US20050217866A1 - Mono diameter wellbore casing - Google Patents
Mono diameter wellbore casing Download PDFInfo
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- US20050217866A1 US20050217866A1 US10/513,614 US51361404A US2005217866A1 US 20050217866 A1 US20050217866 A1 US 20050217866A1 US 51361404 A US51361404 A US 51361404A US 2005217866 A1 US2005217866 A1 US 2005217866A1
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- United States
- Prior art keywords
- tubular member
- expandable tubular
- passage
- anchoring device
- expandable
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
- E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
- E21B43/105—Expanding tools specially adapted therefor
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
- E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
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- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Piles And Underground Anchors (AREA)
- Shaping Of Tube Ends By Bending Or Straightening (AREA)
- Prostheses (AREA)
Abstract
An apparatus and system is disclosed for radially expanding and plastically deforming an expandable tubular member.
Description
- The present application is the National Stage application corresponding to PCT application serial number PCT/US2003/014153, attorney docket number 25791.104.02, filed on May 6, 2003, which claimed the benefit of the filing date of U.S. provisional patent application Ser. No. 60/380,147, attorney docket no 25791.104, filed on May 6, 2002, the disclosures of which are incorporated herein by reference.
- The present application is a continuation-in-part of U.S. utility patent application Ser. No. 10/507,567, attorney docket number 25791.95.03, filed on Sep. 13, 2004, which was the National Stage application for PCT application serial number PCT/US2003/004837, attorney docket number 25791.95.02, filed on Feb. 19, 2003, which claimed the benefit of the filing date of U.S. provisional patent application Ser. No. 60/363829, attorney docket number 25791.95, filed on Mar. 13, 2002, which was a continuation-in-part of both of: (1) U.S. utility patent application Ser. No. 10/495,347, attorney docket number 25791.87.05, filed on May 12, 2004, which was filed as the National Stage application for PCT application serial number PCT/US2002/036157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, which claimed the benefit of the filing date of U.S. provisional application Ser. No. 60/338996, attorney docket number 25791.87, filed on Nov. 12, 2001; and (2) U.S. utility patent application Ser. No. 10/495,344, attorney docket number 25791.88.05, filed on May 12, 2004, which was filed as the National Stage application for PCT application serial number PCT/US2002/036267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, which claimed the benefit of the filing date of U.S. provisional application Ser. No. 60/339013, attorney docket number 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference.
- The present application is related to the following: (1) U.S. patent application Ser. No. 09/454,139, attorney docket no. 25791.03.02, filed on Dec. 3, 1999, (2) U.S. patent application Ser. No. 09/510,913, attorney docket no. 25791.7.02, filed on Feb. 23, 2000, (3) U.S. patent application Ser. No. 09/502,350, attorney docket no. 25791.8.02, filed on Feb. 10, 2000, (4) U.S. patent application Ser. No. 09/440,338, attorney docket no. 25791.9.02, filed on Nov. 15, 1999, (5) U.S. patent application Ser. No. 09/523,460, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, (6) U.S. patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, (7) U.S. patent application Ser. No. 09/511,941, attorney docket no. 25791.16.02, filed on Feb. 24, 2000, (8) U.S. patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, (9) U.S. patent application Ser. No. 09/559,122, attorney docket no. 25791.23.02, filed on Apr. 26, 2000, (10) PCT patent application serial no. PCT/US00/18635, attorney docket no. 25791.25.02, filed on Jul. 9, 2000, (11) U.S. provisional patent application Ser. No. 60/162,671, attorney docket no. 25791.27, filed on Nov. 1, 1999, (12) U.S. provisional patent application Ser. No. 60/154,047, attorney docket no. 25791.29, filed on Sep. 16, 1999, (13) U.S. provisional patent application Ser. No. 60/159,082, attorney docket no. 25791.34, filed on Oct. 12, 1999, (14) U.S. provisional patent application Ser. No. 60/159,039, attorney docket no. 25791.36, filed on Oct. 12, 1999, (15) U.S. provisional patent application Ser. No. 60/159,033, attorney docket no. 25791.37, filed on Oct. 12, 1999, (16) U.S. provisional patent application Ser. No. 60/212,359, attorney docket no. 25791.38, filed on Jun. 19, 2000, (17) U.S. provisional patent application Ser. No. 60/165,228, attorney docket no. 25791.39, filed on Nov. 12, 1999, (18) U.S. provisional patent application Ser. No. 60/221,443, attorney docket no. 25791.45, filed on Jul. 28, 2000, (19) U.S. provisional patent application Ser. No. 60/221,645, attorney docket no. 25791.46, filed on Jul. 28, 2000, (20) U.S. provisional patent application Ser. No. 60/233,638, attorney docket no. 25791.47, filed on Sep. 18, 2000, (21) U.S. provisional patent application Ser. No. 60/237,334, attorney docket no. 25791.48, filed on Oct. 2, 2000, (22) U.S. provisional patent application Ser. No. 60/270,007, attorney docket no. 25791.50, filed on Feb. 20, 2001, (23) U.S. provisional patent application Ser. No. 60/262,434, attorney docket no. 25791.51, filed on Jan. 17, 2001, (24) U.S. provisional patent application Ser. No. 60/259,486, attorney docket no. 25791.52, filed on Jan. 3, 2001, (25) U.S. provisional patent application Ser. No. 60/303,740, attorney docket no. 25791.61, filed on Jul. 6, 2001, (26) U.S. provisional patent application Ser. No. 60/313,453, attorney docket no. 25791.59, filed on Aug. 20, 2001, (27) U.S. provisional patent application Ser. No. 60/317,985, attorney docket no. 25791.67, filed on Sep. 6, 2001, (28) U.S. provisional patent application Ser. No. 60/3318,386, attorney docket no. 25791.67.02, filed on Sep. 10, 2001, (29) U.S. utility patent application Ser. No. 09/969,922, attorney docket no. 25791.69, filed on Oct. 3, 2001, (30) U.S. utility patent application Ser. No. 10/016,467, attorney docket no. 25791.70, filed on Dec. 10, 2001; (31) U.S. provisional patent application Ser. No. 60/343,674, attorney docket no. 25791.68, filed on Dec. 27, 2001; (32) U.S. provisional patent application Ser. No. 60/346,309, attorney docket no 25791.92, filed on Jan. 7, 2002; (33) U.S. provisional patent application Ser. No. 60/372,048, attorney docket no. 25791.93, filed on Apr. 12, 2002; and (34) U.S. provisional patent application Ser. No. 60/372,632, attorney docket no. 25791.101, filed on Apr. 15, 2002, the disclosures of which are incorporated herein by reference.
- This invention relates generally to oil and gas exploration, and in particular to forming and repairing wellbore casings to facilitate oil and gas exploration and production.
- Conventionally, when a wellbore is created, a number of casings are installed in the borehole to prevent collapse of the borehole wall and to prevent undesired outflow of drilling fluid into the formation or inflow of fluid from the formation into the borehole. The borehole is drilled in intervals whereby a casing which is to be installed in a lower borehole interval is lowered through a previously installed casing of an upper borehole interval. As a consequence of this procedure the casing of the lower interval is of smaller diameter than the casing of the upper interval. Thus, the casings are in a nested arrangement with casing diameters decreasing in downward direction. Cement annuli are provided between the outer surfaces of the casings and the borehole wall to seal the casings from the borehole wall. As a consequence of this nested arrangement a relatively large borehole diameter is required at the upper part of the wellbore. Such a large borehole diameter involves increased costs due to heavy casing handling equipment, large drill bits and increased volumes of drilling fluid and drill cuttings. Moreover, increased drilling rig time is involved due to required cement pumping, cement hardening, required equipment changes due to large variations in hole diameters drilled in the course of the well, and the large volume of cuttings drilled and removed.
- The present invention is directed to overcoming one or more of the limitations of the existing processes for forming and repairing wellbore casings.
- According to one aspect of the present invention, an apparatus and method for forming a mono diameter wellbore casing is provided.
