US20040055786A1 - Positive displacement apparatus for selectively translating expander tool downhole - Google Patents
Positive displacement apparatus for selectively translating expander tool downhole Download PDFInfo
- Publication number
- US20040055786A1 US20040055786A1 US10/253,114 US25311402A US2004055786A1 US 20040055786 A1 US20040055786 A1 US 20040055786A1 US 25311402 A US25311402 A US 25311402A US 2004055786 A1 US2004055786 A1 US 2004055786A1
- Authority
- US
- United States
- Prior art keywords
- piston
- rotor
- fluid
- rotor piston
- displacement
- 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.)
- Abandoned
Links
Images
Classifications
-
- 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
-
- 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
- E21B4/00—Drives for drilling, used in the borehole
- E21B4/18—Anchoring or feeding in the borehole
-
- 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
Abstract
The present invention provides a positive displacement apparatus for selectively translating a completion tool, such as an expander tool, downhole. The positive displacement apparatus comprises a set of three essentially concentric tubular members. The three tubulars represent (1) an outer sleeve, (2) an inner mandrel, and (3) a middle displacement piston between the sleeve and the mandrel. These three tubular members are nested within the expandable liner or other tubular to be expanded within a wellbore. A fluid transfer chamber is provided below the middle displacement piston. Rotation of the positive displacement apparatus serves to draw fluid into the fluid transfer chamber. This fluid, in turn, is pumped into a fluid transfer channel and forces the displacement piston upward between the outer sleeve and the inner mandrel. The displacement piston then acts against the rotary expander tool. In this manner, the displacement piston translates the rotary expander tool axially within the wellbore.
Description
- 1. Field of the Invention
- The present invention relates to methods for wellbore completion. More particularly, the invention relates to an apparatus for selectively translating a completion tool, such as an expander tool, downhole.
- 2. Description of the Related Art
- Hydrocarbon and other wells are completed by forming a borehole in the earth and then lining the borehole with steel pipe or casing to form a wellbore. After a section of wellbore is formed by drilling, a section of casing is lowered into the wellbore and temporarily hung therein from the surface of the well. Using apparatus known in the art, the casing is cemented into the wellbore by circulating cement into the annular area defined between the outer wall of the casing and the borehole. The combination of cement and casing strengthens the wellbore and facilitates the isolation of certain areas of the formation behind the casing for the production of hydrocarbons.
- It is common to employ more than one string of casing in a wellbore. In this respect, a first string of casing is set in the wellbore when the well is drilled to a first designated depth. The first string of casing is hung from the surface, and then cement is circulated into the annulus behind the casing. The well is then drilled to a second designated depth, and a second string of casing, or liner, is run into the well. The second string is set at a depth such that the upper portion of the second string of casing overlaps the lower portion of the first string of casing. The second liner string is then fixed or “hung” off of the existing casing by the use of slips which utilize slip members and cones to wedgingly fix the new string of liner in the wellbore. The second casing string is then cemented. This process is typically repeated with additional casing strings until the well has been drilled to total depth. In this manner, wells are typically formed with two or more strings of casing of an ever decreasing diameter.
- Apparatus and methods are emerging that permit tubulars to be expanded in situ. The apparatus typically includes expander tools that are run into the wellbore on a working string. The expander tools include a plurality of expansion assemblies that are urged radially outward into contact with a tubular therearound. The expansion assemblies typically comprise a piston disposed within a recess of the expander tool body, and a roller member positioned on or above an external piston surface. In some arrangement's, the expansion assemblies are urged outward from the body of the expander tool by mechanical force. More commonly, the back surface of the expansion assembly is exposed to hydraulic pressure from within the bore of the tool. Fluid pressure is provided either by injecting fluid under pressure into the wellbore from the surface, or by activating a dedicated fluid reservoir associated with the tool.
- As sufficient pressure is generated on the piston surface behind the expansion assemblies, the tubular being acted upon by the expander tool is expanded past its point of elastic deformation. In this manner, the inner and outer diameter of the tubular is increased in the wellbore. By rotating the expander tool in the wellbore and/or moving the expander tool axially in the wellbore with the expansion assemblies actuated, a tubular can be expanded into plastic deformation along a predetermined length in a wellbore.
- Multiple uses for expandable tubulars are being discovered. For example, an intermediate string of casing can be hung off of a string of surface casing by expanding an upper portion of the intermediate string into frictional contact with the lower portion of surface casing therearound. This allows for the hanging of a string of casing without the need for a separate slip assembly as described above. Additional applications for the expansion of downhole tubulars exist, such as the use of an expandable sand screen.
- There are problems associated with the expansion of tubulars. One problem particularly associated with the use of rotary expander tools is the likelihood of obtaining an uneven expansion of a tubular. In this respect, the inner diameter of the tubular that is expanded tends to initially assume the shape of the compliant rollers of the expander tool, including imperfections in the rollers. Moreover, as the working string is rotated from the surface, the expander tool may temporarily stick during expansion of a tubular, then turn quickly, and then stop again. This spring-type action in the working string further creates imperfections in the expansion job.
- Another obstacle to smooth expansion relates to the phenomenon of pipe stretch. Those of ordinary skill in the art will understand that raising a working string a selected distance at the surface does not necessarily translate into the raising of a tool at the lower end of a working string by that same selected distance. The potential for pipe stretch is great during the process of expanding a tubular. Once the expander tool is actuated at a selected depth, an expanded profile is created within the expanded tubular. This profile creates an immediate obstacle to the raising or lowering of the expander tool. Merely raising the working string a few feet from the surface will not, in many instances, result in the raising of the expander tool; rather, it will only result in stretching of the working string. Applying further tensile force in order to unstick the expander tool may cause a sudden recoil, causing the expander tool to move uphole too quickly, leaving gaps in the tubular to be expanded.
- The same problem exists in the context of pipe compression. In this respect, the lowering of the working string from the surface does not typically result in a reciprocal lowering of the expander tool at the bottom of the hole. This problem is exacerbated by pipe drag caused by friction between the drill pipe and the casing. Because of pipe drag, it is not known how much weight is actually reaching the tools down hole. The overall result of these drag problems is that the inner diameter of the expanded tubular may not have a uniform circumference along the desired length.
- There is a need, therefore, for an improved apparatus for expanding a portion of casing or other tubular within a wellbore. Further, there is a need for an apparatus which will aid in the expansion of a tubular downhole and which reduces the potential of pipe-stretch/pipe-compression by the working string. Correspondingly, there is a need for a method for expanding a tubular which avoids the risk of uneven expansion of the tubular caused by pipe-stretch incident to raising the working string. Still further, a need exists for an apparatus which will selectively translate a completion tool such as a rotary expander tool axially downhole without requiring that the working string be raised or lowered.
- There is yet a further need for an apparatus which translates a rotary expander tool by means of a piston selectively driven through positive displacement.
- The present invention provides an apparatus and method for selectively translating a completion tool, such as an expander tool, downhole. According to the present invention, a translation apparatus is introduced into a wellbore. The translation apparatus is lowered downhole on a working string along with an expander tool, and along with a lower string of casing or other tubular to be expanded. The expander tool includes compliant rollers which are expandable radially outward against the inner surface of the tubular upon actuation.
