System and methods for recovering hydrocarbons

A wellbore servicing method includes positioning a tubing string within a wellbore. The tubing string comprises a lower tubular coupled to an upper tubular via a disconnectable assembly having a lower section connected to the lower tubular and an upper section connected to the upper tubular. The method also includes disconnecting the lower tubular from the upper tubular via the disconnectable assembly. Disconnecting the lower tubular from the upper tubular comprises introducing a releasing member into the upper tubular and conveying the releasing member through the upper tubular to engage the disconnectable assembly. The method also includes retracting the upper tubular upwardly within the wellbore. Upon retracting the upper tubular, the releasing member is retracted along with the upper section of the disconnectable assembly. Also, upon retracting the upper tubular, a route of fluid communication out of the upper tubular is provided.

Not applicable.

REFERENCE TO A MICROFICHE APPENDIX

Not applicable.

BACKGROUND

Wellbores are sometimes drilled into subterranean formations containing hydrocarbons, for example, to allow for the recovery of hydrocarbons from the subterranean formation. Conventionally, various wellbore tubulars may be conveyed into the wellbore for various purposes, such as drilling the wellbore, servicing the wellbore, producing the hydrocarbons from the wellbore, or combinations thereof. For example, a wellbore casing string may be positioned, and in some cases secured, within a wellbore, for example, so as to ensure the wellbore against collapse. Such a casing string may be run into a wellbore, for example, suspended from a work string and decoupled from the work string so as to allow at least a portion of the wellbore tubular (e.g., the casing string) to remain in a particular portion or section of the wellbore, such as a section of the wellbore penetrating a coal seam. For example, a wellbore tubular (e.g., a casing string) may be decoupled from a work string so as to remain within a section of the wellbore so as to provide structural support for a horizontal wellbore, repair a section of another wellbore tubular (e.g., another casing string), provide a route of fluid communication for the production of hydrocarbons (such as methane gas, from a wellbore penetrating a coal bed), or combinations thereof. However, conventional apparatuses, systems, and methods utilized to position such wellbore tubulars suffer from various shortcomings. As such, there is a need for improved apparatuses, systems, and methods that may be suitably employed to deploy a wellbore tubular within a wellbore.

SUMMARY

Disclosed herein is a wellbore servicing method comprising positioning a wellbore tubing string within a wellbore, wherein the wellbore tubing string comprises a lower wellbore tubular coupled to an upper wellbore tubular via a disconnectable assembly having a lower section connected to the lower wellbore tubular and an upper section connected to the upper wellbore tubular, disconnecting the lower wellbore tubular from the upper wellbore tubular via the disconnectable assembly, wherein disconnecting the lower wellbore tubular from the upper wellbore tubular comprises introducing a releasing member into the upper wellbore tubular, and conveying the releasing member through the upper wellbore tubular to engage the disconnectable assembly; and retracting the upper wellbore tubular upwardly within the wellbore, wherein upon retracting the upper wellbore tubular, the releasing member is retracted along with the upper section of the disconnectable assembly, and wherein upon retracting the upper wellbore tubular, a route of fluid communication out of the upper wellbore tubular is provided.

Also disclosed herein is a wellbore connection system comprising a first wellbore tubular, a second wellbore tubular, a disconnectable assembly comprising a lower section, wherein the upper section is coupled to the first wellbore tubular, and an upper section, wherein the upper section is coupled to the second wellbore tubular, and wherein the lower section is selectively, disconnectably coupled to the upper section, a releasing member configured to uncouple the lower section from the upper section, wherein the disconnectable assembly and/or the releasing member is configured such that upon uncoupling the lower section from the upper section, the releasing member is at least partially retained by the upper section, and wherein the disconnectable assembly and/or the releasing member is configured so as to provide a route of fluid communication upon uncoupling the lower section from the upper section.

Further disclosed herein is a wellbore connection system comprising a first wellbore tubular, the first wellbore tubular disposed in an upper portion of a wellbore, a lower section of a dissconnectable assembly, wherein the lower section is coupled to the first wellbore tubular, and a second wellbore tubular, the second wellbore tubular disposed in an upper portion of the wellbore, an upper section of the disconnectable assembly, wherein the upper section is coupled to the second wellbore tubular, and a releasing member, wherein the releasing member is at least partially retained by the upper section of the disconnectable assembly.

DETAILED DESCRIPTION OF THE EMBODIMENTS

In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. In addition, similar reference numerals may refer to similar components in different embodiments disclosed herein. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present invention is susceptible to embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is not intended to limit the invention to the embodiments illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “up-hole,” “upstream,” or other like terms shall be construed as generally from the formation toward the surface or toward the surface of a body of water; likewise, use of “down,” “lower,” “downward,” “down-hole,” “downstream,” or other like terms shall be construed as generally into the formation away from the surface or away from the surface of a body of water, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis.

Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.

Disclosed herein are embodiments of wellbore servicing apparatuses, systems, and methods of using the same. Particularly disclosed herein are one or more embodiments of a disconnectable connection assembly (DCA), as well as systems and methods of utilizing and/or employing the same. In one or more embodiments, as will be disclosed herein, the DCA may generally be configured to selectively, axially couple two tubular strings. For example, in an embodiment as will be disclosed herein, a DCA may be configured to couple a first tubular string (e.g., casing string) and a second tubular string (e.g., a work string) such that the casing string may be run into a wellbore suspended from the work string. The DCA may also be configured such that the casing string may be disconnected from the work string, for example, without leaving an obturating member disposed within the casing (e.g., so as to not block any portion of the casing string) and/or while providing a flow path out of the work string, for example, during removal of the work string from the wellbore.

Referring toFIG. 1, an example of an operating environment in which such a DCA and/or a system comprising such a DCA may be employed is illustrated. As depicted inFIG. 1, the operating environment generally comprises a wellbore114that penetrates a subterranean formation102for the purpose of recovering hydrocarbons, storing hydrocarbons, disposing of carbon dioxide, or the like. The wellbore114may be drilled into the subterranean formation102using any suitable drilling technique. In an embodiment, a drilling or servicing rig106disposed at the surface104comprises a derrick108with a rig floor110through which various tubular strings, (e.g., a work string, such as a drill string, a tool string, a segmented tubing string, a jointed tubing string, a casing string, or any other suitable conveyance, or combinations thereof) generally defining an axial flow bore may be positioned within or partially within wellbore114. In an embodiment, such a tubular string may comprise two or more concentrically positioned strings of pipe or tubing (e.g., a first work string may be positioned within a second work string). The drilling or servicing rig may be conventional and may comprise a motor driven winch and other associated equipment for lowering the tubular string(s) into wellbore114. Alternatively, a mobile workover rig, a wellbore servicing unit (e.g., coiled tubing units), or the like may be used to lower the tubular string into the wellbore114. In such an embodiment, the tubular string(s) may be utilized in drilling, stimulating, completing, or otherwise servicing the wellbore, or combinations thereof.