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FIGS. 1 a-1 f are conceptual illustrations of one aspect of the present invention. -
FIGS. 2 a-2 f are fragmentary cross-sectional illustrations of the placement of an exemplary embodiment of an apparatus for forming a mono diameter wellbore casing within a wellbore that traverses a subterranean formation. -
FIGS. 3 a-3 f are fragmentary cross-sectional illustrations of the apparatus ofFIGS. 2 a-2 f after placement on the bottom of the wellbore. -
FIGS. 4 a-4 f are fragmentary cross-sectional illustrations of the apparatus ofFIGS. 3 a-3 f after placing a ball or dart within the ball or dart seat to initiate the radial expansion and plastic deformation of the expandable tubular member. -
FIGS. 5 a-5 f are fragmentary cross-sectional illustrations of the apparatus ofFIGS. 4 a-4 f after the initiation of the radial expansion and plastic deformation of the aluminum sleeve within the shoe. -
FIG. 6 a-6 f are fragmentary cross sectional illustrations of the apparatus ofFIGS. 5 a-5 f after the completion of the radial expansion and plastic deformation of the aluminum sleeve within the shoe. -
FIGS. 7 a-7 f are fragmentary cross-sectional illustrations of the apparatus ofFIGS. 6 a-6 f after displacing the sliding sleeve valve within the shoe to permit circulation around the ball or dart. -
FIGS. 8 a-8 f are fragmentary cross-sectional illustrations of an alternative embodiment of a bottom anchoring apparatus. -
FIGS. 9 a-9 g are fragmentary cross sectional illustrations of certain aspects of the operation of the apparatus ofFIGS. 8 a-8 f. - Referring initially to
FIG. 1 a, an embodiment of an apparatus and method for radially expanding a tubular member will now be described. As illustrated inFIG. 1 a, awellbore 100 is positioned in asubterranean formation 105. In an exemplary embodiment, thewellbore 100 may include acasing 110. Thewellbore 100 may be positioned in any orientation from vertical to horizontal. Thus, in this application the direction “up”, “upper” or “upward” refers to the direction towards the surface termination of the wellbore and the direction “down”, “lower” or “downward” refers to the direction towards the bottom or end of the wellbore. - In order to extend the
wellbore 100 into thesubterranean formation 105, a drill string (not shown) is used in a well known manner to drill out material from thesubterranean formation 105 to form thewellbore 100. The inside diameter of thewellbore 100 is greater than or equal to the outside diameter of thecasing 110. - In an exemplary embodiment, a
tubular apparatus 120 having anopening 122 may then be positioned within thewellbore 100 with anupper end 124 a of theapparatus 120 initially coupled to awell string 125. Theapparatus 120 is adapted to allow fluidic materials to enter theupper end 124 a of the tool and exit through theopening 122 positioned at thelower end 124 b of the tool, thereby creating a passage (not shown) orfluid flow path 126. Theapparatus 120 may include, among other components, acasing lock 130, agripping device 132, atension actuator 134, asealing mechanism 136, anexpansion cone 140, acementing probe 144, and acasing anchor 148. - The
apparatus 120 as illustrated inFIG. 1 a is in a “running” or positioning configuration. In other words, the tool is running or traveling down the wellbore. In several exemplary embodiments, in the running configuration, thelower end 124 b of theapparatus 120 extends past thecasing 110 into the wellbore. Thecasing lock 130 may be used to support or couple theapparatus 120 to thecasing 110 which may keep thecasing 110 positioned above thelower end 124 b of the tool when theapparatus 120 is in the running configuration. Alternatively, theexpansion cone 140 may be used to support thecasing 110 during the running or positioning of theapparatus 120. - In one embodiment, the
gripping device 132 may be positioned close to theupper end 124 a of theapparatus 120. In the illustrative embodiment, thegripping device 132 is positioned above thecasing lock 130. As will be explained in detail below, thegripping device 132 may be used to keep thecasing 110 stationary during the operation of theapparatus 120. A force multiplier ortension actuator 134 may be positioned below thecasing lock 130. Thetension actuator 134 may be used to “pull” theexpansion cone 140 and thelower end 124 b of theapparatus 120 inside thecasing 110. In the illustrative embodiment, analternative sealing mechanism 136 may be positioned below thetension actuator 134. - As illustrated in
FIG. 1 a, an apparatus for radially expanding a tubular member, such as anexpansion cone 140 may then be positioned outside of thecasing 110. A tubular member, such as acementing probe 144, may be positioned below theexpansion cone 140. Acasing anchor 148, such as a packer or drillable shoe, may be positioned at thelower end 124 b of theapparatus 120. - Turning now to
FIG. 1 b, there is illustrated theapparatus 120 positioned at the bottom of thewellbore 100. As will be explained in detail below, when theapparatus 120 contacts with the bottom of thewellbore 100, anexpansion mechanism 150, coupled to thecasing anchor 148, expands radially outward such that thecasing 110 cannot move past the expansion mechanism. In one embodiment, theexpansion cone 140 may also expand upon impact with the bottom of the well. The expansion cone may expand to a diameter that is greater than the interior diameter of thecasing 110. - In an exemplary embodiment, as illustrated in
FIG. 1 c, an actuating event may occur to cause thegripping device 132 to grip thecasing 110. Such an actuating event may be placing a plug, such as a ball or dart into theapparatus 120 to block theflow path 126 and prevent fluids from exiting throughopening 122. Injecting a fluidic material into the apparatus when theflow path 126 is blocked causes an increase in pressure within the tool. The increase pressure may actuate gripping elements of thegripping device 132 thereby locking the top end of theapparatus 120 to the expandable tubular member. In some alternative embodiments, the continued injection of the fluidic material furthermore increases the operating pressure within the tool which causes the expansion cone to expand. The increase operating pressure may also cause thetension actuator 134 to pull theexpansion cone 140 into the expandable tubular member. As a result, the casing orexpandable casing 110 is radially expanded as theexpansion cone 140 travels up thecasing 110. - Turning now to
FIG. 1 d, the continued upward movement of theexpansion cone 140 pulls thecasing anchor 148 into the end of the radially expandedcasing 110. As a result, the end of the radially expanded casing 110 will impact theexpansion mechanism 150, thereby preventing thecasing anchor 148 from moving further in the upward direction. In some embodiments, the continued upward force on thecasing anchor 148 may cause the casing anchor to radially expand within the casing to firmly couple the end of the tubular member to thecasing anchor 148. In alternative embodiments, this anchoring may also hydraulically seal theanchor 148 to thecasing 110. - The continued upward force on the
apparatus 120 may cause thecementing probe 144 to separate from thecasing anchor 148, as illustrated inFIG. 1 e. At the top of the stroke, the casing lock 130 (not shown) may be released. After separation, theapparatus 120 is free to continue to advance up causing thecasing 110 to expand as necessary. If a hydraulic seal is created between theanchor 148 and thecasing 110, the region between the anchor and thesealing mechanism 136 may be pressurized. This pressurized region forces the expansion cone upwardly, thereby causing a radial expansion and plastic deformation of theexpandable casing 110. In this manner, in the alternative embodiment, the fluid pressure below thesealing mechanism 136 pulls theexpansion cone 140 upwardly through theexpandable casing 110. Thus, the use of thetension actuator 134 to pull the expansion cone upwards is no longer necessary. - At some point (e.g., at the top of the liner), it may become desirable to stop expanding and to inject a hardenable fluidic sealing material such as, for example, cement into the well annulus. To begin the cementing operation, the
apparatus 120 may be lowered into thewellbore 100 until thecementing probe 144 couples to thecasing anchor 148 as illustrated inFIG. 1 f. This coupling opens abypass flowpath 154 to permit fluidic materials to bypass around the blockage inflow path 126. As a result, thebypass flow path 154 allows for cement or other fluidic materials to flow around the blockage offlow path 126. - Thus, the cement flows through the interior of the
apparatus 120, through thebypass flow path 154, and out through a one-way valve (not shown) into the annulus between the radially expanded tubular member and the wellbore. After the cement has been injected into the annulus, the one way valve may prevent the cement from flowing backwards into theapparatus 120. - After completing the injection of the cement into the annulus, the drilling pipe may then pulled upwardly out of the wellbore. The radial expansion and plastic deformation of the expandable tubular member may then be continued by the resumed injection of fluidic material into the apparatus. After the cement has cured, the
anchor 148 may be drilled out and another expandable tubular member may then be radially expanded and plastically deformed within the wellbore with the upper end of the other tubular member overlapping with the lower end of the earlier expanded tubular member. In this manner, a mono diameter wellbore casing may be formed that includes a plurality of radially expanded tubular members. - Turning now to