- The translation apparatus of the present invention utilizes positive displacement to translate the expander tool. The positive displacement translation apparatus first defines a set of three essentially concentric tubular members which reside below the expander tool. The three concentric tubulars represent (1) an outer sleeve, (2) an inner mandrel, and (3) a middle displacement piston nested between the sleeve and the mandrel. These three tubular members are disposed within the expandable liner or other tubular to be expanded.
- A fluid transfer chamber is provided below the middle displacement piston. Rotation of the positive displacement apparatus serves to draw fluid into the fluid transfer chamber. This fluid is applied against the base of the displacement piston in order to force the displacement piston upward between the outer sleeve and the inner mandrel. This, in turn, causes the displacement piston to act against the rotary expander tool. In this manner, the displacement piston translates the expander tool incrementally upward within the wellbore.
- In order to fill the fluid transfer chamber with fluid, a positive displacement mechanism is provided. First, a stator member is provided below the middle displacement piston. The stator member has a top face at its top end configured in a wave form. In one aspect, the wave form is sinusoidal. At the same time, a rotor piston is provided below the displacement piston. The rotor piston has a bottom face which rides upon the wave form face of the stator member. Preferably, the bottom face of the rotor piston also has a sinusoidal wave form shape. Rotation of the expander tool and the positive displacement apparatus, including the rotor piston, serves to reciprocate the rotor piston in an up-and-down manner. By this reciprocating motion, fluid is drawn into the fluid transfer chamber and fed against the base of the displacement piston. This, in turn, causes the expander tool to be translated upwardly within the wellbore. In this manner, the expander tool can be raised without raising the working string itself.
- So that the manner in which the above recited features of the present invention are attained and can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to 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 may admit to other equally effective embodiments.
- FIG. 1 is a cross-sectional view of a wellbore having an upper string of casing, and a lower string of casing being lowered into the upper string of casing. In this view, the lower string of casing serves as the expandable tubular. Also depicted in FIG. 1 is a positive displacement apparatus of the present invention for translating an expander tool.
- FIG. 2 is a more detailed view of a scribe as might be placed in the lower string of casing. The scribe serves as a point of structural weakness in the lower string of casing, permitting severance upon expansion of the casing.
- FIG. 3 is an enlarged view of the fluid transfer chamber in an exemplary positive displacement apparatus of the present invention.
- FIG. 4 is a cross-sectional view of a positive displacement apparatus of the present invention, taken across line4-4 of FIG. 1.
- FIG. 5 is a cross-sectional view of the positive displacement apparatus of FIG. 1. In this view, oil is being transferred from the fluid transfer chamber, up the transfer chamber channel, and into the piston feed channel. Visible in this view is the initial translation of the middle displacement piston.
- FIG. 6 presents an exploded view of an expander tool as might be translated by the positive displacement pump/piston apparatus of the present invention.
- FIG. 7 presents a portion of the expander tool of FIG. 5 in cross-section, with the view taken across line7-7 of FIG. 6.
- FIG. 8 depicts the wellbore of FIG. 1. In this view, the expander tool has been actuated so as to begin expanding the lower string of casing. Further, the torque anchor has been actuated so as to stabilize the lower string of casing and to prevent rotational movement during expansion.
- FIG. 9 depicts the wellbore of FIG. 8. In this view, the expander tool remains actuated by hydraulic pressure from the surface. The working string has been rotated so as to begin raising the expander tool within the wellbore. In this respect, rotation of the positive displacement apparatus serves to actuate the piston within the apparatus. This in turn, causes the expander tool to be translated co-axially within the wellbore.
- FIG. 10 depicts the wellbore of FIG. 9. Here, the expander tool has been raised further within the wellbore so as to expand the lower string of casing into the surrounding upper string of casing along a desired length. The portion of the lower string of casing having a scribe has been expanded, causing severance of the lower string of casing.
- FIG. 11 is a sectional view of the wellbore of FIG. 10. In this view, the torque anchor and the expander tool have been de-actuated and the lower collet has been released from the liner. Also, the expansion assembly is being removed from the wellbore. Removal of the expansion assembly brings with it the severed upper portion of the lower casing string.
- FIG. 12 is a sectional view of the wellbore of FIG. 11, with the positive displacement apparatus of the present invention having been removed. In this view, the lower string of casing has been expanded into frictional and sealing engagement with the upper string of casing.
- FIG. 1 presents a cross-sectional view of a
wellbore 100 having an upper string ofcasing 110 and a lower string ofcasing 120. The lower string ofcasing 120, or liner, is being lowered into thewellbore 100 co-axially with the upper string ofcasing 110. The lower string ofcasing 120 is positioned such that an upperexpandable portion 120E of the lower string ofcasing 120 overlaps with alower portion 110L of the upper string ofcasing 110. - In the example of FIG. 1, the lower string of
casing 120 serves as an expandable tubular. The lower string ofcasing 120 will be hung off of the upper string ofcasing 110 by expanding anupper portion 120E of the lower string ofcasing 110 into thelower portion 110L of the upper string ofcasing 110. However, it is understood that the apparatus and method of the present invention may be utilized to expand downhole tubulars other than strings of casing. - A sealing
member 222 is preferably disposed on the outer surface of the lower string ofcasing 120. In one embodiment, the sealingmember 222 defines a matrix formed in grooves (not shown) on the outer surface of the lower string ofcasing 120. However, other configurations are permissible, including one or more simple rings formed circumferentially around the lower string ofcasing 120. In the arrangements of FIG. 1, asingle ring 222 is shown. - The sealing
member 222 is fabricated from a suitable material based upon the service environment that exists within thewellbore 100. Factors to be considered when selecting asuitable sealing member 222 include the chemicals likely to contact the sealing member, the prolonged impact of hydrocarbon contact on the sealing member, the presence and concentration of erosive compounds such as hydrogen sulfide or chlorine, and the pressure and temperature at which the sealing member must operate. In a preferred embodiment, the sealingmember 222 is fabricated from an elastomeric material. However, non-elastomeric materials or polymers may be employed as well, so long as they substantially prevent production fluids from passing upwardly between the outer surface of the lower string of casing 120L and the inner surface of the upper string ofcasing 110L after the expandable section 120L of thecasing 120 has been expanded. - Also positioned on the outer surface of the lower string of
casing 120 is at least oneslip member 224. Theslip member 224 is used to provide an improved grip between the expandable tubular 120E and the upper string ofcasing 110L when the lower string ofcasing 120 is expanded. In this example, theslip member 224 defines a plurality of carbide buttons interspersed within the matrix of the sealingmember 222. However, any suitable placement of a hardened material which provides a gripping means for the lower string ofcasing 120 into the upper string ofcasing 110 may be used. For example, a simple pair of rings having grip surfaces (not shown) formed thereon for engaging the inner surface of the upper string ofcasing 110 when the lower string ofcasing 120 is expanded would be suitable. The size, shape and hardness of theslips 224 are selected depending upon factors well known in the art such as the hardness of the inner wall ofcasing 110, the weight of thecasing string 120 being hung, and the arrangement ofslips 224 used. - In order to expand the lower string of