The wellbore114may extend substantially vertically away from the earth's surface over a vertical wellbore portion, or may deviate at any angle from the earth's surface104over a deviated or horizontal wellbore portion. For example, in an embodiment, the horizontal wellbore portion may penetrate a subterranean formation zone, such as a coal seam138, as shown inFIG. 1, for example, for the purpose of extracting methane gas present within the coal seam138. In alternative operating environments, portions or substantially all of wellbore114may be vertical, deviated, horizontal, and/or curved. In some embodiments, at least a portion of the wellbore114may be lined with a casing120that is secured into position against the formation102in a conventional manner using cement122. In alternative operating environments, the wellbore114may be partially cased and cemented thereby resulting in a portion of the wellbore114being uncased. In an embodiment, a portion of wellbore114may be cased and may remain uncemented, but may employ one or more packers (e.g., mechanical and/or swellable packers, such as Swellpackers™, commercially available from Halliburton Energy Services, Inc.) to isolate two or more adjacent portions or zones within wellbore114. Alternatively, portions or substantially all of the wellbore114may be uncased and/or uncemented. It is noted that although some of the figures may exemplify a horizontal or vertical wellbore, the principles of the system, apparatuses, and methods disclosed may be similarly applicable to horizontal wellbore configurations, conventional vertical wellbore configurations, new wellbores, existing wellbores, straight wellbores, extended reach wellbores, sidetracked wellbores, multi-lateral wellbores, other types of wellbores for drilling and completing one or more production zones, or combinations thereof. Therefore, the horizontal or vertical nature of any figure is not to be construed as limiting the wellbore to any particular configuration.

Referring toFIG. 1, a wellbore disconnect system100is illustrated positioned within the wellbore114. In the embodiment ofFIG. 1, the wellbore disconnect system100generally comprises a wellbore tubing string, particularly, a first wellbore tubing string selectively coupled to a second wellbore tubing string via a DCA200. For example, in the embodiment ofFIG. 1, the wellbore servicing system100comprises a casing string204releasably suspended from a work string202by the DCA200. In such an embodiment, the casing string204may be coupled to the work string202via the DCA, for example, at a position relatively downhole from the work string202. Also, in such an embodiment, the work string202may be positioned within the wellbore114such that the casing string204is and/or may be positioned at a desired, predetermined depth within the wellbore114, for example, proximate and/or substantially adjacent to one or more zones of the subterranean formation102, for example, within a coal seam138. While one or more of the embodiments herein may disclose the DCA200with reference to a casing string and/or to a work string (e.g., the casing string204, which is run into the wellbore114suspended from the work string202), in additional or alternative embodiments, a DCA (such as DCA200, which is disclosed herein) may be similarly employed to releasably couple any suitable first wellbore tubular and/or wellbore tool to any other suitable second wellbore tubular; as such, this disclosure should not be construed as so-limited. Additionally, in an embodiment the wellbore disconnect system100may further comprise a releasing member300(e.g., a releasing dart).

In an embodiment, the casing string204may be generally configured so as (when positioned within the wellbore114) to provide a route of fluid communication through at least a portion of the subterranean formation102and/or to maintain the integrity of the wellbore114, for example, for the production of hydrocarbons. For example, the casing string204may be configured to prevent the wellbore114(e.g., a horizontal wellbore portion) from collapse. Also, the casing string204may be disposed within the wellbore114(e.g., within a horizontal wellbore portion) so as to allow one or more formation fluid to be produced therefrom, for example, so as to extract methane gas from a coal seam. The casing string204may comprise any suitable type and/or configuration thereof. For example, the casing string204may generally comprise a production tubular, such as a jointed tubing string, a coiled tubing string, or combinations thereof. Also, in embodiments, substantially all or portions of the casing string204may be perforated or un-perforated. The casing string204may be formed from a suitable material, examples of which include but are not limited to, metals and/or metallic alloys, such as aluminum, iron, or steel; synthetic materials, such as plastics; composite materials, such as fiberglass; any other suitable material as will be appreciated by one of ordinary skill in the art upon viewing this disclosure, or combinations thereof.

While one or more of the embodiments of this disclosure may refer to a casing string204configured for use in a production operation (e.g., a production string), as disclosed herein, a tubular string may be configured for various additional or alternative operations and, as such, this disclosure should not be construed as limited to utilization in any particular wellbore servicing context unless so-designated. For example, in an embodiment, a tubular string (e.g., like the casing string204) may be configured for a servicing operation, such as a stimulation operation, a completion operation, a clean-out operation, or combinations thereof. In such an embodiment, such a tubular string may comprise one or more wellbore servicing tools (e.g., perforating, fracturing, and/or the like)

In an embodiment, the work string202may be generally configured to deliver the casing string204to a desired and/or predetermined location within the wellbore114. The work string may comprise any suitable type and/or configuration of tubular string. Suitable types/configurations of such a tubular string include, but are not limited to a drill string, a coiled-tubing string, a segmented tubing string, a jointed tubing string, or any other suitable conveyance, or combinations thereof, as may be appropriate for a given operation or environment.

Referring toFIGS. 2A, 2B, and 2C, an embodiment of a DCA200is illustrated. In the embodiment ofFIGS. 2A, 2B, and 2C, the DCA200generally comprises an upper section10aand a lower section10b. Each of the upper section10aand the lower section10bcomprises a generally tubular structure, with respect to a longitudinal axis28, cooperatively defining an axial flowbore26extending longitudinally therethrough. In an embodiment, and as will be disclosed herein, the DCA200is generally configured such that the upper section10aand the lower section10bmay be selectively connected, alternatively, selectively disconnected. For example,FIGS. 2A and 2Billustrate the DCA200in a first or “connected” configuration, for example, where the upper section10aand the lower section10bare coupled together (e.g., longitudinally).FIG. 2Cillustrates the DCA200in a second or “disconnected” configuration where the upper section10aand lower section10bare separated. Additionally,FIG. 2Billustrates the DCA200at an intermediate stage, for example, during the decoupling of the lower section10bfrom the upper section10a, as will be disclosed herein. As will be explained in detail below, the DCA200comprises a coupling mechanism configured such that in the connected configuration the coupling mechanism couples (e.g., longitudinally) the upper section10ato the lower section10b, and in the disconnected configuration the coupling mechanism does not couple the upper section10ato the lower section10b, for example, thereby allowing the upper section10aand the lower section10bto be longitudinally separated.

While an embodiment of the DCA200is disclosed with respect toFIGS. 2A, 2B, and2C, one of skill in the art upon viewing this disclosure, will recognize suitable alternative configurations. As such, while embodiments of a DCA may be disclosed with reference to a given configuration (e.g., DCA200as will be disclosed with respect toFIGS. 2A, 2B, and 2C), this disclosure should not be construed as limited to such embodiments.