FIGS. 2 a-2 f, there is illustrated an exemplary embodiment of anapparatus 200, which illustrates certain aspects of theapparatus 120 discussed above. At the upper end of theapparatus 200, there is thegripping device 132. In several exemplary embodiments, thegripping device 132 may be any device capable of engaging the inside surface of the tubular member or casing 110 in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. In the embodiment as illustrated inFIGS. 2 a-2 f, thegripping device 132 comprises a tubularcentral mandrel 202 which defines acentral passage 203. Thecentral mandrel 202 has anupper end 204 a adapted to threadably couple to and receive within an end of thewell string 125 in a conventional manner. Atubular retaining sleeve 206 slidingly engages thecentral mandrel 202, such that the retainingsleeve 206 may move longitudinally relative to thecentral mandrel 202 between an external annular upper flange 205 a and an external annularlower flange 205 b projecting from thecentral mandrel 202. A pair of concentric annular recesses in the upper flange 205 a form anannular guide flange 209 which fits within the retainingsleeve 206. The retainingsleeve 206 has an internalupper flange 207 a and an internallower flange 207 b. Theupper flange 207 a, theguide flange 209, the external surface of thecentral mandrel 202 and the internal surface of the retainingsleeve 206 defines an annularupper spring chamber 208 a. Similarly, thelower flange 205 b, thelower flange 207 b, the external surface of thecentral mandrel 202 and the internal surface of the retainingsleeve 206 defines an annularlower spring chamber 208 b. Helical springs 210 a and 210 b may be disposed within the upper andlower retaining chambers sleeve 206 relative to thecentral mandrel 202. - A plurality of tapered recesses, for example recesses 212 a-212 d are defined in the external surface of the
central mandrel 202. Corresponding to each recess 212 a-212 d, there is a tapered circular opening, for instance circular openings 214 a-214 d, through the wall of the retainingsleeve 206. The tapered recesses 212 a-212 d, the interior surface of the retainingsleeve 206, and the circular openings 214 a-214 d define retaining chambers 216 a-216 d, respectively. Hardened gripping elements, such as balls 218 a-218 d or sprag clutch elements, made from stainless steel or another hardened material, may be positioned with the retaining chambers 216 a-216 d. In the running configuration illustrated inFIGS. 2 a-2 e, thesprings sleeve 206 such that the balls 218 a-218 d remain in the widest portion of the tapered retaining chambers 216 a-216 d. In this configuration, the balls do not engage the interior surface of the casing orcasing 110. - An
annular pressure chamber 222 may be defined between the bottom of theinternal flange 207 a of the retainingsleeve 206 and the top of an externalannular flange 224. A sealing means, such as an O-ring or sealingcartridge 211 may provide a seal between theinternal flange 207 a and the exterior surface of thecentral mandrel 202. Additionally, a sealing means, such as an O-ring or sealingcartridge 213 may provide a seal between the side of theflange 224 and the exterior of thecentral mandrel 202. A plurality of radial passages, forinstance passages central mandrel 202 which provides fluid communication between thecentral passage 203 and thepressure chamber 222. Thus, the pressure of thepressure chamber 222 remains approximately the same as the pressure within thecentral passage 203. When the pressure of thecentral passage 203 is large enough to overcome the biasing of the springs 208 an and 208 b, thepressure chamber 222 expands by driving the upper flange 207 away from theexternal flange 224. Thus, the upper flange 207 acts like a piston pushing the retainingsleeve 206 in an upperwardly direction with respect to thecentral mandrel 202. - When the retaining sleeve moves up, the steel balls 218 a-218 d are forced up into thinner regions of the retaining chambers 216 a-216 d. A portion of the steels balls 218 a-218 d, therefore, projects radially through the circular openings 214 a-214 d. As the steel balls 218 a-218 d project through the circular openings 214 a-214 d, they engage the interior surface of the
casing 110. The balls 218 a-218 d grip the interior surface in proportion to the pressure applied to thecentral passage 203. The balls may create small concave indents that imparts a benign compressive stress into thecasing 110. - A
lower end 204 b of thecentral mandrel 202 may be adapted to threadably couple to other components or tools, such as thecasing lock 130 or thetension actuator 134. In the illustrative embodiment, the lower end 204 is coupled to thetension actuator 134. - In several exemplary embodiments, the
tension actuator 134 may be any device capable of pulling theexpansion cone 140 into thecasing 110 in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. - In the illustrative embodiment, the
actuator 134 comprisesactuator barrel 250 having atop end 252 adapted to threadably couple to thelower end 204 b of thegripping device 132. Theactuator barrel 250 defines alongitudinal passage 250 a having an internalannular flange 250 b at the lower end of thelongitudinal passage 250. The lower end of theactuator barrel 250 couples to aconnector barrel 254. Theconnector barrel 254 defines alongitudinal passage 254 a having an internalannular flange 254 b at the lower end of thelongitudinal passage 254 a. The lower end of theconnector barrel 254 couples to aconnector barrel 256. Theconnector barrel 256 defines alongitudinal passage 256 a having an internalannular flange 256 b at the lower end of thelongitudinal passage 256 a. - A
piston tube 260 runs through thepassages actuator barrel 250 and the connector barrels 254 and 256, respectively. Thepiston tube 260 may define alongitudinal passage 261. An externalannular flange 262 a is defined at the top end of thepiston tube 260. The outside diameter of theannular flange 262 a is slightly smaller than the inside diameter of thelongitudinal passage 250 a such that theannular flange 262 a can slide longitudinally within thelongitudinal passage 250 a. A sealing means, such as a sealingcartridge 264 a creates a seal between theannular flange 262 a and the interior surface of thelongitudinal passage 250. Similarly a sealing means, such as a sealingcartridge 266 a creates a seal between the exterior surface of thepiston tube 260 and theflange 254 b. Anannular pressure chamber 268 a may be defined between the bottom of the external flange 262 of thepiston tube 260 and the top of theannular flange 250 b.Radial tubes pressure chamber 268 a to thelongitudinal passage 261 of thepiston tube 260. - An external
annular flange 262 b may be defined on the exterior of thepiston tube 260. The outside diameter of theannular flange 262 b is slightly smaller than the inside diameter of thelongitudinal passage 254 a such that theannular flange 262 b can slide longitudinally within thelongitudinal passage 254 a. A sealing means, such as a sealingcartridge 264 b creates a seal between theannular flange 262 b and the interior surface of thelongitudinal passage 254 a. Similarly a sealing means, such as a sealingcartridge 266 b creates a seal between the exterior surface of thepiston tube 260 and theflange 254 b. Anannular pressure chamber 268 b may be defined between the bottom of theexternal flange 262 b of thepiston tube 260 and the top of theannular flange 254 b.Radial tubes pressure chamber 268 b to thelongitudinal passage 261 of thepiston tube 260. - Similarly, an external
annular flange 262 c may be defined on the exterior of thepiston tube 260. The outside diameter of theannular flange 262 c is slightly smaller than the inside diameter of thelongitudinal passage 256 a such that theannular flange 262 c can slide longitudinally within thelongitudinal passage 256 a. Optionally, a sealing means, such as a sealingcartridge 264 c creates a seal between theannular flange 262 c and the interior surface of thelongitudinal passage 256 a. Similarly a sealing means, such as a sealingcartridge 266 c creates a seal between the exterior surface of thepiston tube 260 and theflange 256 b. Anannular pressure chamber 268 c may be defined between the bottom of theexternal flange 262 c of thepiston tube 260 and the top of theannular flange 256 b.Radial tubes pressure chamber 268 b to thelongitudinal passage 261 of thepiston tube 260. - A
lower end 272 of the piston tube may be adapted to be coupled to another component, such as thecasing lock 130. Optionally, thecasing lock 130 may be positioned above theactuator 130. In several exemplary embodiments, thecasing lock 134 may be any device capable of coupling the apparatus to the casing while the apparatus is being positioned within the wellbore in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. -
FIG. 2 d illustrates an alternative embodiment where a sealing means 136, such as a packer cup assembly may provide a way to create a pressurized zone within thecasing 110. In several exemplary embodiments, the sealing means 136 may be any device capable of sealing between differential zones of pressure in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. - For instance, an upper
packer cup assembly 280 may be coupled to amandrel 282 proximate the upper end of themandrel 282. Themandrel 282 may define anlongitudinal passage 283. In an exemplary embodiment, apacker cup 284 may be a Guiberson™ packer cup. Optionally, a spacer sleeve (not shown) may mate with, receives, and may be coupled to themandrel 282 proximate an end of the upperpacker cup assembly 280. A lowerpacker cup assembly 286 may be coupled to themandrel 282. In an exemplary embodiment, alower packer cup 286 is a Guiberson™ packer cup. Optionally, a lower spacer sleeve may be coupled to themandrel 282 to longitudinally position thelower packer assembly 286. - An