casing 120 seen in FIG. 1, anexpander tool 400 is provided. An expander tool as might be used in the expansion assembly is seen more fully in FIG. 6. FIG. 6 is an exploded view of anexemplary expander tool 400. FIG. 7 presents thesame expander tool 400 in cross-section, with the view taken across line 7-7 of FIG. 6. - The
expander tool 400 has abody 402 which is hollow and generally tubular. Thecentral body 402 has a plurality ofrecesses 414 to hold arespective roller 416. Each of therecesses 414 has parallel sides and holds arespective piston 420. Thepistons 420 are radially slidable, onepiston 420 being slidably sealed within eachrecess 414. The back side of eachpiston 420 is exposed to the pressure of fluid within thehollow bore 415 of thetool 400. In this manner, pressurized fluid provided from the surface of the well can actuate thepistons 420 and cause them to extend outwardly whereby therollers 416 contact the inner surface of the tubular 120L to be expanded. - It is understood that the
expander tool 400 shown in the referenced illustrations is merely exemplary. Any arrangement for an expander tool may be employed with the translation apparatus of thepresent invention 100. These include not only hydraulic expander tools, but mechanically activated expander tools as well. Further, the utility of the present invention is not limited to hydraulical expander tools that rely upon hydraulic pressure from the surface, but includes hydraulic expander tools that utilize a dedicated fluid reservoir associated with the tool. For example, a sealed fluid reservoir may be provided between concentric tubulars downhole. Fluid from this reservoir may be applied against the expansion assemblies within an expander tool, thereby urging them outwardly to expand a surrounding tubular. Alternatively, a blended system may be adopted having a mechanically advanced piston or other roller carrier that rides on a ramp, and has a hydraulic assist. - Disposed within each
piston 420 is aroller 416. In one embodiment of theexpander tool 400,rollers 416 are near-cylindrical and slightly barreled. Each of therollers 416 is supported by ashaft 418 at each end of therespective roller 416 for rotation about a respective rotational axis. Therollers 416 are preferably tilted at a very slight angle of approximately two degrees relative to the longitudinal axis of thetool 400. This aids in translation of the expander tool upward. In the arrangement of FIG. 6, the plurality ofrollers 416 are radially offset at mutual 120-degree circumferential separations around thecentral body 402. In the arrangement shown in FIG. 6, only a single row ofrollers 416 is employed. However, additional rows may be incorporated into thebody 402, as shown in FIG. 1. - The
rollers 416 illustrated in FIG. 6 have generally cylindrical or barrel-shaped cross sections; however, it is to be appreciated that other roller shapes are possible. For example, theroller 416 may have a cross sectional shape that is conical, truncated conical, semi-spherical, multifaceted, elliptical or any other cross sectional shape suited to the expansion operation to be conducted within the tubular 120. In addition, at least one portion of the roller surface is preferably tapered. In some instances, solid pads will take the place of rollers in an assembly. - The
expander tool 400 is preferably designed for use at or near the end of a workingstring 170. In the arrangement of FIG. 1, connection between the workingstring 170 and theexpander tool 400 is by amandrel 340′. Themandrel 340′ defines an elongated tubular body that extends into and through theexpander tool 400. The mandrel portion above theexpander tool 400 is shown at 340′, while the mandrel portion below the expander tool is shown at 340. Theupper mandrel 340′ includes aspline 337 which is received within a profile (not shown) within theexpander tool body 402. In this way, rotation of the workingstring 170 and theupper mandrel 340′ imparts rotation to theexpander tool 400. At the same time, and as will be described below, theupper mandrel 340′ is able to radially receive theexpander tool 400 when thetool 400 is translated upward by apositive displacement apparatus 300. - In order to actuate the
exemplary expander tool 400 of FIG. 6, fluid is injected into the workingstring 170. Fluid under pressure then travels downhole through the workingstring 170 and into the perforated tubular bore 415 of thetool 400. From there, fluid contacts the backs of thepistons 420. As hydraulic pressure is increased, fluid forces thepistons 420 outwardly from theirrespective recesses 414. This, in turn, causes therollers 416 to make contact with the inner surface of the liner 120L. Fluid finally exits theexpander tool 400 through themandrel 340 at the base of thetool 400. The circulation of fluids to and within theexpander tool 400 is preferably regulated so that the contact between and the force applied to the inner wall of theliner 120E is controlled. The pressurized fluid causes thepiston assembly 420 to extend radially to place therollers 416 into contact with the inner surface of the lower string ofcasing 120E. With a predetermined amount of fluid pressure acting on thepiston surface 420, the lower string ofexpandable liner 120E is expanded past its elastic limits. Of course, as noted previously, other means for activating the pistons of the expander tool may be employed. - In the arrangement of FIG. 1, the lower end of the
expander tool 400 is connected to apositive displacement apparatus 300. Thepositive displacement apparatus 300 generally defines a tubular assembly which is able to translate theexpander tool 400 upwardly in thewellbore 100 when theexpander tool 400 and thepositive displacement apparatus 300 are rotated. - In the arrangement shown in FIG. 1, the
positive displacement apparatus 300 first comprises a set of three essentially concentric tubular members which reside below theexpander tool 400. The three tubulars represent (1) anouter sleeve 330, (2) aninner mandrel 340, and (3) amiddle displacement piston 355 nested between thesleeve 330 and themandrel 340. These threetubular members expandable liner 120 or other tubular to be expanded. Hence, fourseparate tubulars upper casing string 100. - FIG. 4 is a cross-sectional view of a
positive displacement apparatus 300 of the present invention, taken across line 4-4 of FIG. 1. The relative placement of theliner string 120 and of the threetubulars inner mandrel 340 and thedisplacement piston 355. Likewise, an annular region is found between thedisplacement piston 355 and theouter sleeve 330. Also, an annular region is created between thesleeve 330 and theliner string 120. Finally, ahollow bore 345 is defined within theinner mandrel 340. - Each of the three
tubulars positive displacement apparatus 300 has an upper end and a lower end. The upper end of thedisplacement piston 355 is connected to theexpander tool 400. Connection is preferably by a threaded connection. - In order to impart rotation to the
expander tool 400, and as noted above, asplined connection 337 is provided between theupper mandrel 340′ and theexpander tool body 402. Thesplined connection 337 is in the nature of a traveling spline. - A