In the embodiment ofFIGS. 2A, 2B, and 2C, the upper section10aof the DCA200is connected to (e.g., incorporated with) the work string202; for example, the upper section10ais connected to a lower, terminal end of the work string202via a suitable interface (e.g., a threaded connection, as will be disclosed herein). Also in the embodiment ofFIGS. 2A, 2B, and 2C, the lower section10bof the DCA200is connected to (e.g., incorporated with) the casing string204; for example, the lower section10bis connected to an upper, terminal end of the casing string204via suitable interface (e.g., a threaded connection, as will also be disclosed herein). Alternative, suitable connections may be appreciated by one of skill in the art upon viewing this disclosure. In an embodiment, the DCA200may be generally configured such that, when activated (e.g., transitioned from the first, connected configuration to the second, disconnected configuration) as will be disclosed herein, the lower section10bmay be selectively released (e.g., decoupled) from the upper section10a, for example, so as to selectively couple or decouple the casing string204to/from the work string202. The individual components of the DCA206will now be discussed with reference toFIGS. 2A, 2B, and 2C.

In an embodiment, the upper section10aof the DCA200generally comprises an upper housing14, a collet retainer16, and a releasing member retainer18, cooperatively generally defining an upper portion of the axial flowbore26a. In the embodiment ofFIGS. 2A, 2B, and 2C, the upper housing14and the collet retainer16comprise two or more separate, operably coupled components (e.g., coupled via a suitable connected, such as a welded or threaded connection). Also in the embodiment ofFIGS. 2A, 2B, and 2C, the upper housing14and the releasing member retainer18comprise a single, unitary structure. In alternative embodiments, two or more of the upper housing14, the collet retainer16, and the releasing member retainer18may comprise separate, operably-joined components or may comprise a single, unitary structure.

In an embodiment, the upper housing14generally comprises a cylindrical or tube-like structure. In an embodiment, the upper housing14may be adapted for connection to the work string202(alternatively, to any suitable wellbore tubular) in a suitable manner, as disclosed herein. For example, in an embodiment, the upper housing14comprises an internally threaded surface30(alternatively, an externally threaded surface) to connect to the work string202. Additional or alternative suitable connections will be known to those of skill in the art upon viewing this disclosure.

Referring toFIG. 1, the DCA200is incorporated within the work string202such that the axial flowbore26of the DCA200is in fluid communication with the axial flowbore126of the work string202. For example, the DCA200is incorporated within the work string202such that a fluid may be communicated between the axial flowbore126of the work string202and the axial flowbore26of the DCA200.

Referring toFIG. 3, an embodiment of the releasing member retainer18is illustrated. In an embodiment, the releasing member retainer18is generally configured to interact with at least a portion of the releasing member300so as to retain at least a portion of the releasing member300from passing therethrough. In an embodiment, the releasing member retainer18generally comprises a narrowing and/or reduction in the inner diameter of the upper portion of the axial flowbore26a(e.g., a choke). For example, in the embodiment ofFIG. 3, the releasing member retainer18comprises radially inward shoulder or protrusion (alternatively, a plurality of radially inward shoulders or protrusions) within the upper housing14. In the embodiment ofFIG. 3, the diameter of the axial flowbore26(e.g., the upper portion of the axial flowbore) narrows at a bevel18a(alternatively, a chamfer, shoulder, or the like) to a bore surface18bhaving a decreased diameter relative to the diameter of the axial flowbore26. In such an embodiment, releasing member retainer18(e.g., the bevel18aand/or bore surface) may define an inner profile.

In an embodiment, the releasing member retainer18may be configured to allow a route of fluid communication from one side of the releasing member retainer18(e.g., an uphole side) to the other side of the releasing member retainer18(e.g., the downhole side) when the bore18bis blocked or obscured (e.g., by an obturating member, such as a dart, as will be disclosed herein). For example, in the embodiment ofFIG. 3, the releasing member retainer18comprises one or more slots18c(alternatively, grooves, bores, notches, holes, channels, or the like) extending generally longitudinally through the releasing member retainer18. For example, where the bore18bextending through the releasing member retainer18is blocked (e.g., by the releasing member or a portion thereof, as will be disclosed herein), fluid may be communicated through the slots18c, which may form a fluidic pathway between the uphole and downhole sides of the releasing member retainer18, as will be disclosed herein.

In an embodiment, the collet retainer16is coupled to (alternatively, forms) a lower end of the upper housing14. In an embodiment, the collet retainer16generally comprises a cylindrical or tube-like structure, having a first inner bore surface64and a second inner bore surface66. In the embodiment ofFIGS. 2A, 2B, and 2C, the first inner bore surface64is generally located above (e.g., uphole from) the second inner bore surface66and comprises a relatively greater diameter than the second inner bore surface66. Also in the embodiment ofFIGS. 2A, 2B, and 2C, the first inner bore surface64narrows (e.g., radially inward) at a bevel65(alternatively, a chamfer, lip, shoulder, seat, or the like) to the second inner bore surface66. In an embodiment, the first inner bore surface64, the bevel65, and/or the second inner bore surface66may cooperatively form an inner profile. In an embodiment, at least a portion of the inner profile may be complementary to at least a portion of the lower section (e.g., at least a portion of a collet, as will be disclosed herein).

In an embodiment, the lower section10bof the DCA200generally comprises a lower housing20, a releasing collet22, and a releasing sleeve24, cooperatively generally defining a lower portion of the axial flowbore26b. In the embodiment ofFIGS. 2A, 2B, and 2C, the lower housing20and the releasing collet22comprise two or more separate, operably coupled components (e.g., coupled via a suitable connection, such as a welded or threaded connection). In alternative embodiments, the lower housing20and the releasing collet22may comprise a single, unitary structure.

In an embodiment, the lower housing20generally comprises a cylindrical or tube-like structure. In an embodiment, the lower housing20may be adapted for connection to the casing string204(alternatively, to any suitable wellbore tubular) in a suitable manner, as disclosed herein. For example, in an embodiment, the lower housing20comprises an externally threaded surface32(alternatively, an internally threaded surface) to connect to the casing string204. Additional or alternative suitable connections will be known to those of skill in the art upon viewing this disclosure.

Referring toFIG. 1, the DCA200is incorporated within the work string204such that the axial flowbore26of the DCA200is in fluid communication with the axial flowbore126of the work string204. For example, the DCA200is incorporated within the casing string204such that a fluid may be communicated between the axial flowbore126of the casing string204and the axial flowbore26of the DCA200.

In an embodiment, the lower housing20may be configured to house and/or retain the releasing collet22. For example, in the embodiment ofFIGS. 2A, 2B, and 2C, the lower housing20comprises a collet recess25. In such an embodiment, the collet recess25may comprise a first inner bore surface27and a second bore surface29, for example, the first bore surface27having a diameter greater than the diameter to the second bore surface29. The collet recess25may be generally sized to receive the releasing collet22or a portion thereof. Additionally, in an embodiment, the collet recess25may be configured to retain the releasing collet. For example, in an embodiment the collet recess25(e.g., the first bore surface) may comprise a threaded surface generally configured to interface with the releasing collet22.