expansion cone 140 may be positioned below the sealing means 136. In several exemplary embodiments, theexpansion cone 140 may be any device capable of expanding the casing ortubing member 110 within thewellbore 105 in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. - In an exemplary embodiment, an adjustable expansion cone may be similar to a conventional adjustable expansion mandrel in that may be expanded to a larger outside dimension or collapsed to a smaller outside dimension and includes external surfaces for engaging the
casing 110 to thereby radially expand and plastically deform the tubular member when the adjustable expansion mandrel is expanded to the larger outside dimension. In an alternative embodiment, theexpansion cone 140 may include a rotary adjustable expansion device such as, for example, the commercially available rotary expansion devices of Weatherford International, Inc. In several alternative embodiments, the cross sectional profile of theexpansion cone 140 for radial expansion operations may, for example, be an n-sided shape, where n may vary from 2 to infinity, and the side shapes may include straight line segments, arcuate segments, parabolic segments, and/or hyperbolic segments. In several alternative embodiments, the cross sectional profile of theadjustable expansion cone 140 may, for example, be circular, oval, elliptical, and/or multifaceted. - Alternatively, the
expansion cone 140 may be comprised of a plurality of circumferentially spaced apart upper cone segments interleaved among the cam arms of an upper cam spaced around a mandrel 291 defininglongitudinal passage 293. In an exemplary embodiment, each upper cone segment includes a first outer surface that defines a hinge groove, a plurality of inner surfaces and a plurality of outer surfaces. In an exemplary embodiment, there may be a combination of arcuate and cylindrical segments. The upper cone segments may be pivotally coupled to anupper cone retainer 290. A plurality of circumferentially spaced apart lower cone segments interleaved among the cam arms of a lower cam. In an exemplary embodiment, each lower cone segment includes a first outer surface that defines a hinge groove, a plurality of inner surfaces and a plurality of outer surfaces. In an exemplary embodiment, there may be a combination of arcuate and cylindrical segments. The lower cone segments may be pivotally coupled to alower cone retainer 292. Shear pins or another retaining mechanism longitudinally position thelower retainer 292 relative to theupper retainer 290 such that they remain positioned apart during the positioning of the apparatus within the well. In one embodiment, when the apparatus reaches the bottom of the well, the impact shears the shear pins and drives the lower cone retainer toward the upper cone retainer, causing the cone segments to pivot outward in a lateral direction. As the cone segments pivot outward, the diameter of theexpansion cone 140 increases. A locking mechanism then locks the cone segments together in an expanded configuration. - The
lower cone retainer 292 receives and may be threadably coupled to an end of arelease housing 300 that defines alongitudinal passage 302. Alower end 304 of therelease housing 300 defines aexternal flange 305 adapted to mate into asleeve 306 in theanchoring device 148. In some exemplary embodiments, atubular cementing probe 308 may be slidingly disposed within thelongitudinal passage 302. The cementingprobe 308 may be a tubular shaped member which defines alongitudinal passage 310. A top end of thecementing probe 308 has an annular exterior flange orrim 312, the diameter of which is slightly smaller than the interior diameter of thelongitudinal passage 302. During operation, an interiorannular seat 314 defined within therelease housing 300 keeps theflange 312 of cementing probe within thelongitudinal passage 302. A lower end of the concrete probe narrows to form aneck 316 which, as will be explained below, is adapted to mate with a collet of theanchoring device 148. During positioning of the apparatus, a probe shear pin 318 longitudinally retains the sliding sleeve within thelongitudinal passage 302. Once thecement probe 308 has been extended during operation, however, aprobe locking ring 320 may maintain the probe in an extended configuration. - In the illustrative embodiment, the
anchoring device 148 may be a anexpandable float shoe 340. In some exemplary embodiments, thefloat shoe 340 may be made out of aluminum or another expandable material which may be relative easy to drill out. The top end of the float shoe defines atubular sleeve 342 defining anannual passage 344. Thetubular sleeve 342 is adapted to mate within therelease housing 300. A slidingsleeve valve 346 is slidingly disposed within thelongitudinal passage 344. - The sliding
sleeve valve 346 is generally tubular in shape defining anlongitudinal passage 348. At a top end of the slidingsleeve valve 346, there is an outwardly protruding flange orrim 350 which circumferentially extends around the top end of slidingsleeve valve 346. Below therim 350, there is a flexible or top section defining acollet 346 a. Below thecollet 346 a, there is alower section 346 b of the slidingsleeve valve 346. The wall thickness of thecollet 346 a is narrow relative to thelower section 346 b. There are also a predetermined number of longitudinal slots (not shown) extending from the top of therim 350 through thecollet 346 a. Preferably these longitudinal slots are equally spaced around the periphery of thecollet 346 a. The combination of the longitudinal slots and the narrowed wall thickness of thecollet 346 a allow the diameter of therim 350 to decrease when therim 350 is not radially supported by a supporting mechanism. Thus, therim 350 can be considered “flexible” in that it can contract from a first radial position of a particular diameter to a second radial position of a lesser diameter. In the running configuration illustrated inFIG. 2 f, therim 350 is positioned in aninterior recess 352 defined in thesleeve 342. Theneck 316 of thecementing probe 308 radially supportsrim 350, preventing therim 350 from slipping out of therecess 352 and thus longitudinally maintains the slidingsleeve valve 346 within thesleeve 342. Aside port 354 may be defined within the side wall of thelower section 346 b. - In several exemplary embodiments, there is a
annular seat 355 positioned within thelongitudinal passage 344 of thefloat shoe 340. Theannular seat 355 is adapted to sealingly couple to a plug. The plug may be any conventional plug, such as drill pipe dart or phenolic ball that would provide a hydraulic seal upon reaching theannular seat 355. Thesleeve 342 of thefloat shoe 340 increases in diameter to accommodate abypass passage 356. Thebypass passage 356 defines a passage that connects the portion of thelongitudinal passage 344 above theseat 356 to a portion of thelongitudinal passage 344 below theseat 356, thereby creating a “bypass” around theseat 356. In the running position illustrated inFIGS. 2 a-2 e, an entrance port 356 a of thebypass passage 356 is blocked by the slidingsleeve valve 346. - Positioned below the
annular seat 355 is a one-way valve 358. In several exemplary embodiments, the oneway valve 358 may be a float valve assembly which allows for a fluid to flow in a downward direction, but prevents fluid to flow in an upward direction. The one-way valve 358 opens into anlongitudinal passage 360. A sleeve, such as adog locking sleeve 362 may be slidingly disposed within thelongitudinal passage 360. Ashear pin 364 maintains the relative position of the dog locking sleeve relative to thefloat shoe 340 such that alower end 368 of the dog locking sleeve is disposed below thefloat shoe 340. At the top end of thedog locking sleeve 362, there is anexternal flange 366 adapted such that an upward movement by theexternal flange 366 “expands” or pushes out a plurality ofdogs 370 through a plurality ofradial side openings 372 defined in thefloat shoe 340. In several alternative embodiments, thedogs 370 orexpansion mechanism 150 within thefloat shoe 340 may be replaced by a shoulder on the float shoe for engaging the end of the radially expanded tubular member. - In an exemplary embodiment, during operation of the
apparatus 200, as illustrated inFIGS. 2 a-2 e, the apparatus may be initially positioned in thewellbore 100, partially within thecasing 110, with theexpansion cone 140, the cementingprobe 144, and thefloat shoe 340 positioned outside the casing. In this manner, fluidic materials within the interior of theapparatus 200 may pass through thelongitudinal passages float valve 358, into the annulus between theapparatus 200 and thecasing 110 thereby preventing over pressurization of the annulus. - Referring now to
FIGS. 3 a-3 e, there is illustrated theapparatus 200 positioned at the bottom of thewellbore 100. When theapparatus 200 contacts with the bottom of thewellbore 100, thedog locking sleeve 368 is driven up into thefloat shoe 340, shearing theshear pin 360. The upward movement of the lockingsleeve 368 forces thedogs 370 through theside openings 372, where a locking mechanism prevents their retraction. - In an alternative embodiment of the expansion cone, the force of impact with the bottom of the well shears the retaining mechanism, forcing the lower
expansion cone retainer 292 towards the upperexpansion cone retainer 290. The interleaved cone segments pivot outward in a lateral direction on top of one another. As the cone segments pivot outward, the diameter of theexpansion cone 140 increases. A locking mechanism then locks the upper cone segments in place. Thus, the expansion cone may expand to a diameter that is greater than the interior diameter of thecasing 110. - Referring now to
FIGS. 4 a-4 f, there is illustrated theapparatus 200 when a plug, such as aball 374 is then injected into the apparatus with the fluidic material through thepassages annular seat 355 in thefloat shoe 340. As a result of the positioning of theball 374 in thepassage 344 of thefloat shoe 340, thepassage 344 of the float shoe is thereby closed. - The fluidic material is then injected into the apparatus thereby increasing the operating pressure within the