fluid transfer chamber 348 is provided below thedisplacement piston 355. Thefluid transfer chamber 348 and its related components are seen more fully in the enlarged view of FIG. 3. As shown, thefluid transfer chamber 348 is defined by theinner mandrel 340 on the inside, and by a fluidtransfer chamber housing 346 on the outside. The purpose of thefluid transfer chamber 348 is to serve as a reservoir through which oil may be transferred from the annular space 325 (shown in FIG. 4) outside of thesleeve 330 to the base of thedisplacement piston 355, thereby fluidly forcing thedisplacement piston 355 upward. Theannulus 325 is loaded with a clean, lightweight liquid medium such as oil. A cement bushing (not shown) positioned at a lower end of thepositive displacement apparatus 300 supports the column of fluid outside of thesleeve 330 and within theliner 120. As seen in FIG. 3, thefluid transfer chamber 348 is placed in fluid communication with theannulus 325 by means of anannular feed channel 324. Theannular feed channel 324 has a through-opening 324′ at one end which is in open communication with theannulus 325. At its opposite end, theannular feed channel 324 has a check valve opening 324″ which delivers oil to aninflow check valve 374. - The
inflow check valve 374 permits oil to flow into thefluid transfer chamber 348, but does not permit oil to flow out of thefluid transfer chamber 348. In the arrangement shown in FIG. 3, theinflow check valve 374 is a bullet nose check valve. However, any suitable one-way valve may be used. - As shown in FIG. 3, more than one check valve is employed for the
positive displacement apparatus 300. In addition to theinflow check valve 374, anoutflow check valve 372 is also provided. As with theinflow check valve 374, theoutflow check valve 372 is a one-way check valve. However, theoutflow check valve 372 permits oil to flow out of thefluid transfer chamber 348, but does not permit oil to flow into thefluid transfer chamber 348. In the arrangement shown in FIG. 3, theinflow check valve 372 is a bullet nose check valve. However, any suitable one-way valve may be used, or none at all. As oil is delivered through theinflow check valve 374, thefluid transfer chamber 348 is filled. As additional oil is pumped into thefluid transfer chamber 348, pressure is created therein. Ultimately, oil is forced out of thefluid transfer chamber 348 through theoutflow check valve 372. Oil flows from theoutflow check valve 372 and into apiston feed channel 334. This oil, in turn, provides a force against the lower end of themiddle displacement piston 355, forcing it upward with respect to theouter sleeve 330 and theinner mandrel 340. Because thedisplacement piston 355 is connected to the lower end of theexpander tool 400, upward displacement of thedisplacement piston 355 translates theexpander tool 400 upward within theexpandable tubular 120E. - The arrangement of FIG. 3 also presents a
transfer chamber channel 364. Thetransfer chamber channel 364 provides a path of fluid communication between thecheck valves fluid transfer chamber 348 itself. In this arrangement, thetransfer chamber channel 364 resides within a fluidtransfer channel housing 365. The fluidtransfer channel housing 365 defines the top of thefluid transfer chamber 348, and also houses thecheck valves fluid transfer chamber 348, through theoutflow check valve 372, and against thedisplacement piston 355. - A means is needed to draw oil from the
annular space 325 into thefluid transfer chamber 348. In the present invention, the drawing of oil is accomplished through positive displacement. In accordance with the present invention, astator member 210 is first provided. Thestator member 210, in one aspect, defines a tubular body which is disposed below thefluid transfer chamber 348. Thestator member 210 has a top surface which serves as aface 385. Theface 385 is configured in a wave form. Preferably, the wave form is sinusoidal. Thestator member 210 remains stationary, while themandrel 340′ rotates through it. - As seen in FIG. 1, a lower portion of the
mandrel 340″ extends below thestator 210. Thislower mandrel 340″ also rotates in response to rotation imparted by the workingstring 170. A swivel, shown schematically as a sub at 150, is positioned between thelower mandrel 340″ and thecollet 160 to further facilitate rotation of theinner mandrel 340 and thelower mandrel 340″. - Fixed between the
fluid transfer chamber 348 and thetubular body 210 is arotor piston 357. Therotor piston 357 is rotated as part of thepositive displacement apparatus 300. In this respect, a key or other splined-type connection 335 connects themandrel 340 to therotor piston 357 to impart rotation to therotor piston 357. In the arrangement of FIG. 3, the fluidtransfer channel housing 365 also includes separate split rings 332 and 362 which provide a locating shoulder between theouter sleeve 330, the fluidtransfer channel housing 365, and theinner mandrel 340. These split rings 332, 362 ensure that the components of thepositive displacement apparatus 300 remain axially stationary relative to therotor piston 357. It is understood, however, that the present invention is not limited to any particular manner in which therotor piston 357 is connected to thepositive displacement apparatus 300, so long as therotor piston 357 is able to reciprocate in response to the wave form on theface 385 of thestator member 210. - The
rotor piston 357 has an upper end which defines the bottom of thefluid transfer chamber 348. Therotor piston 357 further has a lower end that includes aface 380 configured in a wave form similar to theface 385 on thetubular body 210. Theface 380 of therotor piston 357 rides upon theface 385 of thestator member 210 as therotor piston 357 is rotated. Preferably, therotor piston face 380 and thestator member face 385 are each sinusoidal, though other wave forms may be used. This means that rotation of therotor piston 357 by 90 degrees creates a single stroke length. In the preferred arrangement, the stroke length is approximately one-half inch (1.27 cm). Thus, rotation of theexpander tool 400 and thepositive displacement apparatus 300, including therotor piston 357, serves to reciprocate therotor piston 357 in an up-and-down manner along a stroke length of approximately one-half of an inch. As will be shown, it is this reciprocating stroke that produces the positive displacement used to translate theexpander tool 400. - As noted, the
positive displacement apparatus 300 includes afluid transfer chamber 348. Thefluid transfer chamber 348 is sized and configured such that reciprocal movement of therotor piston 357 causes translational movement of thedisplacement piston 355. During the first half of the stroke cycle, therotor piston 357 moves upwards, thereby reducing the volume of thefluid transfer chamber 348. Reduction of the volume of thefluid transfer chamber 348 extrudes oil from thefluid transfer chamber 348 and into thepiston feed channel 334. This injection of oil moves thedisplacement piston 355 upward within theexpandable tubular 120E. - A biasing
member 342 is housed inside thefluid transfer chamber 348. The biasingmember 342 biases therotor piston 357 in its downward position to ensure essentially continuous contact between thebottom face 380 of therotor piston 357 and thetop face 385 of thestator member 210. Preferably, the biasingmember 342 is a spring. Thespring 342 becomes compressed during the first half of the stroke cycle when therotor piston 357 is thrust upward. During the second half of the rotor piston's 357 stroke cycle, therotor piston 357 moves back into phase with theface 385 of thestator member 210. Thespring 342 pushes therotor piston 357 back downward, re-expanding the volume of thefluid transfer chamber 348. The second half of the stroke cycle occurs after an additional 90 degree rotation of therotor piston 357. This movement downward of therotor piston 357 creates a vacuum within thefluid transfer chamber 348, thereby drawing fluid, e.g., oil, into thechamber 348 from the piston-sleeve annulus 325. With continued cycles, thetransfer chamber 348 becomes filled with fluid under pressure. Ultimately, the oil is extruded out of thetransfer chamber 348 and against the base of thedisplacement piston 355. - FIG. 5 presents a cross-sectional view of the
positive displacement apparatus 300 of FIG. 1. In this view, oil is being transferred from thefluid transfer chamber 348, up thetransfer chamber channel 364, and into thepiston feed channel 334. Visible in this view is the initial translation of themiddle displacement piston 355. Continued rotation of thepositive displacement apparatus 300 will raise thedisplacement piston 355 further within theexpandable tubular 120E. This, in turn, causes theexpander tool 400 to be translated upwardly. In this manner, theexpander tool 400 can be raised without raising the workingstring 170 itself. - In order to effectuate the transfer of oil from the