In an embodiment, the releasing collet22comprises a generally cylindrically shaped structure. In an embodiment, the releasing collet22generally comprises a radially outwardly protruding rim80, a flexible (or upper) portion82, and a lower (or base) portion84. In an embodiment, the outwardly protruding rim extends circumferentially at least partially around an upper end of releasing collet22. The rim80may comprise a diameter generally greater than the diameter of the remainder of the releasing collet22, for example, narrowing at a generally downwardly-facing bevel81or shoulder. In an embodiment, the releasing collet22(e.g., the outwardly protruding rim80) may generally define an outer profile. In an embodiment, at least a portion of the outer profile may be complementary to the at least at portion of the inner profile defined by the first inner bore surface64, the bevel65, and/or the second inner bore surface66(e.g., of the collet retainer16, as disclosed herein).

In an embodiment, the flexible portion82is located generally downward from the rim80. In an embodiment, the flexible portion82may comprise a wall thickness that is narrow relative to the lower portion84of the releasing collet22. Also, in an embodiment, the releasing collet22may comprise a predetermined number of longitudinal slots extending from the top of the rim80through the upper flexible portion82(e.g., a portion of the longitude of the releasing collet22), for example, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, or any suitable number of slots. In an embodiment, the slots may be substantially equally spaced around the periphery of the rim80and/or the flexible portion82. Also, in an embodiment, the slots may radially divide the flexible portion82of the releasing collet22into a plurality of radially-spaced “fingers” (e.g., collet fingers or cage) or longitudinal protrusions. As will be explained herein, the slots and/or the narrowed wall thickness of the flexible portion82may allow the diameter of the rim80to vary. For example, the rim80can be considered “flexible” in that it can contract from a first radially-expanded configuration (e.g., of a particular diameter) to a second radially-contracted conformation (e.g., of a lesser diameter). For example, the rim80may be configured so as to be able to decrease in diameter when the rim80is not radially supported (e.g., held in a radially expanded conformation), for example, by a supporting mechanism. Additionally, in an embodiment, the flexible portion82(e.g., the collet fingers) may be characterized as exhibiting a bias or spring-like behavior. For example, in an embodiment the flexible portion82may be configured so as contract radially (e.g., a radially-inward bias) when not held or retained in a radially expanded configuration.

In an embodiment, the lower portion84may be located below the upper flexible portion82. In an embodiment, the lower portion84of the collet22may be configured to be joined to the lower housing20. For example, in an embodiment, the lower section84of the collet22may comprise an externally threaded surface, for example, to mate with an internally threaded surface of the lower housing20and, thereby, couple the collet22to and/or within the lower housing20. Alternatively, in an embodiment the collet22and the lower housing20may be formed as a single, integrated component.

In an embodiment, the collet22may be configured to house the releasing sleeve24. For example, in the embodiment ofFIGS. 2A, 2B, and 2C, the collet22may comprise a releasing sleeve recess34or a portion thereof. In such an embodiment, the collet22may comprise a first inner bore surface35and a second bore surface36, for example, the first bore surface35having a diameter greater than the diameter to the second bore surface36and being at least partially defined by a shoulder37therebetween. In an embodiment, the releasing sleeve recess34may be generally sized to receive the releasing sleeve24or a portion thereof. For example, the releasing sleeve recess34may be generally sized so as to allow the releasing sleeve24to slide longitudinally therein, as will be disclosed herein.

Additionally, in an embodiment the releasing sleeve recess34may extend (e.g., longitudinally) over at least a portion of the upper housing18. For example, in the embodiment ofFIGS. 2A, 2B, and 2C, the releasing sleeve recess34extends to the upper housing18. In the embodiment ofFIGS. 2A, 2B, and 2C, the upper housing18comprises a bore surface38having a diameter substantially the same as the diameter of the first inner bore surface35and adjacent thereto.

In an embodiment, the releasing sleeve24may comprise a generally cylindrical structure generally defining a concentric bore40which runs along the longitudinal axis of the releasing sleeve24. In an embodiment, the exterior diameter of the releasing sleeve24may be slightly smaller than the inner diameter of the releasing sleeve recess34of the collet22. In an embodiment, the releasing sleeve24may be configured to engage an obturating member of a given size and/or configuration (e.g., a dart, such as the releasing member300, as will be disclosed herein). For example, in the embodiment ofFIGS. 2A, 2B, and 2C, the releasing sleeve24comprises a radially inwardly beveled surface42generally defining a relatively narrowed bore44within the concentric bore40of the releasing sleeve24, for example, at the relatively upper end thereof. In such an embodiment, the narrow bore44generally forms a portion of the concentric bore40.

In an embodiment, the releasing sleeve24may be slidably disposed within the releasing sleeve recess34. For example, in the embodiment ofFIGS. 2A, 2B, and 2C, depending upon the position of the releasing sleeve24, the releasing sleeve24is slidably disposed such that a portion of the releasing sleeve24is disposed against (e.g., interfaces with) a portion of the upper housing and/or such that a portion of the releasing sleeve24is disposed against (e.g., interfaces with) a portion of the collet22. In such an embodiment, the bore40of the releasing sleeve24may be in fluid communication with the concentric bore26(for example, forming a portion of the concentric bore26and/or the lower portion26bthereof).

In an embodiment, the releasing sleeve24may be slidably movable between a first position and a second position. Referring to the embodiment ofFIG. 2A, the releasing sleeve24is illustrated in the first position. In the first position, the releasing sleeve24“radially supports” the collet22(e.g., the rim80and/or flexible portion82of the collet in an expanded conformation), for example, in that the releasing sleeve24prevents the rim80from radially contracting to a relatively smaller diameter. For example, in the first position, the releasing sleeve24retains (e.g., holds) the rim80in the first, radially expanded conformation, for example, thereby prohibiting the upper, flexible portion82of the collet22from flexing inwardly. Also, in the second position, the releasing sleeve24does not radially support the rim80. For example, in the second position, the releasing sleeve24does not retain or otherwise hold the rim80in the first, radially expanded conformation. For example, when the releasing sleeve is in the second position, the rim80is allowed to move inwardly from the first, radially expanded configuration to the second, radially contracted configuration, for example, via the flexing of the upper flexible portion of the collet22.

