`elastomers, rubbers, Te?on®, blend and combinations
`thereof.
`In one or more embodiments, the element system 150 can
`have any number of con?gurations to effectively seal the
`annulus. For example, the element system 150 can include
`
`MEGCO Ex. 1023
`
`

`

`US 7,762,323 B2
`
`7
`one or more grooves, ridges, indentations, or protrusions
`designed to allow the element system 150 to conform to
`variations in the shape of the interior of a surrounding tubular
`(not shoWn) or borehole.
`Referring again to FIG. 1, the support ring 180 can be
`disposed about the body 110 adjacent a ?rst end of the slip
`140. The support ring 180 can be an annular member having
`a ?rst end that is substantially ?at. The ?rst end serves as a
`shoulder adapted to abuts a setting tool described beloW. The
`support ring 180 can include a second end adapted to abuts the
`slip 140 and transmit axial forces therethrough. A plurality of
`pins can be inserted through receptacles 182 to secure the
`support ring 180 to the body 110.
`In one or more embodiments, tWo or more lock rings 160,
`170 can be disposed about the body 110. In one or more
`embodiments, the lock rings 160, 170 can be split or “C”
`shaped alloWing axial forces to compress the rings 160, 170
`against the outer diameter of the body 110 and hold the rings
`160, 170 and surrounding components in place. In one or
`more embodiments, the lock rings 160, 170 can include one or
`more serrated members or teeth that are adapted to engage the
`outer diameter of the body 11 0. Preferably, the lock rings 160,
`170 are constructed of a harder material relative to that of the
`body 110 so that the rings 160, 170 can bite into the outer
`diameter of the body 110. For example, the rings 160, 170 can
`be made of steel and the body 110 made of aluminum.
`In one or more embodiments, one or more of the lock rings
`160, 170 canbe disposed Within a lock ring housing 165. Both
`the ?rst and second lock rings 160, 170 are shoWn in FIG. 1
`disposed Within a housing 165. In one or more embodiments,
`the lock ring housing 165 has a conical or tapered inner
`diameter that complements a tapered angle on the outer diam
`eter of the lock rings 160, 170. Accordingly, axial forces in
`conjunction With the tapered outer diameter of the lock ring
`housing 165 urge the lock ring 160, 170 toWards the body 110.
`Still referring to FIG. 1, the body 110 can include one or
`more shear points 175 disposed thereon. The shear point 175
`is a designed Weakness located Within the body 110, and is
`preferably located at an upper portion of the body 110. In one
`or more embodiments, the shear point 175 can be a portion of
`the body 110 having a reduced Wall thickness, creating a Weak
`or fracture point therein. In one or more embodiments, the
`shear point 175 can be a portion of the body 110 constructed
`of a Weaker material. The shear point 175 is designed to
`Withstand a predetermined stress and is breakable by pulling
`and/ or rotating the body 110 in excess of that stress.
`The plug 100 can be installed in a vertical or horiZontal
`Wellbore. The plug 100 can be installed With a non-rigid
`system, such as an electric Wireline or coiled tubing. Any
`commercial setting tool adapted to engage the upper end of
`the plug 100 can be used to activate the plug 100 Within the
`Wellbore. Speci?cally, an outer movable portion of the setting
`tool can be disposed about the outer diameter of the support
`ring 180. An inner portion of the setting tool can be fastened
`about the outer diameter of the body 1 10. The setting tool and
`plug 100 are then run into the Wellbore to the desired depth
`Where the plug 100 is to be installed as shoWn in FIG. 4.
`FIG. 4 depicts an illustrative schematic of the plug 100
`located Within a Well bore 400. To set or activate the plug 100,
`the body 110 can be held by the Wireline, through the inner
`portion of the setting tool, While an axial force can be applied
`through a setting tool (not shoWn) to the support ring 180. The
`axial forces cause the outer portions of the plug 100 to move
`axially relative to the body 110.
`FIG. 5 depicts an illustrative schematic of the plug 100
`activated in the Well bore 400. As shoWn, the doWnWard axial
`force asserted against the support ring 180 and the upWard
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`axial force on the body 110 translates the forces to the move
`able disposed slip members 140, 145 and back up ring mem
`bers 120, 125. The slip members 140,145 move up and across
`the tapered surfaces of the back up ring members 120, 125 or
`separate cone 130 and contact an inner surface of a surround
`ing tubular 400. The axial and radial forces applied to the slip
`members 140, 145 causes the recessed grooves 142 to frac
`ture into equal segments, permitting the serrations or teeth of
`the slip members 140, 145 to ?rmly engage the inner surface
`of the surrounding tubular 400.
`The oppo