annulus 325, into thefluid transfer chamber 348, and against thedisplacement piston 355, it is desirable to utilize various seals between the components of thepositive displacement apparatus 300. FIG. 5 presents a variety of seals. These include afirst sealing member 356 at the lower end of thedisplacement piston 355. The sealingmember 356 creates a fluid seal between thedisplacement piston 355 and thetubulars piston feed channel 334 to fully act upon thedisplacement piston 355. Asecond sealing member 359 is disposed at the lower end of thetransfer channel housing 365. Thesecond sealing member 359 creates a fluid tight seal for thetransfer channel housing 365 between thetransfer chamber housing 346 and themandrel 340, thereby preventing a leakage from the upper end of thefluid transfer chamber 348. Athird sealing member 358 is disposed at the upper end of therotor piston 357. The sealingmember 358 creates a fluid tight seal for therotor piston 357 housed between thetransfer chamber housing 346 and themandrel 340, thereby preventing any fluid leakage from the lower end of thefluid transfer chamber 348. - Seals are additionally positioned inside and outside of the
outer sleeve 330 at the lower end. First, seal 337 seals the interface between theouter sleeve 330 and theinner mandrel 340. Second, seal 353 seals the annular area between theouter sleeve 330 and the fluidtransfer channel housing 365. Theseseals annular feed channel 324 during the translation process. Theseals - The present invention is not limited in scope to any single arrangement of seals. In this respect, various means are known for providing a fluid seal between nested tubulars. Any sealing arrangement may be utilized, so long as the reciprocation of the
rotor piston 357 within thefluid transfer chamber 348 is able to draw oil in during a first stroke, and extrude oil during an opposite second stroke. In the arrangement shown in FIGS. 3 and 5, oil is drawn into thefluid transfer chamber 348 on the downstroke, and extruded during the upstroke. Of course, theapparatus 300 can also be configured to draw oil on the upstroke and to discharge on the downstroke. - In operation, the
positive displacement apparatus 300 of the present invention is run into thewellbore 100 on the lower end of the workingstring 170. As seen in FIG. 1, thepositive displacement apparatus 300 is connected to theexpander tool 400 at one end. In the arrangement shown in FIG. 1, theapparatus 300 is connected to the bottom of theexpander tool 400. However, it will be appreciated that thepositive displacement apparatus 300 will also function if thepositive displacement apparatus 300 is above theexpander tool 400. In this regard, thecheck valves chamber 348 andchannel 364 would be positioned above thedisplacement piston 355. - In order to accomplish the expansion operation in a single trip, the working
string 170 also is temporarily connected to the lower string ofcasing 120. In this manner, the lower string ofcasing 120 can be introduced into thewellbore 100 at the same time as theexpander tool 400 and theapparatus 300. In FIG. 1, acollet 160 is presented as the releasable connection. Thecollet 160 is shown near the end of the workingstring 170. Thecollet 160 is landed into aradial profile 165 within the lower string ofcasing 120 so as to support the lower string ofcasing 120. Thecollet 160 is mechanically or hydraulically actuated as is known in the art, and supports the lower string ofcasing 120 until such time as the lower string ofcasing 120 has been expandably set by actuation of theexpander tool 400. - FIG. 8 depicts the wellbore of FIG. 1, in which the
expander tool 400 has been actuated. It can be seen that an initial portion of the lower string ofcasing 120 has been expanded. As explained above, actuation of theexpander tool 400 is by injection of fluid under pressure into the workingstring 170. Fluid travels from the surface, down the workingstring 170, and through thebore 415 of theexpander tool 400. - FIG. 9 depicts the
wellbore 100 of FIG. 8. In this view, theexpander tool 400 remains actuated. This allows theexpander tool 400 to move within theexpandable tube 120E relative to therunning tool collet 160. Also, in FIG. 9, the workingstring 170 has been rotated so as to begin raising theexpander tool 400 within theexpandable tubular 120E. As described above, rotation of the workingstring 170 causes thedisplacement piston 355 and, therewith, theexpander tool 400 to be translated axially within thewellbore 100. FIG. 9 thus demonstrates theexpander tool 400 being raised within the expandable tubular 120E by actuation of thepositive displacement apparatus 300. - It is contemplated in FIG. 1 that rotation of the
rotor piston 357 and of theexpander tool 400 is accomplished by rotating the working string, i.e.,drill pipe 170, from the surface. However, rotation may also be achieved by activation of a downhole rotary motor, such as a mud motor (not shown). - FIG. 10 depicts the
wellbore 100 of FIG. 9. Here, the actuatedexpander tool 400 has been raised further within thewellbore 100 so as to expand the lower string ofcasing 120 into the surrounding upper string ofcasing 110 along a desired length. This, in turn, results in an effective hanging and sealing of the lower string ofcasing 120 upon the upper string ofcasing 110 within thewellbore 100. Thus, theapparatus 300 enables a lower string ofcasing 120 to be hung onto an upper string ofcasing 110 by expanding thelower string 120 into theupper string 110, and without raising or lowering the workingstring 170 from the surface during expansion operations. It is understood, however, that the workingstring 170 may optionally be raised and lowered while theexpander tool 400 is still actuated and after the initial expansion has taken place, i.e., after theexpander tool 400 has been initially actuated. Using this procedure, thecollet 160 would first need to be released from theliner 120. - Following expansion operations, hydraulic pressure from the surface is relieved, allowing the
pistons 420 to return to therecesses 414 within thebody 402 of thetool 400. Theexpander tool 400 and thepositive displacement apparatus 300 can then be withdrawn from thewellbore 100 by pulling the run-intubular 170. FIG. 11 is a partial section view of thewellbore 100 of FIG. 10. In this view, theexpander tool 400 has been de-actuated and is being removed from thewellbore 100 along with thepositive displacement apparatus 300. In addition, thecollet 160 or other releasable connection must be released from theliner 120, as shown in FIG. 11. - In one procedure for utilizing the
positive displacement apparatus 300 of the present invention, theliner 120 is expanded to its top end. However, the length of expansion is discretionary. An uppernon-expanded portion 120S of theliner 120 can be severed after aportion 120E is expanded. The severedportion 120S of the lower string ofcasing 120 above theexpander tool 400 must then be removed from thewellbore 100. To accomplish this, typical casing severance operations may be conducted. This would be done via a subsequent trip into thewellbore 100. However, as an alternative shown in FIG. 11, the severedportion 120S of the lower string ofcasing 120 may be removed from thewellbore 100 at the same time as theexpander tool 400 after thecollet 160 has been released from theliner 120. In order to employ this method, anovel scribe 130 is formed on the outer surface of the lower string ofcasing 120. - An enlarged view of the
scribe 130 in one embodiment is shown in FIG. 2. Thescribe 130 defines a cut made into the outer surface of the lower string ofcasing 120. Thescribe 130 is preferably placed around thecasing 120 circumferentially. The depth of thescribe 130 needed to cause the break is dependent upon a variety of factors, including the tensile strength of the tubular, the overall deflection of the material as it is expanded, the profile of the cut, and the weight of the tubular being hung. Thescribe 130 must be shallow enough that the tensile strength of the tubular 120 supports the weight below thescribe 130 during run-in. The arrangement shown in FIG. 2 employs asingle scribe 130 having a V-shaped profile so as to impart a high stress concentration onto the casing wall. However, other profiles may be employed. - The