In an embodiment, the releasing sleeve24may be maintained in the first position by a positioning mechanism, such as a shearing mechanism. For example, in the embodiment ofFIG. 2A, the shearing mechanism comprises a one or more frangible members (e.g., a plurality of radially-spaced frangible members), such as one or more shear pins50which may extend through the releasing sleeve24and the collet22. In an embodiment, the shear mechanism may actuate (e.g., break, shear) upon the application of a predetermined force, for example, which may be applied upon the longitudinal movement of the releasing sleeve24. As will be explained below in relation to the operation of the DCA200, once the one or more shear pins50have sheared (e.g., disabling the positioning mechanism), the releasing sleeve24may be free to slidably move (e.g., downward, along the longitudinal axis28to the second position). In an alternative embodiment, the shearing mechanism may comprise a shearing ring, which may similarly actuate (e.g., break, shear) upon the application of a predetermined force, as will also be disclosed herein. One of ordinary skill in the art, upon viewing this disclosure, will appreciate various, suitable embodiments by which a collet may be held in a particular position.

In an embodiment, the releasing sleeve24may be configured such that one or more of the interfaces between the releasing sleeve24and the collet22and/or between the releasing sleeve24and the upper housing18may be substantially fluid-tight. For example, in an embodiment, the releasing sleeve, the upper housing18, the collet22, or combinations thereof, may comprise a suitable fluid seal at one or more of the interface between the releasing sleeve24and the upper housing18and/or the interface between the releasing sleeve24and the collet22. In the embodiment ofFIGS. 2A, 2B, and 2C, depending upon the position of the releasing sleeve24, a first fluid seal52may be present at the interface between the releasing sleeve24and the upper housing18and a second fluid seal54may be present at the interface between the releasing sleeve24and the collet22. In such an embodiment, the first and second fluid seals,52and54, respectively, may be configured to prohibit fluid communication via the interface between the releasing sleeve24and the upper housing18and the interface between the releasing sleeve24and the collet22, for example, such that fluid is prohibited from escaping from the DCA200(e.g., via the joint between the upper section10aand the lower section10b.

In an embodiment, the upper section10aand the lower section10bmay be selectively coupled. For example, referring toFIG. 2A, the collet22(e.g., of the lower section10b), which is held in the first, radially expanded conformation by the releasing sleeve24(which is in the first, longitudinal position), engages the collet retainer16(e.g., of the upper section10a), for example, so as to retain the lower section10bin relationship to the upper section10a. Particularly, in the embodiment ofFIG. 2A, the outwardly protruding rim80and/or the downward facing shoulder81of the collet22(e.g., the outer profile of the releasing collet22) engage the first inner bore surface64and/or the bevel65of the collet retainer16(e.g., the inner profile of the collet retainer16). In such an embodiment, where the releasing sleeve24is in the first position, as disclosed herein, the releasing collet22may be prohibited from contracting to the radially inward conformation and, as such, may be prohibited from disengaging the collet retainer16, thereby coupling the lower section10bto the upper section10aof the DCA200.

Also, in an embodiment, the upper section10aand the lower section10bmay be configured so as to be selectively decoupled (e.g., uncoupled via the operation of the releasing member, as will be disclosed herein). For example, referring toFIG. 2C, the collet22(e.g., of the lower section10b), which is not held in the first, radially expanded conformation by the releasing sleeve (which is in the second longitudinal position), is allowed to disengage the collet retainer16(e.g., of the lower section10b), for example, so as to allow the lower section10bto be uncoupled from the upper section10a. Particularly, in the embodiment ofFIG. 2C, the outwardly protruding rim80and/or the downward facing shoulder81of the collet22(e.g., the outer profile of the releasing collet22) are allowed to disengage the first inner bore surface64and/or the bevel65of the collet retainer16(e.g., the inner profile of the collet retainer16). In such an embodiment, where the releasing sleeve24is in the second position, as disclosed herein, the releasing collet is allowed to contract (e.g., flex inwardly) to the radially inward conformation and, as such, to disengage the collet retainer16, thereby uncoupling the lower section10bfrom the upper section10aof the DCA200.

In an embodiment, the DCA200may be configured so as to be selectively uncoupled (e.g., the lower section10bfrom the upper section10a, as disclosed herein) via the operation of the releasing member300, as will also be disclosed herein. Referring toFIG. 4, an embodiment of the releasing member300is illustrated. As will be disclosed herein, the releasing member300may be generally configured to be displaced through the axial flowbore126so as to engage the DCA200(or a component thereof) so as to decouple the work string202from the casing string204. In the embodiment ofFIG. 4, the releasing member300generally comprises a releasing dart. In such an embodiment, the releasing member300generally comprises a body310, a tail portion320, and a nose portion330.

In an embodiment, the body310may generally comprise a shaft having a relatively small diameter, for example, in comparison to the tail portion320and/or the nose portion330. In an embodiment, the body310may be configured so as to allow the releasing member300to be displaced through a wellbore tubular, such as the work string202. For example, in an embodiment, the body310may be characterized as exhibiting a desired and/or predetermined degree of flexibility. For example, the body310may be configured so as to be capable of bending or flexing, for example, so as to enable the releasing member300to traverse various bends, curves, or the like, while being displaced through a wellbore tubular.

In an embodiment, the releasing member300may be configured to sealingly and/or substantially sealingly engage an inner wall of a wellbore tubing string, such as, work string202(e.g., while displaced therethrough). For example, in the embodiment ofFIG. 4, the body310of the releasing member300further comprises one or more wipers315. In an embodiment, the wipers315may generally be configured to substantially engage an inner surface of a wellbore tubular. As will be appreciated by one of skill in the art viewing this disclosure, the wipers315may be sized to sealably and slidably engage the inner bore of a wellbore tubular, such as the work string202, of a particular size. The wipers315may be provided in a suitable number and configuration, as will be appreciated by one of skill in the art viewing this disclosure. For example, the embodiment ofFIG. 4illustrates the releasing member300with four wipers, however more or fewer may be provided. The wipers315may extend radially outward from the body310. For example, the wipers315may extend generally outward from the body310at a suitable angle from the body310. For example, in the embodiment of theFIG. 4, each of the four wipers315is angled, thereby forming a downwardly-facing conical structure concentric about the body310. In an embodiment, the wipers315may be formed from a suitable material. Such a suitable material may be characterized as conformable or pliable, for example, such that the wipers315may be able to conform to inconsistencies in the inner bore of the wellbore tubular when displaced therethrough. Examples of suitable materials include but are not limited to rubber, foam, plastics, elastomers, or combinations thereof.

In an embodiment, the tail portion320may generally comprise an upper or relatively uphole portion of the releasing member300(e.g., when the releasing member300is displaced through a wellbore tubular such as the work string202). In an embodiment, the tail portion320may generally be configured to engage the releasing member retainer18within the upper section10aof the DCA200, for example, such that the releasing member300cannot be fully displaced through the DCA200(e.g., prohibited from passing through the releasing member retainer18of the DAC200). For example, in such an embodiment, the tail portion320may be sized such that at a least a portion of the tail portion320comprises a diameter greater than the diameter of the releasing member retainer18(e.g., greater than the diameter of the bore surface18bof the releasing member retainer18). Also, in the embodiment ofFIG. 4, the tail portion320generally comprises a downwardly-facing conical structure321. In such an embodiment, the tail portion320may generally define an outer profile, at least a portion of which may be at least partially complementary to the inner profile defined by the releasing member retainer18(for example, a complementary seat or landing for tail portion320).