passages apparatus 200 causes the fluidic material to pass through theradial passages annular pressure chamber 222 of thegripping device 132. When the pressure of thecentral passage 203 is large enough to overcome the biasing of thesprings pressure chamber 222 expands by driving the upper flange 207 away from theexternal flange 224. Thus, theupper flange 207 a acts like a piston pushing the retainingsleeve 206 in an upperwardly direction with respect to thecentral mandrel 202. When the retaining sleeve moves up, the steel balls 218 a-218 d are forced up into thinner regions of the retaining chambers 216 a-216 d. A portion of the steels balls 218 a-218 d, therefore, projects radially through the circular openings 214 a-214 d. As the steel balls 218 a-218 d project through the circular openings 214 a-214 d, they engage the interior surface of thecasing 110. - The fluidic material is then injected into the apparatus thereby increasing the operating pressure within the
passages apparatus 200 also causes the fluidic material to pass through theradial tubes 270 a through 270 f, of thepiston tube 260 into anannular pressure chambers - The pressurization of the annular pressure chambers, 268 a, 268 b, and 268 c then cause the
piston flanges casing 100. As a result, the upperpacker cup assembly 280, the lowerpacker cup assembly 286,expansion cone 140, therelease housing 300, the cementingprobe 308, and thefloat shoe 340 are displaced upwardly relative to thecasing 110. - The continued injection of the fluidic material into the
apparatus 200 continues to pressurize annular pressure chambers, 268 a, 268 b, and 268 c. The further upward displacement of thepiston flanges expansion cone 140 upwardly relative to thecasing 110. As a result, theexpansion cone 140 radially expands and plastically deforms a portion of thecasing 110. - Referring to
FIGS. 5 a-5 f, during the continued injection of the fluidic material, theexpansion cone 140 will continue to be displaced upwardly relative to thecasing 110 thereby continuing to radially expand and plastically deform the casing until the lockingdogs 370 a-370 b engage the lower end of thecasing 110. The continued upward movement of theexpansion cone 140,cement probe 308, and releasehousing 300 causes therelease housing 300 to move longitudinally upward—out of thesleeve 306 of thefloat shoe 340. Theexternal flange 305 of therelease housing 300 causes thesleeve 306 to radially expand against thecasing 110. In some embodiments, this radial expansion of thesleeve 306 also causes an expansion and plastic deformation of a portion of thecasing 110 which may also hydraulically seal thesleeve 306 to thecasing 110. Optionally, a elastomeric sealing material may be applied to the exterior of thesleeve 306 to create a seal between thesleeve 306 and thecasing 110. - Referring to
FIGS. 6 a to 6 e, The continued upward movement of theexpansion cone 140,cement probe 308, and releasehousing 300 causes the probe shear pin 318 to shear. The force on thecement probe 308 pulls the probe downward until theexternal flange 312 impacts theseat 314 defined with thepassage 302 preventing further movement of the cement probe. Aprobe lock ring 313 disposed on the exterior surface of the concrete probe contacts a downward facingseat 315, thereby “locking” the concrete probe in place. The continued upward movement of thecement probe 308 causes thecement probe 308 to separate from thefloat shoe 340. At the top of the stroke of thetension actuator 134, thecasing lock 130 may be released. After separation, theapparatus 200 is free to continue to advance up causing thecasing 110 to expand as necessary. Because there is an hydraulic seal between thesleeve 306 and thecasing 110, the region between thefloat shoe 340 and thepacker cup assemblies expansion cone 140 upwardly, thereby causing a continued radial expansion and plastic deformation of theexpandable casing 110. In this manner, the fluid pressure below thepacker cup assemblies expansion cone 140 upwardly through theexpandable casing 110. Thus, the use of thetension actuator 134 to pull the expansion cone upwards is no longer necessary. - At some point (e.g., at the top of the liner), it may become desirable to stop expanding and to inject a hardenable fluidic sealing material such as, for example, cement into the well annulus. Referring to
FIGS. 7 a to 7 f, to begin the cementing operation, theapparatus 200 may be lowered into thewellbore 100 until theneck 316 of thecementing probe 308 impacts thecollet 346 a forcing therim 350 of the collet from therecess 352, which allows the slidingsleeve valve 346 to move downward until the sliding sleeve valve impacts an upward facingseat 345 in thepassage 344. In this position, thesideport 354 is aligned with the opening of thebypass flowpath 356 to permit fluidic materials to bypass around the ball in thepassage 344. As a result, thebypass flow path 356 allows for cement or other fluidic materials to flow around the ball. - Thus, the cement may flow through the through the
bypass flow path 356, and out through the one-way valve 358 into the annulus between the radially expanded tubular member and the wellbore. After the cement has been injected into the annulus, the one way valve may prevent the cement from flowing backwards into theflowpath 356. - After completing the injection of the cement into the annulus, the drilling pipe may then pulled upwardly out of the wellbore. The radial expansion and plastic deformation of the expandable tubular member may then be continued by the resumed injection of fluidic material into the apparatus. After the cement has cured, the
float shoe 340 may be drilled out and another expandable tubular member may then be radially expanded and plastically deformed within the wellbore with the upper end of the other tubular member overlapping with the lower end of the earlier expanded tubular member. In this manner, a mono diameter wellbore casing may be formed that includes a plurality of radially expanded tubular members. - In several alternative embodiments, a packer may be used instead of the
float shoe 340 to couple the end of the casing to the apparatus. Referring toFIGS. 8 a to 8 e, an alternative embodiment, anapparatus 500 for forming a monodiameter wellbore casing 502 provides a one step monobore wellbore casing radial expansion system. The one step monobore system can also be used as a cased or open hole radial expansion system, or an open hole cladding system where an expandable casing is clad against a formation in open hole. - In an exemplary embodiment, the
apparatus 500 includes anexpansion assembly 504 and apacker 506. Theexpansion assembly 504 includes, among other things, asafety sub 508, a gripping device 510, acasing lock device 512, a force multiplier ortension actuator 514, an expansion cone 516, a packer setting sleeve 518, aninternal sleeve 520 and a stinger 522. - In an exemplary embodiment, the
safety sub 508 allows a quick connection and disconnection of the drill string to and from the expansion system. - In several exemplary embodiments, the gripping device 510 may be any device capable of engaging the inside surface of the tubular member or casing 502 in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. In the embodiment as illustrated in
FIGS. 8 a-8 f, the gripping device 510 comprises hydraulic slips 510 a-510 c are isolated from internal pressure by arupture disc 524. In an exemplary embodiment, apacker cup 526 acts as a check valve to allow external pressure to equalize behind the hydraulic slips 510 a-510 c when in a running configuration, but holds internal pressure when the rupture disc is ruptured. In an exemplary embodiment, the hydraulic slips 510 a-510 c are actuated by rupturing therupture disc 524 with internal pressure. In an exemplary embodiment, the internal pressure then acts on the hydraulic slips 510 a-510 c, moving them out against the internal diameter of theexpandable casing 502. The hydraulic slips 510 a-510 c thereby provide an anchor for the tension actuator to pull theexpansion cone 504 against and expand the expandable casing. When the internal pressure is released, the hydraulic slips 510 a-510 c retract away from the internal diameter of theexpandable casing 502. - In an exemplary embodiment, a
casing lock 512 holds the weight of the expandable casing string as it is run in the well. In several exemplary embodiments, thecasing lock 512 may be any device capable of coupling the apparatus to the casing while the apparatus is being positioned within the wellbore in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. - In the illustrative embodiment,
casing lock dogs 530 fit in upsets formed in the internal diameter of the expandable casing and are held in place with a retainingsleeve 532. When the retainingsleeve 532 is shifted by thetension actuator 514, thedogs 530 retract and theexpansion 504 is released from theexpandable casing 502. - In several exemplary embodiments, the
tension actuator 514 may be any device capable of pulling theexpansion cone 140 into thecasing 110 in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. Thetension actuator 514 may also be similar to thetension actuator 134 described above. - In an exemplary embodiment, the
tension actuator 514 provides several stages of differential area for internal pressure to act upon and thereby provide an upward force to theexpansion cone 504 to thereby expand theexpandable casing 502. Thetension actuator 514 may be used to initially expand theexpandable casing 502 and to pull thepacker 506 into the radially expandedcasing 502. Thetension actuator 514 may be used at any time during radial expansion process when the hydraulic slips 510 a-510 b are actuated to provide additional upward force to the expansion cone. In an exemplary embodiment, thetension actuator 514 may be used to assist in the radial expansion process when the portion of the expandable casing that overlaps with another casing is radially expanded and plastically deformed. - In several exemplary embodiments, the