scribe 130 creates an area of structural weakness within thelower casing string 120. When the lower string ofcasing 120 is expanded at the depth of thescribe 130, the lower string ofcasing 120 is cleanly severed. The severed portion 120U of thelower casing string 120 can then be easily removed from thewellbore 100. Thus, thescribe 130 may serve as a release mechanism for thelower casing string 120. Other means for severing the tubular 120 upon expansion may be developed as well. - In order to remove the severed
portion 120S of the lower string of casing 120 from thewellbore 100, a second connection must be provided with the severed portion of the lower string ofcasing 120. In the arrangement of FIGS. 8-11, areleasable connector 124 is shown. Theconnector 124 is demonstrated as acollet 124 to be landed into aradial profile 125 within the lower string ofcasing 120. Thecollet 124 is mechanically or pneumatically actuated as is known in the art, and supports the severedportion 120S of the lower string ofcasing 120 while theapparatus 300 and theexpander tool 400 are being removed from thewellbore 100. Removal of the workingstring 170 with theexpander tool 400 brings with it the severedportion 120S of thelower casing string 120. It is, of course, understood that other means may be employed for removing a non-expanded upper portion ofliner 120, and that the arrangement shown in FIGS. 8-11 is purely exemplary. - FIG. 12 is a partial section view of the
wellbore 100 of FIG. 11. In this view, thepositive displacement apparatus 300 of the present invention and theexpander tool 400 have been removed. It can be seen that theexpandable portion 120E of the lower string ofcasing 120 has been expanded into frictional and sealing engagement with the upper string ofcasing 110. Theseal member 222 and theslip member 224 are engaged to the inner surface of the upper string ofcasing 110. Further, theannulus 135 between the lower string ofcasing 120 and the upper string ofcasing 110 has been optionally filled with cement, excepting that portion of the annulus which has been removed by expansion of the lower string ofcasing 120E. - As a further aid in the expansion of the
lower casing string 120, atorque anchor 200 may optionally be utilized. Thetorque anchor 200 serves to prevent rotation of thestator 210 during the expansion process. Thetorque anchor 200 shown in FIG. 1 includes radiallyextendable cleating mechanism 240 for engaging the inner surface of thecasing 110. Thetorque anchor 200 is actuated during initial expansion of theexpandable portion 120E of theliner 120. Thetorque anchor 200 may be released after initial expansion, as shown in FIG. 11. - While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
Claims (24)
1. An apparatus for translating an expander tool axially within a wellbore in order to facilitate the expansion of a first tubular into a surrounding second tubular, the apparatus comprising:
a fluid chamber having a first end and a second end;
a displacement piston having a first end and a second end, the first end of the displacement piston acting upon the expander tool, and the second end being in communication with the fluid chamber;
a rotor piston having a first end and a second end, the first end of the rotor piston sealingly residing within the fluid chamber; and
the fluid chamber sized and configured such that reciprocal movement of the rotor piston causes axial movement of the displacement piston within the wellbore.
2. The apparatus of claim 1 , further comprising a fluid medium that is applied under pressure against the second end of the displacement piston in order to translate the expander tool within the wellbore.
3. The apparatus of claim 2 , wherein the first tubular defines a lower string of casing, and the second tubular defines an upper string of casing.
4. The apparatus of claim 3 , wherein
the rotor piston has a bottom face at its second end, the bottom face having a wave form configuration; and
the first end of the rotor piston is reciprocated axially within the fluid transfer chamber by rotating the rotor piston.
5. The apparatus of claim 4 ,
further comprising a stator member, the stator member having a top face having a wave form configuration; and
wherein the bottom face of the rotor piston rides on the top face of the stator member such that rotation of the rotor piston causes the rotor piston to reciprocate axially.
6. The apparatus of claim 5 , wherein the stator member is stationary within the wellbore while the rotor piston is being rotated.
7. The apparatus of claim 6 , further comprising a biasing member disposed in the fluid chamber, the biasing member biasing the rotor piston to ensure essentially continuous contact between the bottom face of the rotor piston and the top face of the stator member.
8. The apparatus of claim 7 , further comprising:
an inner mandrel, the inner mandrel defining a tubular body nested essentially concentrically within the displacement piston;
an outer sleeve, the outer sleeve defining a tubular body surrounding the displacement piston such that the displacement piston is nested essentially concentrically within the outer sleeve; and
wherein the fluid medium is loaded in an annular region defined between the expandable first tubular and the outer sleeve.
9. The apparatus of claim 8 , further comprising:
an annular feed channel placing the annular region and the fluid chamber in fluid communication;
an inflow valve permitting fluid to flow from the annular region into the fluid chamber; and
an outflow valve permitting fluid to flow from the fluid chamber against the second end of the displacement piston in response to rotational movement of the rotor piston.
10. The apparatus of claim 9 , wherein the displacement piston is connected to the outer sleeve by a splined connection, allowing the displacement piston to move axially relative to the outer sleeve.
11. The apparatus of claim 10 , wherein the displacement piston is connected to the inner mandrel by a splined connection, allowing the displacement piston to move axially relative to the inner mandrel.
12. The apparatus of claim 9 , further comprising at least one seal at the first end of the rotor piston to provide a fluid seal between the rotor piston and the fluid chamber.
13. The apparatus of claim 12 , further comprising at least one seal at the second end of the displacement piston to provide a fluid seal between the displacement piston and the inner mandrel on an inner surface of the displacement piston, and between the displacement piston and the outer sleeve on an outer surface of the displacement piston.
14. An apparatus for translating an expander tool axially within a wellbore in order to facilitate the expansion of an upper portion of a liner string into a surrounding string of casing, the apparatus comprising:
a fluid transfer chamber having an upper end and a lower end;
a displacement piston having an upper end and a lower end, the upper end of the displacement piston acting upon the expander tool, and the lower end being in communication with the fluid chamber;
an inner mandrel, the inner mandrel defining a tubular body nested essentially concentrically within the displacement piston;
an outer sleeve, the outer sleeve defining a tubular body surrounding the displacement piston such that the displacement piston is nested essentially concentrically within the outer sleeve;
a rotor piston having an upper end and a lower end, the upper end of the rotor piston sealingly residing within the fluid transfer chamber;
oil, the oil loaded in an annular region defined between the expandable liner string and the outer sleeve;
an annular feed channel placing the annular region and the fluid chamber in fluid communication;
an inflow valve permitting the oil to flow from the annular region into the fluid chamber;
an outflow valve permitting the oil to flow from the fluid chamber against the lower end of the displacement piston in response to rotational movement of the rotor piston; and
the fluid chamber sized and configured such that reciprocal movement of the rotor piston causes axial movement of the displacement piston within the wellbore.