In an embodiment, the tail portion320may be configured to allow a route of fluid communication from one side of the tail portion320(e.g., an uphole side) to the other side of the tail portion320(e.g., the downhole side), for example, when the tail portion engages the releasing member retainer18(e.g., when the releasing member300blocks and/or is disposed within the bore18bof the releasing member retainer18). For example, tail portion320may comprise one or more slots (alternatively, grooves, bores, notches, holes, channels, or the like) extending generally longitudinally through the tail portion320. For example, where the releasing member engages the bevel18aand/or bore18bof the releasing member retainer18, fluid may be communicated through such slots, grooves, bores, notches, channels, or the like, which may form a fluidic pathway between the uphole and downhole sides of the tail portion320of the releasing member300, as will be disclosed herein.

In an embodiment, the nose portion330generally comprises a lower or relatively downhole portion of the releasing member300(e.g., when the releasing member300is displaced through a wellbore tubular such as the work string202). In an embodiment, the nose portion330may be generally configured to engage the releasing sleeve24(e.g., to sealingly and/or substantially sealingly engage the releasing sleeve24) within the lower section10bof the DCA200, for example, such that the nose portion330cannot pass through the releasing sleeve24. For example, in such an embodiment, the nose portion330may be sized such that the nose portion330comprises a diameter less than the diameter of the of the releasing member retainer18(e.g., less than the diameter of the bore surface18bof the releasing member retainer18) and also such that the nose portion330(e.g., at least a portion of the nose portion330) comprises a diameter greater than the diameter of the releasing sleeve24(e.g., greater than the diameter of the concentric bore40of the releasing sleeve24. For example, in the embodiment ofFIG. 4, the nose portion330generally comprises a first downwardly-facing conical structure332, an outer bore surface334, and a downwardly-facing shoulder or bevel336. In such an embodiment, the nose portion330may generally define an outer profile, at least a portion of which may be at least partially complementary to the inner profile defined by the releasing sleeve24(e.g., a complementary landing seat for the nose portion330). For example, the outer bore surface334and the downwardly-facing bevel336may be generally complementary to the bevel42and the concentric bore surface40of the releasing sleeve24. Additionally, in an embodiment, the nose portion330and/or the releasing sleeve24may comprise one or more seals, such as O-rings or the lie, generally disposed about at least a portion of the nose portion, for example, so as form a substantially fluid-tight upon engaging the releasing sleeve24, as will be disclosed herein.

One or more embodiments of a connection assembly (such as the DCA200disclosed herein) and/or a connection system (such as the connection system100disclosed herein), one or more embodiments of wellbore servicing methods utilizing such a connection assembly and/or such a connection system will also be disclosed.

In an embodiment, a wellbore servicing method (for example, a wellbore servicing method utilizing the DCA200and/or the connection system100) generally comprises the steps of positioning a wellbore tubing string (particularly, a first wellbore tubing string selectively suspended from a second wellbore tubing string via the DCA200) within a wellbore (such as the wellbore114), selectively disconnecting the first wellbore tubing string from the second wellbore tubing string, and removing the second wellbore tubing string from the wellbore114. As will be disclosed herein, upon removal of the second wellbore tubing string from the wellbore114, the first wellbore tubing string will remain in the wellbore and be substantially free of obstructions to flow therethrough. As will also be disclosed herein, as the second wellbore tubing string is removed from the wellbore, fluid within the second wellbore tubing string may be substantially drained therefrom. Additionally, in an embodiment the wellbore servicing method may further comprise allowing a fluid to be produced from the subterranean formation via the first wellbore tubing string.

In an embodiment, a wellbore tubing string, for example, comprising a first wellbore tubing string selectively suspended from a second wellbore tubing string via the DCA200. For example, in the embodiment ofFIG. 1, a wellbore tubing string comprises a casing string (e.g., the casing string204) selectively and releasably suspended from a work string (e.g., the work string202). The work string202and the casing string204may be run into the wellbore114to a predetermined or desired depth, for example, such that the casing string204is positioned at a predetermined location (e.g., proximate and/or adjacent to one or more formation zones) within the wellbore114. In an embodiment, a wellbore servicing tool (e.g., a stimulation tool) may be incorporated within the first wellbore tubing string (e.g., within the casing string204). In such an embodiment, the wellbore tubing string(s) may be positioned such that the wellbore servicing tool is positioned at a predetermined location (e.g., proximate and/or adjacent to one or more formation zones).

In an embodiment, a fluid may be communicated through the wellbore tubing string(s) (e.g., forward-circulated, reverse-circulated, or combinations thereof) during the placement of the tubing string(s) within the wellbore114and/or to treat (e.g., stimulate) the wellbore/formation during and/or following placement.

In an embodiment, the first wellbore tubing string (e.g., the casing string204) may be disconnected from the second wellbore tubing string (e.g., the work string202), for example, after positioning the casing string204, as disclosed herein. In an embodiment, disconnecting the casing string204from the work string202may generally comprise introducing a releasing member (such as the releasing member300disclosed herein) into the wellbore tubing string (e.g., the work string202). For example, referring toFIG. 1, the releasing member300(e.g., a releasing dart) may be introduced into the work string202(the nose portion330first, followed by the tail portion320). In an embodiment, the releasing member300may be released from the surface via the operation of a dart releasing assembly or the like; alternatively, the releasing member300may be released from a subsurface location.

In an embodiment, disconnecting the casing string204from the work string202may further comprise communicating the releasing member300through the work string202(e.g., pumping the dart downhole), for example, so as to engage the releasing sleeve24within the DCA200, for example, as shown inFIG. 2B. For example, in an embodiment, the wipers315of the releasing member300may substantially sealingly engage the interior walls of the work string202, for example, such that the downward circulation of fluid through via the axial flowbore126causes the releasing member300to move downwardly through the work string202. In an embodiment, the releasing member300will be communicated through the work string to the DCA200. Upon reaching the DCA200, the nose portion330and the wipers315of the releasing member300will be transmitted through the releasing member retainer18(e.g., the nose portion330of the releasing member300may comprise an outermost diameter that is smaller than the diameter of the bore surface18bof the releasing member retainer18; likewise, the wipers may be generally flexible and, as such, will not inhibit the downward movement of the releasing member300). The releasing member300may continue to move downwardly until the nose portion330of the releasing member300reaches and engages the releasing sleeve24. For example, in such an embodiment, the nose portion330may sealingly engage the releasing sleeve24(e.g., the outer bore surface334and the downwardly-facing bevel336of the nose portion330may be generally complementary to the bevel42and the concentric bore surface40of the releasing sleeve24, as disclosed herein). In an embodiment, DCA200and/or releasing member300may be configured such that the nose portion330reaches and engages the releasing sleeve24before the tail portion reaches and/or engages the releasing member retainer18, as will be disclosed herein.