expansion cone 504 be any device capable of expanding the casing ortubing member 110 within thewellbore 105 in a conventional manner and/or using one or more of the methods and apparatus disclosed in one or more of the following: (1) PCT application no. serial no. PCT/US02/36267, attorney docket no. 25791.88, filed on Nov. 12, 2002, (2) U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (3) U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, and (4) U.S. provisional patent application Ser. No. 60/339,013, attorney number attorney docket no. 25791.88, filed on Nov. 12, 2001, the disclosures of which are incorporated herein by reference. Thus, the expansion cone 516 may be an adjustable expandable expansion cone, or it may be expandable or non-expandable for use in cased or open hole expansion systems or open hole clad systems. - In an exemplary embodiment, an internal sleeve 534
blocks ports 536 which lead from the internal passage 528 to thepacker setting sleeve 538. In an exemplary embodiment, the internal sleeve 534 may be moved away from theports 536 by thetension actuator 514 at the end of the tension actuator stroke to allow internal pressure to act on thepacker setting sleeve 538 and thereby set thepacker 506 in the expandedcasing 502. Thus, in an exemplary embodiment, thepacker setting sleeve 538 is moved downwardly against thepacker 506 to set the packer by internal pressure. - In an exemplary embodiment, the
packer 506 may be a fas dril packer which is a composite drillable packer that is set in the expanded casing and contains the expansion pressure. The fas dril packer includes an internal pressure balanced slidingsleeve valve 540 which is used to open andclose fluid ports 542 Thesleeve valve 540 has two external seals which seal against the internal diameter of the fas dril packer and isolate fluid ports in the fas dril packer when the sleeve valve is in the up position. When the sleeve valve is moved downwardly,ports 544 in thesleeve valve 540 align withports 542 in the fas dril packer and allow fluid to be displaced into abypass passage 546 in the fas dril packer. Collets at the top of the sleeve valve fit in an internal groove provided in the internal diameter of the fas dril packer when the sleeve valve is in the up position and allow the end of the stinger to pass and shoulder against the sleeve valve. When astinger 548 pushes thesleeve valve 540 downwardly to open theports 542, the collets are pulled out of the groove and retract inward into an external undercut on the bottom of thestinger 548. - When the
stinger 548 is moved up to close theports 542, a lower shoulder on the external undercut contacts the inward retracted collets and pulls the slidingsleeve valve 540 upwardly until the collets expand out into the internal groove. Thesleeve valve 540 is operated with astinger 548 attached to theexpansion assembly 504. Below thesleeve valve 540 are twoball seats rupture disc 552 in between. Thebypass passage 546 connects theports 542 covered by the sleeve valve, therupture disc ports 554, andports 556 positioned below the bottom ball seat. - A
check valve 558 may be disposed at the bottom of the fas dril packer. Other types of commercially available drillable packers may also be used, such as, for example, the EZ Drill. Additionally, for open and cased hole cladding systems where cement is not going to be used, retrievable packers can be used and retrieved after expansion instead of drilled. - In an exemplary embodiment, the
stinger 548 may be attached to theexpansion assembly 504 and includes anexternal seal 560 which seals against the inside diameter of the fas dril packer. At the bottom end of the stinger is an external undercut which is used to close the sliding sleeve valve. - Turning now to
FIGS. 9 a-9 e, which illustrates some aspects of the operation of theapparatus 500. InFIG. 9 a, theexpansion assembly 504 is run through thecasing 502 until thepacker 506 is in open hole beyond the casing. - A first plug, which may be a ball or a dart, may be dropped to the
plug seat 550 a in the packer central passage 528. Continued pumping of fluids causes the internal pressure to be increased. As described above with reference toFIGS. 1 a to 7 f, the pressure actuates thetension actuator 514 which pulls the expansion cone 516 up against the bottom of the casing 510. - The expansion cone 516 expands in size and then expands the
expandable casing 502, pulling thepacker 506 upwardly along with it. Near the end of the tension actuator stroke, thepacker 506 is positioned in the expanded casing and the lower end of the tension actuator shoulders against theinternal sleeve 520, shifting it downward. As a result, theports 536 open allowing fluidic communication from the central passage 528 to thepacker setting sleeve 538. The internal pressure then causes the settingsleeve 538 to down, which pushes against and sets thepacker 506. - The tension actuator 514 then pulls against a connecting mechanism, such as a plurality of shear pins, connecting the
packer 506 to theexpansion assembly 504 until they shear. - At the end of the tension actuator stroke, an
upper end 562 of thetension actuator 514 shoulders against thedog retaining sleeve 532 and moves it upward, releasing thedogs 530 and unlocking theexpansion assembly 504 from thecasing 502. - Continued injection of the fluidic material into the
apparatus 500 causes an increase in the internal pressure in the central passage 528. The increase pressure ruptures therupture disc 554, which allows the fluid to flow into thebypass passage 546. Thecasing 502 can now be run to the bottom of the well. - Once the casing has reached the bottom of the well, a second plug may be dropped. The second plug sized to sealingly fit the
second plug seat 550 b. The second plug stops circulation through thebypass passage 546. Continued injection of fluid increases the internal pressure in the central passage 528 so that the casing expansion can be partially or completely continued, or the expansion assembly can be set down to open the sliding sleeve valve to circulate mud or displace cement. Picking back up on theexpansion assembly 504 will close the sliding sleeve valve. At any point during expansion, theexpansion assembly 504 can be set down on thepacker 506 to open the slidingsleeve valve 540 to continue circulation. - Once the
expansion assembly 504 reaches an overlap section of theexpandable casing 502, the expansion pressure increases until theupper rupture disc 524 ruptures. The hydraulic slips 510 a-510 c then move out against the internal diameter of theexpandable casing 502, providing an anchor for the tension actuator to pull the expansion cone against. When thetension actuator 514 reaches the end of its stroke, the internal pressure is released, the hydraulic slips 510 a-510 c retract, and thetension actuator 514 is extended for another stroke. In an exemplary embodiment, the hydraulic slips 510 a-510 c may be designed to not only contact the unexpanded casing, but will also extend out far enough the contact the previously expanded casing string at the final expansion stroke. - After the
expansion assembly 504 is pulled out of the well, thepacker 506 may be drilled out and another section of hole may be drilled. An identical expansion system is then run and expanded to the same ID as the previous string. - It is understood that variations may be made in the foregoing without departing from the scope of the invention. For example, the teachings of the present illustrative embodiments may be used to provide a wellbore casing, a pipeline, or a structural support. Furthermore, the elements and teachings of the various illustrative embodiments may be combined in whole or in part in some or all of the illustrative embodiments.
- It is understood that variations may be made in the foregoing without departing from the scope of the invention. For example, the teachings of the present illustrative embodiments may be used to provide a wellbore casing, a pipeline, or a structural support. Furthermore, the elements and teachings of the various illustrative embodiments may be combined in whole or in part in some or all of the illustrative embodiments.
- Although illustrative embodiments of the invention have been shown and described, a wide range of modification, changes and substitution is contemplated in the foregoing disclosure. In some instances, some features of the present invention may be employed without a corresponding use of the other features. Accordingly, it is appropriate that the appended claims be construed broadly and in a manner consistent with the scope of the invention.
Claims (60)
1. An apparatus for radially expanding and plastically deforming an expandable tubular member, comprising:
an anchoring mechanism adapted to mate with an end of the expandable tubular member;
a tubular support member releasably coupled to the anchoring mechanism,
an adjustable expansion mandrel coupled to the tubular support member adapted to be controllably expanded to a larger outside dimension for radial expansion of the expandable tubular member or collapsed to a smaller outside dimension;
an actuator coupled to the tubular support member and the adjustable expansion mandrel adapted to controllably longitudinally displace the adjustable expansion mandrel relative to the tubular support member and the expandable tubular member; and
a gripping device coupled to the tubular support member adapted to controllably engage the expandable tubular member.