15. The apparatus of claim 14 , wherein the rotor piston has a bottom face at its lower end, the bottom face having a wave form configuration;
the second end of the rotor piston is reciprocated axially within the fluid transfer chamber by rotating the rotor piston;
16. The apparatus of claim 15 , further comprising a stationary stator member, the stator member having a top face having a wave form configuration; and
wherein the bottom face of the rotor piston rides on the top face of the stator member such that rotation of the rotor piston imparts an upstroke and a downstroke to the rotor piston, causing the rotor piston to reciprocate axially within the fluid transfer chamber such that oil is drawn into the fluid transfer chamber on the downstroke of the rotor piston, and oil is extruded under pressure against the displacement piston on the upstroke, thereby imparting axial movement to the displacement piston and to the expander tool within the wellbore.
17. The apparatus of claim 16 , further comprising a spring disposed in the fluid transfer chamber, the spring biasing the rotor piston to ensure essentially continuous contact between the bottom face of the rotor piston and the top face of the stator member.
18. The apparatus of claim 17 , wherein the displacement piston moves axially relative to the outer sleeve.
19. The apparatus of claim 18 , wherein the displacement piston moves axially relative to the inner mandrel.
20. The apparatus of claim 15 ,
further comprising a stationary stator member, the stator member having a top face having a wave form configuration; and
wherein the bottom face of the rotor piston rides on the top face of the stator member such that rotation of the rotor piston imparts a downstroke and an upstroke to the rotor piston, causing the rotor piston to reciprocate axially within the fluid transfer chamber such that oil is drawn into the fluid transfer chamber on the upstroke of the rotor piston, and oil is extruded under pressure against the displacement piston on the downstroke, thereby imparting axial movement to the displacement piston and to the expander tool within the wellbore.
21. An apparatus for translating an expander tool axially within a wellbore in order to facilitate the expansion of an upper portion of a liner string into a surrounding string of casing, the apparatus comprising:
a fluid transfer chamber having an upper end and a lower end;
a displacement piston having an upper end and a lower end, the upper end of the displacement piston acting upon the expander tool, and the lower end being in communication with the fluid chamber;
a rotor piston having an upper end and a lower end, the upper end of the rotor piston sealingly residing within the fluid transfer chamber, and the lower end having a bottom face, the bottom face having a wave form configuration;
a spring disposed in the fluid transfer chamber, the spring biasing the rotor piston to ensure essentially continuous contact between the bottom face of the rotor piston and the top face of the stator member;
a stator having an upper face having a wave form configuration which mates with the bottom face of the rotor piston; and
wherein the bottom face of the rotor piston rides on the top face of the stator member such that rotation of the rotor piston imparts an upstroke and a downstroke to the rotor piston, causing the rotor piston to reciprocate axially within the fluid transfer chamber such that oil is drawn into the fluid transfer chamber on the downstroke of the rotor piston, and oil is extruded under pressure against the displacement piston on the upstroke, thereby imparting axial movement to the displacement piston and to the expander tool within the wellbore.
22. The apparatus of claim 21 , further comprising a plurality of check valves, the check valves being constructed and arranged to allow the oil to enter the fluid transfer chamber on the downstroke of the rotor piston, and to exit the fluid transfer chamber on the upstroke of the rotor piston.
23. The apparatus of claim 22 , further comprising a plurality of check valves, the check valves being constructed and arranged to allow the oil to enter the fluid transfer chamber on the upstroke of the rotor piston, and to exit the fluid transfer chamber on the downstroke of the rotor piston.
24. The apparatus of claim 22 , further comprising:
an inner mandrel, the inner mandrel defining a tubular body nested essentially concentrically within the displacement piston;
an outer sleeve, the outer sleeve defining a tubular body surrounding the displacement piston such that the displacement piston is nested essentially concentrically within the outer sleeve; and
wherein the fluid medium is loaded in an annular region defined between the expandable liner string and the outer sleeve.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/253,114 US20040055786A1 (en) | 2002-09-24 | 2002-09-24 | Positive displacement apparatus for selectively translating expander tool downhole |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/253,114 US20040055786A1 (en) | 2002-09-24 | 2002-09-24 | Positive displacement apparatus for selectively translating expander tool downhole |
Publications (1)
Publication Number | Publication Date |
---|---|
US20040055786A1 true US20040055786A1 (en) | 2004-03-25 |
Family
ID=31993097
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/253,114 Abandoned US20040055786A1 (en) | 2002-09-24 | 2002-09-24 | Positive displacement apparatus for selectively translating expander tool downhole |
Country Status (1)
Country | Link |
---|---|
US (1) | US20040055786A1 (en) |
Cited By (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20030146003A1 (en) * | 2001-12-27 | 2003-08-07 | Duggan Andrew Michael | Bore isolation |
US20040177974A1 (en) * | 2001-04-06 | 2004-09-16 | Simpson Neil Andrew Abercrombie | Tubing expansion |
US20050000697A1 (en) * | 2002-07-06 | 2005-01-06 | Abercrombie Simpson Neil Andrew | Formed tubulars |
US20050126251A1 (en) * | 2001-08-16 | 2005-06-16 | Peter Oosterling | Apparatus for and a method of expanding tubulars |
EP1662087A1 (en) * | 2004-11-24 | 2006-05-31 | BAUER Maschinen GmbH | Device and method for providing hydraulic energy |
US20080156499A1 (en) * | 2007-01-03 | 2008-07-03 | Richard Lee Giroux | System and methods for tubular expansion |
US20080164018A1 (en) * | 2004-08-12 | 2008-07-10 | Wireline Engineering Limited | Downhole Device |
US20080230236A1 (en) * | 2007-03-21 | 2008-09-25 | Marie Wright | Packing element and method |
EP2039879A2 (en) * | 2007-09-18 | 2009-03-25 | Weatherford/Lamb, Inc. | Apparatus and methods for running liners |
GB2466565A (en) * | 2008-12-23 | 2010-06-30 | Tiw Corp | Actuator assembly for tubular expansion |