In an embodiment, disconnecting the casing string204from the work string202may further comprise applying a force to the releasing sleeve24via the releasing member300. For example, with the releasing member300engaged (e.g., sealingly engaged) with the releasing sleeve24, as disclosed herein, the application of force to the releasing member, for example, a hydraulic force, via a pressure exerted against the releasing member300, may transmit a force to the releasing sleeve24. Particularly, in such an embodiment, the application of such a force via the releasing member300may transmit a force to the releasing sleeve24in the direction of the second position. For example, such a force may cause the releasing sleeve24to exert a force against the shear pins50, causing the shear pins50to fail (e.g., shear, break, sever, or otherwise cease to retain the releasing sleeve24in the first position). In an embodiment, continued application of such force to the releasing member300may cause the releasing sleeve24may continue to move in the direction of the second position (e.g., downward) until reaching the second position, for example, until the releasing sleeve24(e.g., a lower shoulder48of the releasing sleeve24) engages the shoulder37of the collet, thereby restraining the releasing sleeve24from further, downward movement. In an embodiment, the DCA200and/or releasing member300may be configured such that the releasing sleeve24reaches the second position, as disclosed herein, before the tail portion reaches and/or engages the releasing member retainer18, as will be disclosed herein.

With the releasing sleeve24in the second longitudinal position, the collet22(e.g., the rim80of the collet22) is not retained/held in the first radially expanded conformation. For example, upon transitioning the releasing sleeve24from the first longitudinal position to the second longitudinal position, the collet22(e.g., the rim80of the collet22) may be allowed to the contract into the second, radially inward conformation, for example, such that the collet22is allowed to disengage the collet retainer16. Particularly, as shown in the embodiment ofFIG. 2C, the outwardly protruding rim80and/or the downward facing shoulder81of the collet22(e.g., the outer profile of the releasing collet22) are allowed to disengage the first inner bore surface64and/or the bevel65of the collet retainer16(e.g., the inner profile of the collet retainer16).

In an embodiment, for example, in an embodiment where the collet22(e.g., the plurality of collet fingers) is inwardly-biased, upon the movement of the releasing sleeve24from the first longitudinal position to the second longitudinal position, the collet22may contract into the second, radially inward conformation. Additionally or alternatively, in an embodiment, the collet22may contract radially inward upon the application of a longitudinal force to the DCA200, for example, upon removing the second wellbore tubing string from the wellbore as will be disclosed herein. For example, as disclosed herein, in an embodiment the downward facing shoulder81of the collet22and/or the bevel65of the collet retainer16may comprise angled/beveled surfaces such that the application of a longitudinal, tensile force (e.g., a force pulling the upper section10aand the lower section10bin opposite directions) the interaction between the downward facing shoulder81and the bevel65may cause the collet22(e.g., the plurality of collet fingers) to flex inwardly to the second, radially inward conformation. As such, the outwardly protruding rim80and/or the downward facing shoulder81of the collet22(e.g., the outer profile of the releasing collet22) are allowed to disengage the first inner bore surface64and/or the bevel65of the collet retainer16(e.g., the inner profile of the collet retainer16), thereby allowing the lower section10bof the DCA200to be disconnected from the upper section10athereof.

In an embodiment, upon disconnecting the lower section10bfrom the upper section10aand/or readying the lower section10bto be disconnected from the upper section10a(e.g., upon the application of a longitudinal, tensile force, as disclosed herein), the second wellbore tubing string (e.g., the work string202) may be removed from the wellbore114. In such an embodiment, removing the work string202from the wellbore114may generally comprising retracting the work string202toward the surface104(e.g., “running out” the work string202) while the first wellbore tubing string (e.g., the casing string204) remains positioned within the wellbore114.

In an embodiment as shown inFIG. 2C, as the work string202is retracted (pulled upwardly) away from the casing string204, the releasing member300, particularly, the tail portion320of the releasing member300, may engage the releasing member retainer18. For example, the as the work string202(and upper section10a) is pulled away from the casing string204(and lower section10b), the, downward facing conical structure321of the tail portion320may engage the upper, conical bevel18aof the releasing member retainer18. As disclosed herein, the tail portion320is generally configured so as to engage the releasing member retainer18, for example, such that the releasing member300cannot be fully displaced through the releasing member retainer18. As such, in an embodiment, as the work string202is retracted (e.g., pulled upwardly), the engagement between the tail portion320and the releasing member retainer18pulls the releasing member300upwardly along with the work string202, for example, thereby separating or disengaging the nose portion330of the releasing member from the releasing sleeve24. As the work string202is pulled further up-hole away from the casing string204, the releasing member300may also be pulled up-hole with the work string202. As such, upon removing (e.g., fully or partially, upwardly retracting) the work string202, the releasing member300will be removed from the lower section10bof the DCA200, for example, so that the releasing member300(nor any portion thereof) blocks, obscures, or remains within any portion of the lower section10b. As such, upon removing and/or retracting the work string202, the lower portion of the axial flow bore26bis unobstructed by the releasing member300(or any other, like obturating member associated with the operation of the DCA200).

Additionally, in an embodiment, as the work string202is removed from the wellbore114, the DCA200and/or the releasing member300may be configured so as to allow fluid within the axial flowbore126of the work string to be drained therefrom. For example, in an embodiment as disclosed herein, the releasing member retainer18and/or the tail portion320of the releasing member300may comprise one or more slots, grooves, bores, notches, holes, channels, or the like (e.g., slots18c) that allow fluid to pass from the uphole to the downhole side of the releasing member retainer18and out of the work string202, for example, even though the releasing member300engages the releasing member retainer18within the upper portion10aof the DCA200(which is coupled to the lower-most end of the work string202). As such, fluid may be drained from the work string202during run-out of the work string202and the upper section10aof the DCA200.

In an embodiment, a DCA (like DCA200), a system utilizing such a DCA, and/or a method utilizing such a DCA may be advantageously employed in the performance of a wellbore servicing operation. For example, as disclosed herein, the DCA allows for an operator to dispose a first wellbore tubular within a wellbore (e.g., such as a horizontal wellbore portion, for example, penetrating a coal seam) and decouple the first wellbore tubular from a second wellbore tubular. Particularly, the DCA allows for the first wellbore tubular (e.g., which is disposed within the wellbore) to be open-ended and/or unobstructed (for example, by a dart or a plug), thereby providing a flow path for fluids (e.g., for production of a formation fluid). For example, utilizing such a DCA, a perforated tubing string may be disposed within a wellbore to prevent collapse of the wellbore while providing a relatively unobstructed flow path for gas production (e.g., coal bed method). Additionally, the DCA allows an operator to decouple the two wellbore tubulars without the need for utilizing conventional liner hanger disconnect tools and/or without the need for drilling-out the wellbore tubular that remains in the wellbore, for example, decreasing the time associated with such operations.