2. The apparatus of claim 1 further comprising a locking device coupled to the actuator adapted to controllably engage the expandable tubular member.
3. The apparatus of claim 1 further comprising a sealing device for sealingly engaging the expandable tubular member adapted to define an annular pressure chamber above the adjustable expansion mandrel during radial expansion of the expandable tubular member.
4. The apparatus of claim 1 wherein the gripping device comprises:
a tubular mandrel having a plurality of tapered grooves defined on an exterior surface of the tubular mandrel,
a retaining sleeve coupled to the tubular mandrel and adapted to slidingly move longitudinally with respect to the tubular mandrel, the retaining sleeve having a plurality of openings,
a plurality of gripping elements positioned within the tapered grooves, wherein when the retaining sleeve is in a first longitudinal configuration, portions of the gripping elements protrude through the plurality of openings, and when the retaining sleeve is in a second longitudinal configuration, portions of the gripping elements do not protrude through plurality of tapered openings.
5. The apparatus of claim 1 wherein the anchoring device is a float shoe, comprising:
an expandable sleeve adapted to mate with the tubular member, wherein the tubular member is adapted to controllably expand the expandable sleeve to a larger outside dimension for radial expansion of the expandable sleeve to the expandable tubular member.
6. The apparatus of claim 5 wherein the anchoring device comprises:
a first passage,
a second passage,
a seat within the first passage adapted to receive a plug,
a sliding valve disposed within the first passage, adapted to direct flow from the first passage to the second passage, and
a one-way valve coupled to the first and second passages.
7. The apparatus of claim 1 wherein the anchoring mechanism is a packer.
8. The apparatus of claim 7 wherein the packer is hydraulically actuated.
9. The apparatus of claim 7 wherein the packer comprises:
a first passage,
a second passage,
a first seat within the first passage adapted to receive a plug, and
a sliding valve disposed within the first passage, adapted to direct flow from the first passage to the second passage.
10. A method for radially expanding and plastically deforming an expandable tubular member within a borehole, comprising:
positioning an adjustable expansion mandrel, an anchoring device, and a coupling mechanism below the expandable tubular member such that the anchoring device contacts a bottom of the borehole,
increasing the outside dimension of the adjustable expansion mandrel; and
displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member,
displacing the anchoring device upwardly relative to the expandable tubular member such that the anchoring device contacts the bottom of the expandable tubular member,
coupling the anchoring device to the bottom of the casing,
uncoupling the expansion mandrel from the anchoring device, and
displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member.
11. The method of claim 10 , further comprising:
lowering the adjustable expansion mandrel to couple the expansion mandrel to the anchoring device, and
cementing the borehole, wherein the cementing flows through a flow path located in the anchoring device.
12. The method of claim 10 further comprising expanding an expansion device coupled to the anchoring device such that the anchoring device couples to the casing.
13. An apparatus for radially expanding and plastically deforming an expandable tubular member, comprising:
an anchoring mechanism adapted to mate with an end of the expandable tubular member;
a tubular support member releasably coupled to the anchoring mechanism,
an adjustable expansion device coupled to the tubular support member adapted to be controllably expanded to a larger outside dimension for radial expansion of the expandable tubular member or collapsed to a smaller outside dimension;
an actuator coupled to the tubular support member and the adjustable expansion device adapted to controllably longitudinally displace the adjustable expansion device relative to the tubular support member and the expandable tubular member; and
a gripping device coupled to the tubular support member adapted to controllably engage the expandable tubular member.
14. The apparatus of claim 13 further comprising a locking device coupled to the actuator adapted to controllably engage the expandable tubular member.
15. The apparatus of claim 13 further comprising a sealing device for sealingly engaging the expandable tubular member adapted to define an annular pressure chamber above the adjustable expansion device during radial expansion of the expandable tubular member.
16. The apparatus of claim 13 wherein the gripping device comprises:
a tubular member having a plurality of tapered grooves defined on an exterior surface of the tubular member,
a retaining sleeve coupled to the tubular member and adapted to slidingly move longitudinally with respect to the tubular member, the retaining sleeve having a plurality of openings,
a plurality of gripping elements positioned within the tapered grooves, wherein when the retaining sleeve is in a first longitudinal configuration, portions of the gripping elements protrude through the plurality of openings, and when the retaining sleeve is in a second longitudinal configuration, portions of the gripping elements do not protrude through plurality of tapered openings.
17. The apparatus of claim 13 wherein the anchoring device is a float shoe, comprising:
an expandable sleeve adapted to mate with the tubular member, wherein the tubular member is adapted to controllably expand the expandable sleeve to a larger outside dimension for radial expansion of the expandable sleeve to the expandable tubular member.
18. The apparatus of claim 17 wherein the anchoring device comprises:
a first passage,
a second passage,
a seat within the first passage adapted to receive a plug,
a sliding valve disposed within the first passage, adapted to direct flow from the first passage to the second passage, and
a one-way valve coupled to the first and second passages.
19. The apparatus of claim 13 wherein the anchoring mechanism is a packer.
20. The apparatus of claim 19 wherein the packer is hydraulically actuated.
21. The apparatus of claim 19 wherein the packer comprises:
a first passage,
a second passage,
a first seat within the first passage adapted to receive a plug, and
a sliding valve disposed within the first passage, adapted to direct flow from the first passage to the second passage.
22. A method for radially expanding and plastically deforming an expandable tubular member within a borehole, comprising:
positioning an adjustable expansion device, an anchoring device, and a coupling mechanism below the expandable tubular member such that the anchoring device contacts a bottom of the borehole,
increasing the outside dimension of the adjustable expansion device; and
displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member,
displacing the anchoring device upwardly relative to the expandable tubular member such that the anchoring device contacts the bottom of the expandable tubular member,
coupling the anchoring device to the bottom of the casing,
uncoupling the adjustable expansion device from the anchoring device, and
displacing the adjustable expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member.
23. The method of claim 22 , further comprising:
lowering the adjustable expansion device to couple the expansion device to the anchoring device, and
cementing the borehole, wherein the cementing flows through a flow path located in the anchoring device.
24. The method of claim 22 further comprising expanding an expansion device coupled to the anchoring device such that the anchoring device couples to the casing.
25. An apparatus for radially expanding and plastically deforming an expandable tubular member, comprising:
an anchoring mechanism adapted to mate with an end of the expandable tubular member;
a tubular support member releasably coupled to the anchoring mechanism,
an expansion device coupled to the tubular support member adapted to be controllably expanded to a larger outside dimension for radial expansion of the expandable tubular member or collapsed to a smaller outside dimension;
an actuator coupled to the tubular support member and the adjustable expansion device adapted to controllably longitudinally displace the adjustable expansion device relative to the tubular support member and the expandable tubular member; and
a gripping device coupled to the tubular support member adapted to controllably engage the expandable tubular member.
26. The apparatus of claim 25 further comprising a locking device coupled to the actuator adapted to controllably engage the expandable tubular member.
27. The apparatus of claim 25 further comprising a sealing device for sealingly engaging the expandable tubular member adapted to define an annular pressure chamber proximate the expansion device during radial expansion of the expandable tubular member.
28. The apparatus of claim 25 wherein the gripping device comprises:
a tubular member having a plurality of tapered grooves defined on an exterior surface of the tubular member,
a retaining sleeve coupled to the tubular member and adapted to slidingly move longitudinally with respect to the tubular member, the retaining sleeve having a plurality of openings,
a plurality of gripping elements positioned within the tapered grooves, wherein when the retaining sleeve is in a first longitudinal configuration, portions of the gripping elements protrude through the plurality of openings, and when the retaining sleeve is in a second longitudinal configuration, portions of the gripping elements do not protrude through plurality of tapered openings.
29. The apparatus of claim 25 wherein the anchoring device is a float shoe, comprising:
an expandable sleeve adapted to mate with the tubular member, wherein the tubular member is adapted to controllably expand the expandable sleeve to a larger outside dimension for radial expansion of the expandable sleeve to the expandable tubular member.
30. The apparatus of claim 29 wherein the anchoring device comprises:
a first passage,
a second passage,
a seat within the first passage adapted to receive a plug,
a sliding valve disposed within the first passage, adapted to direct flow from the first passage to the second passage, and
a one-way valve coupled to the first and second passages.
31. The apparatus of claim 25 wherein the anchoring mechanism is a packer.
32. The apparatus of claim 31 wherein the packer is hydraulically actuated.
33. The apparatus of claim 31 wherein the packer comprises:
a first passage,
a second passage,
a first seat within the first passage adapted to receive a plug, and
a sliding valve disposed within the first passage, adapted to direct flow from the first passage to the second passage.