US20100243277A1 (en) * | 2007-09-18 | 2010-09-30 | Lev Ring | Apparatus and methods for running liners in extended reach wells |
NO20110031A1 (en) * | 2010-01-11 | 2011-07-12 | Tiw Corp | Tubular expansion tool and procedure |
US20110168411A1 (en) * | 2010-01-11 | 2011-07-14 | Braddick Britt O | Tubular expansion tool and method |
WO2019215519A1 (en) * | 2018-05-10 | 2019-11-14 | Deep Casing Tools, Ltd. | Method for removing casing from a wellbore |
US11434580B2 (en) * | 2019-02-28 | 2022-09-06 | Ebara Corporation | Plating apparatus |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3073134A (en) * | 1960-03-21 | 1963-01-15 | William L Mann | Variable length pipe |
US3642032A (en) * | 1970-04-16 | 1972-02-15 | Fischer Cook Inc | Internal pipe clamp applying apparatus and method |
US6668930B2 (en) * | 2002-03-26 | 2003-12-30 | Weatherford/Lamb, Inc. | Method for installing an expandable coiled tubing patch |
-
2002
- 2002-09-24 US US10/253,114 patent/US20040055786A1/en not_active Abandoned
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3073134A (en) * | 1960-03-21 | 1963-01-15 | William L Mann | Variable length pipe |
US3642032A (en) * | 1970-04-16 | 1972-02-15 | Fischer Cook Inc | Internal pipe clamp applying apparatus and method |
US6668930B2 (en) * | 2002-03-26 | 2003-12-30 | Weatherford/Lamb, Inc. | Method for installing an expandable coiled tubing patch |
Cited By (30)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6976536B2 (en) * | 2001-04-06 | 2005-12-20 | Weatherford/Lamb, Inc. | Tubing expansion |
US20040177974A1 (en) * | 2001-04-06 | 2004-09-16 | Simpson Neil Andrew Abercrombie | Tubing expansion |
US7174764B2 (en) | 2001-08-16 | 2007-02-13 | E2 Tech Limited | Apparatus for and a method of expanding tubulars |
US20050126251A1 (en) * | 2001-08-16 | 2005-06-16 | Peter Oosterling | Apparatus for and a method of expanding tubulars |
US7798223B2 (en) | 2001-12-27 | 2010-09-21 | Weatherford/Lamb, Inc. | Bore isolation |
US7066259B2 (en) * | 2001-12-27 | 2006-06-27 | Weatherford/Lamb, Inc. | Bore isolation |
US20060283607A1 (en) * | 2001-12-27 | 2006-12-21 | Duggan Andrew M | Bore isolation |
US20030146003A1 (en) * | 2001-12-27 | 2003-08-07 | Duggan Andrew Michael | Bore isolation |
US20050000697A1 (en) * | 2002-07-06 | 2005-01-06 | Abercrombie Simpson Neil Andrew | Formed tubulars |
US7866384B2 (en) * | 2004-08-12 | 2011-01-11 | Wireline Engineering Limited | Downhole device |
US20080164018A1 (en) * | 2004-08-12 | 2008-07-10 | Wireline Engineering Limited | Downhole Device |
EP1662087A1 (en) * | 2004-11-24 | 2006-05-31 | BAUER Maschinen GmbH | Device and method for providing hydraulic energy |
US20080156499A1 (en) * | 2007-01-03 | 2008-07-03 | Richard Lee Giroux | System and methods for tubular expansion |
US8069916B2 (en) | 2007-01-03 | 2011-12-06 | Weatherford/Lamb, Inc. | System and methods for tubular expansion |
US20080230236A1 (en) * | 2007-03-21 | 2008-09-25 | Marie Wright | Packing element and method |
EP2039879A3 (en) * | 2007-09-18 | 2011-04-13 | Weatherford/Lamb, Inc. | Apparatus and methods for running liners |
US8839870B2 (en) | 2007-09-18 | 2014-09-23 | Weatherford/Lamb, Inc. | Apparatus and methods for running liners in extended reach wells |
EP2407635A3 (en) * | 2007-09-18 | 2014-11-26 | Weatherford/Lamb, Inc. | Apparatus and methods for running liners |
US20100243277A1 (en) * | 2007-09-18 | 2010-09-30 | Lev Ring | Apparatus and methods for running liners in extended reach wells |
EP2039879A2 (en) * | 2007-09-18 | 2009-03-25 | Weatherford/Lamb, Inc. | Apparatus and methods for running liners |
GB2466565A (en) * | 2008-12-23 | 2010-06-30 | Tiw Corp | Actuator assembly for tubular expansion |
US20110168411A1 (en) * | 2010-01-11 | 2011-07-14 | Braddick Britt O | Tubular expansion tool and method |
US8408317B2 (en) * | 2010-01-11 | 2013-04-02 | Tiw Corporation | Tubular expansion tool and method |
NO20110031A1 (en) * | 2010-01-11 | 2011-07-12 | Tiw Corp | Tubular expansion tool and procedure |
NO346185B1 (en) * | 2010-01-11 | 2022-04-11 | Tiw Corp | Tubular expansion tool and procedure |
WO2019215519A1 (en) * | 2018-05-10 | 2019-11-14 | Deep Casing Tools, Ltd. | Method for removing casing from a wellbore |
GB2583282A (en) * | 2018-05-10 | 2020-10-21 | Deep Casing Tools Ltd | Method for removing casing from a wellbore |
US10934796B2 (en) | 2018-05-10 | 2021-03-02 | Deep Casing Tools, Ltd. | Method for removing casing from a wellbore |
GB2583282B (en) * | 2018-05-10 | 2022-06-08 | Deep Casing Tools Ltd | Method for removing casing from a wellbore |
US11434580B2 (en) * | 2019-02-28 | 2022-09-06 | Ebara Corporation | Plating apparatus |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US6722441B2 (en) | Threaded apparatus for selectively translating rotary expander tool downhole | |
US20030168222A1 (en) | Closed system hydraulic expander | |
US6752216B2 (en) | Expandable packer, and method for seating an expandable packer | |
US20040055786A1 (en) | Positive displacement apparatus for selectively translating expander tool downhole | |
CN1298963C (en) | System for lining a section of a wellbore | |
US7350588B2 (en) | Method and apparatus for supporting a tubular in a bore | |
US20030042022A1 (en) | High pressure high temperature packer system, improved expansion assembly for a tubular expander tool, and method of tubular expansion | |
US6668930B2 (en) | Method for installing an expandable coiled tubing patch | |
CN101087926B (en) | expansion pig | |
CN1930369B (en) | Expander for expanding a tubular element | |
US20100319427A1 (en) | Apparatus and method for expanding tubular elements | |
US20030075337A1 (en) | Method of expanding a tubular member in a wellbore | |
US20020166664A1 (en) | Expansion assembly for a tubular expander tool, and method of tubular expansion | |
US20030085041A1 (en) | Expandable tubular having improved polished bore receptacle protection | |
US9976396B2 (en) | Apparatus and method for setting a liner | |
US6820687B2 (en) | Auto reversing expanding roller system | |
US20040129431A1 (en) | Multi-pressure regulating valve system for expander | |
US7308944B2 (en) | Expander tool for use in a wellbore | |
US11299948B2 (en) | Downhole method for removal of tubular metal structure | |
GB2427885A (en) | Radial expansion and plastic deformation tool | |
US20040140086A1 (en) | Expansion apparatus having resistive medium | |
CA2617489C (en) | Auto reversing expanding roller system |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: WEATHERFORD/LAMB, INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MAGUIRE, PATRICK G.;TRAN, KHAI;REEL/FRAME:013327/0004;SIGNING DATES FROM 20020916 TO 20020917 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO PAY ISSUE FEE |