Further still, a DCA as disclosed herein allows for fluid to be drained out of the disconnected end of the second wellbore tubular (such as the work string, as disclosed herein) as the second wellbore tubular is removed from the wellbore. As a result, because fluid is drained prior to being disconnected at the surface (e.g., during run-out), workers may benefit from a safer working environment due to the absence of such fluids and/or associated pressures in the work area. Additionally, this allows run-out to take place more quickly and efficiently.

ADDITIONAL DESCRIPTION OF THE EMBODIMENTS

A first embodiment, which is a wellbore servicing method comprising:

positioning a wellbore tubing string within a wellbore, wherein the wellbore tubing string comprises a lower wellbore tubular coupled to an upper wellbore tubular via a disconnectable assembly having a lower section connected to the lower wellbore tubular and an upper section connected to the upper wellbore tubular;

disconnecting the lower wellbore tubular from the upper wellbore tubular via the disconnectable assembly, wherein disconnecting the lower wellbore tubular from the upper wellbore tubular comprises:introducing a releasing member into the upper wellbore tubular; andconveying the releasing member through the upper wellbore tubular to engage the disconnectable assembly; and

retracting the upper wellbore tubular upwardly within the wellbore, wherein upon retracting the upper wellbore tubular, the releasing member is retracted along with the upper section of the disconnectable assembly, and wherein upon retracting the upper wellbore tubular, a route of fluid communication out of the upper wellbore tubular is provided.

A second embodiment, which is the wellbore servicing method of the first embodiment, wherein the upper section of the disconnectable assembly comprises a collet retainer, and wherein the lower section of the disconnectable assembly comprises a collet and a releasing sleeve.

A third embodiment, which is the wellbore servicing method of one of the first through second embodiments, wherein conveying the releasing member through the upper wellbore tubular to engage the disconnectable assembly comprises conveying the releasing member through the upper wellbore tubular to engage the releasing sleeve.

A fourth embodiment, which is the wellbore servicing method of the third embodiment, further comprising applying a force to the releasing sleeve via the releasing member so as to transition the releasing sleeve from a first position to a second position.

A fifth embodiment, which is the wellbore servicing method of the fourth embodiment, wherein transitioning the releasing sleeve from the first position to the second position allows at least a portion of the collet to contract radially inward.

A sixth embodiment, which is the wellbore servicing method of the fifth embodiment, wherein contracting radially inward allows the collet to disengage the collet retainer.

A seventh embodiment, which is the wellbore servicing method of one of the first through sixth embodiments, wherein upon retracting the upper wellbore tubular, a tail portion of the releasing member engages a releasing member retainer within the upper section of the disconnectable assembly.

An eighth embodiment, which is the wellbore servicing method of the seventh embodiment, wherein the releasing member retainer comprises a seat engaging the tail portion of the releasing member.

A ninth embodiment, which is the wellbore servicing method of one of the seventh through eighth embodiments, wherein the releasing member retainer, the tail portion of the releasing member, or combinations thereof comprises a route of fluid communication therethrough.

A tenth embodiment, which is a wellbore connection system comprising:

a first wellbore tubular;

a second wellbore tubular;

a disconnectable assembly comprising:

a lower section, wherein the upper section is coupled to the first wellbore tubular; and

an upper section, wherein the upper section is coupled to the second wellbore tubular, and wherein the lower section is selectively, disconnectably coupled to the upper section;

a releasing member configured to uncouple the lower section from the upper section, wherein the disconnectable assembly and/or the releasing member is configured such that upon uncoupling the lower section from the upper section, the releasing member is at least partially retained by the upper section, and wherein the disconnectable assembly and/or the releasing member is configured so as to provide a route of fluid communication upon uncoupling the lower section from the upper section.

An eleventh embodiment, which is the wellbore connection system of the tenth embodiment, wherein the upper section of the disconnectable assembly comprises a collet retainer, and wherein the lower section of the disconnectable assembly comprises a collet and a releasing sleeve.

A twelfth embodiment, which is the wellbore connection system of the eleventh embodiment, wherein disconnectable assembly is configured such that:

in a first position, the releasing sleeve retains the collet in a radially expanded conformation, and

in a second position, the releasing sleeve allows the collet to contract into a radially contracted conformation.

A thirteenth embodiment, which is the wellbore servicing system of the twelfth embodiment,

wherein, in the radially expanded conformation, the collet engages the collet retainer, and

wherein, in the radially contracted conformation, the collet releases the collet retainer.

A fourteenth embodiment, which is the wellbore servicing system of one of the tenth through thirteenth embodiments, wherein the upper section of the disconnectable assembly comprises a releasing member retainer, wherein the releasing member retainer allows a nose portion and a body of the releasing member to pass therethrough and retains a tail portion of the releasing member.

A fifteenth embodiment, which is the wellbore servicing system of one of the tenth through fourteenth embodiments, wherein the first wellbore tubular comprises a casing string.

A sixteenth embodiment, which is the wellbore servicing system of the fifteenth embodiment, wherein the casing string is perforated.

A seventeenth embodiment, which is the wellbore servicing system of one of the tenth through sixteenth embodiments, wherein the second wellbore tubular comprises a work string.

An eighteenth embodiment, which is a wellbore connection system comprising:

a first wellbore tubular, the first wellbore tubular disposed in an upper portion of a wellbore;

a lower section of a dissconnectable assembly, wherein the lower section is coupled to the first wellbore tubular; and

a second wellbore tubular, the second wellbore tubular disposed in an upper portion of the wellbore;

an upper section of the disconnectable assembly, wherein the upper section is coupled to the second wellbore tubular; and

a releasing member, wherein the releasing member is at least partially retained by the upper section of the disconnectable assembly.

A nineteenth embodiment, which is the wellbore connection system of the eighteenth embodiment, wherein the upper section of the disconnectable assembly comprises a collet retainer, and wherein the lower section of the disconnectable assembly comprises a collet and a releasing sleeve.

A twentieth embodiment, which is the wellbore connection system of the nineteenth embodiment, wherein disconnectable assembly is selectively configurable from:

a first position, wherein the releasing sleeve retains the collet in a radially expanded conformation, and

a second position, wherein the releasing sleeve allows the collet to contract into a radially contracted conformation.

A twenty-first embodiment, which is the wellbore connection system of the twentieth embodiment,

wherein, in the radially expanded conformation, the collet engages the collet retainer, and

wherein, in the radially contracted conformation, the collet releases the collet retainer.

A twenty-second embodiment, which is the wellbore connection system of one of the eighteenth through twenty-first embodiments, wherein the upper section of the disconnectable assembly comprises a releasing member retainer, wherein the releasing member retainer allows a nose portion and a body of the releasing member to pass therethrough and retains a tail portion of the releasing member.