34. A method for radially expanding and plastically deforming an expandable tubular member within a borehole, comprising:
positioning an expansion device, an anchoring device, and a coupling mechanism below the expandable tubular member;
displacing the expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member,
displacing the anchoring device upwardly relative to the expandable tubular member,
coupling the anchoring device to the bottom of the casing,
uncoupling the expansion device from the anchoring device, and
displacing the expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member.
35. The method of claim 34 , further comprising:
lowering the expansion device to couple the expansion device to the anchoring device, and
cementing the borehole, wherein the cementing flows through a flow path defined in the anchoring device.
36. The method of claim 34 further comprising expanding an expansion device coupled to the anchoring device such that the anchoring device couples to the casing.
37. A gripping device for gripping a wellbore casing, comprising:
a tubular member having a plurality of tapered grooves defined on an exterior surface of the tubular member,
a retaining sleeve coupled to the tubular member and adapted to slidingly move longitudinally with respect to the tubular member, the retaining sleeve having a plurality of openings,
a plurality of gripping elements positioned within the tapered grooves, wherein when the retaining sleeve is in a first longitudinal configuration, portions of the gripping elements protrude through the plurality of openings, and when the retaining sleeve is in a second longitudinal configuration, portions of the gripping elements do not protrude through plurality of tapered openings.
38. An anchoring device for anchoring the position of a wellbore casing, comprising:
an expandable sleeve adapted to mate with the wellbore casing.
39. An anchoring device for anchoring the position of a wellbore casing, comprising:
a housing,
a first passage defined within the housing,
a second passage defined within the housing,
a seat within the first passage adapted to receive a plug,
a sliding valve disposed within the first passage, adapted to direct flow from the first passage to the second passage, and
a one-way valve coupled to the first and second passages.
40. A system for radially expanding and plastically deforming an expandable tubular member within a borehole, comprising:
means for positioning an adjustable expansion mandrel, an anchoring device, and a coupling mechanism below the expandable tubular member such that the anchoring device contacts a bottom of the borehole,
means for increasing the outside dimension of the adjustable expansion mandrel;
means for displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member,
means for displacing the anchoring device upwardly relative to the expandable tubular member such that the anchoring device contacts the bottom of the expandable tubular member,
means for coupling the anchoring device to the bottom of the casing,
means for uncoupling the expansion mandrel from the anchoring device, and
means for displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member.
41. The system of claim 40 , further comprising:
means for lowering the adjustable expansion mandrel to couple the expansion mandrel to the anchoring device, and
means for cementing the borehole, wherein the cementing flows through a flow path located in the anchoring device.
42. The system of claim 40 further comprising means for expanding an expansion device coupled to the anchoring device such that the anchoring device couples to the casing.
43. A method for radially expanding and plastically deforming an expandable tubular member within a borehole, comprising:
means for positioning an adjustable expansion device, an anchoring device, and a coupling mechanism below the expandable tubular member such that the anchoring device contacts a bottom of the borehole,
means for increasing the outside dimension of the adjustable expansion device;
means for displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member,
means for displacing the anchoring device upwardly relative to the expandable tubular member such that the anchoring device contacts the bottom of the expandable tubular member,
means for coupling the anchoring device to the bottom of the casing,
means for uncoupling the adjustable expansion device from the anchoring device, and
means for displacing the adjustable expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member.
44. The system of claim 43 , further comprising:
means for lowering the adjustable expansion device to couple the expansion device to the anchoring device, and
means for cementing the borehole, wherein the cementing flows through a flow path located in the anchoring device.
45. The system of claim 43 further comprising means for expanding an expansion device coupled to the anchoring device such that the anchoring device couples to the casing.
46. A system for radially expanding and plastically deforming an expandable tubular member within a borehole, comprising:
means for positioning an expansion device, an anchoring device, and a coupling mechanism below the expandable tubular member;
means for displacing the expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member,
means for displacing the anchoring device upwardly relative to the expandable tubular member,
means for coupling the anchoring device to the bottom of the casing,
means for uncoupling the expansion device from the anchoring device, and
means for displacing the expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member.
47. The system of claim 46 , further comprising:
means for lowering the expansion device to couple the expansion device to the anchoring device, and
means for cementing the borehole, wherein the cementing flows through a flow path defined in the anchoring device.
48. The method of claim 46 further comprising means for expanding an expansion device coupled to the anchoring device such that the anchoring device couples to the casing.
49. A method of gripping a wellbore casing, comprising:
gripping the interior surface of the wellbore casing at a plurality of discrete spaced apart locations.
50. A method of anchoring the position of a wellbore casing, comprising:
radially expanding and plastically deforming a sleeve within the wellbore casing into contact with the interior surface of the wellbore casing.
51. A system for gripping a wellbore casing, comprising:
means for gripping the interior surface of the wellbore casing at a plurality of discrete spaced apart locations; and
means for actuating the means for gripping.
52. A system for anchoring the position of a wellbore casing, comprising:
means for radially expanding and plastically deforming a sleeve within the wellbore casing into contact with the interior surface of the wellbore casing; and
means for controlling the means for radially expanding and plastically deforming the sleeve.
53. A method of radially expanding and plastically deforming a tubular member, comprising:
pressurizing an interior portion of the tubular member; and
displacing an expansion device through the pressurized interior portion of the tubular member.
54. The method of claim 53 , wherein pressurizing an interior portion of the tubular member comprises pressurizing an annular interior portion of the tubular member.
55. The method of claim 53 , wherein displacing an expansion device through the pressurized interior portion of the tubular member comprises pulling the expansion device through the pressurized interior portion of the tubular member.
56. The method of claim 53 , wherein pulling the expansion device through the pressurized interior portion of the tubular member comprises using the operating pressure of the pressurized interior portion of the tubular member to pull the expansion device through the pressurized interior portion of the tubular member.
57. A system for radially expanding and plastically deforming a tubular member, comprising:
means for pressurizing an interior portion of the tubular member; and
means for displacing an expansion device through the pressurized interior portion of the tubular member.
58. The system of claim 57 , wherein means for pressurizing an interior portion of the tubular member comprises means for pressurizing an annular interior portion of the tubular member.
59. The system of claim 57 , wherein means for displacing an expansion device through the pressurized interior portion of the tubular member comprises means for pulling the expansion device through the pressurized interior portion of the tubular member.
60. The system of claim 57 , wherein means for pulling the expansion device through the pressurized interior portion of the tubular member comprises means for using the operating pressure of the pressurized interior portion of the tubular member to pull the expansion device through the pressurized interior portion of the tubular member.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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US10/513,614 US20050217866A1 (en) | 2002-05-06 | 2003-05-06 | Mono diameter wellbore casing |
US11/552,703 US7546881B2 (en) | 2001-09-07 | 2006-10-25 | Apparatus for radially expanding and plastically deforming a tubular member |
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US38014702P | 2002-05-06 | 2002-05-06 | |
US10/513,614 US20050217866A1 (en) | 2002-05-06 | 2003-05-06 | Mono diameter wellbore casing |
PCT/US2003/014153 WO2003093623A2 (en) | 2002-05-06 | 2003-05-06 | Mono diameter wellbore casing |
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US10/507,567 Continuation-In-Part US20050103502A1 (en) | 2001-09-07 | 2003-02-19 | Collapsible expansion cone |
PCT/US2003/004837 Continuation-In-Part WO2003078785A2 (en) | 2001-09-07 | 2003-02-19 | Collapsible expansion cone |
PCT/US2003/014153 A-371-Of-International WO2003093623A2 (en) | 2001-09-07 | 2003-05-06 | Mono diameter wellbore casing |
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US10/528,497 Continuation-In-Part US7513313B2 (en) | 2001-09-07 | 2003-09-22 | Bottom plug for forming a mono diameter wellbore casing |
PCT/US2003/029460 Continuation-In-Part WO2004027200A2 (en) | 2001-09-07 | 2003-09-22 | Bottom plug for forming a mono diameter wellbore casing |
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Also Published As
Publication number | Publication date |
---|---|
CA2484966A1 (en) | 2003-11-13 |
WO2003093623B1 (en) | 2004-12-16 |
WO2003093623A3 (en) | 2004-07-08 |
WO2003093623A2 (en) | 2003-11-13 |
AU2003266000A1 (en) | 2003-11-17 |
AU2003266000A8 (en) | 2003-11-17 |
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