Patent Publication Number: US-8991486-B2

Title: Remotely activated down hole systems and methods

Description:
BACKGROUND 
     The present invention relates to systems and methods used in down hole applications. More particularly the present invention relates to the remote setting of a down hole tool in various down hole applications. 
     In the course of treating and preparing a subterranean well for production, down hole tools, such as well packers, are commonly run into the well on a tubular conveyance such as a work string, casing string, or production tubing. The purpose of the well packer is not only to support the production tubing and other completion equipment, such as sand control assemblies adjacent to a producing formation, but also to seal the annulus between the outside of the tubular conveyance and the inside of the well casing or the wellbore itself. As a result, the movement of fluids through the annulus and past the deployed location of the packer is substantially prevented. 
     Some well packers are designed to be set using complex electronics that often fail or may otherwise malfunction in the presence of corrosive and/or severe down hole environments. Other well packers require that the ambient conditions in the well be significantly altered in order to obtain adequate hydrostatic pressures to properly set the packer. While reliable in some applications, these and other methods of setting well packers add additional and unnecessary complexity and cost to the pack off process. 
     SUMMARY OF THE INVENTION 
     The present invention relates to systems and methods used in down hole applications. More particularly the present invention relates to the remote setting of a down hole tool in various down hole applications. 
     In some aspects of the disclosure, a system is disclosed. The system may include a base pipe having an inner radial surface and an outer radial surface and defining one or more pressure ports extending between the inner and outer radial surfaces. The system may also include an internal sleeve arranged against the inner radial surface of the base pipe and slidable between a closed position, where the internal sleeve covers the one or more pressure ports, and an open position, where the one or more pressure ports are exposed to an interior of the base pipe. The system further includes a trigger housing disposed about the outer radial surface of the base pipe and defining an atmospheric chamber in fluid communication with the one or more pressure ports, and a piston port cover disposed within the atmospheric chamber and moveable between a blocking position and an exposed position. The system may also include a wellbore device configured to engage and move the internal sleeve into the open position by applying a predetermined axial force to the internal sleeve. 
     In other aspects of the disclosure, a trigger mechanism for setting a down hole tool disposed about a base pipe is disclosed. The trigger mechanism may include an internal sleeve arranged within the base pipe and slidable between a closed position and an open position. The base pipe may define one or more pressure ports. The trigger mechanism may also include a trigger housing disposed about the base pipe and defining an atmospheric chamber in fluid communication with the one or more pressure ports. The trigger mechanism may further include a piston port cover disposed within the atmospheric chamber and moveable between a blocking position, where the piston port cover occludes a hydrostatic conduit in fluid communication with a hydrostatic chamber, and an exposed position, where the hydrostatic conduit is exposed and provides fluid communication between the hydrostatic chamber and the atmospheric chamber. 
     In yet other aspects of the disclosure, a method for remotely setting a down hole tool disposed about a base pipe is disclosed. The method may include engaging an internal sleeve arranged within the base pipe with a wellbore device. The internal sleeve may be slidable between a closed position and an open position, and the base pipe may define one or more pressure ports. The method may also include applying a predetermined axial force on the internal sleeve with the wellbore device in order to move the internal sleeve into the open position and thereby expose the one or more holes to an interior of the base pipe, and allowing an influx of fluid from the interior of the base pipe into an atmospheric chamber via the one or more holes. The atmospheric chamber may be defined by a trigger housing disposed about the base pipe. The method may further include moving a piston port cover arranged within the atmospheric chamber from a blocking position into an exposed position using the influx of fluid. In the exposed position, a hydrostatic conduit may be exposed and provide fluid communication between the atmospheric chamber and a hydrostatic chamber. The method may also include allowing an influx of wellbore fluids into the hydrostatic chamber to move a hydrostatic piston arranged within the hydrostatic chamber. The hydrostatic piston may be configured to set the down hole tool. 
     The features and advantages of the present invention will be readily apparent to those skilled in the art upon a reading of the description of the preferred embodiments that follows. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The following figures are included to illustrate certain aspects of the present invention, and should not be viewed as exclusive embodiments. The subject matter disclosed is capable of considerable modification, alteration, and equivalents in form and function, as will occur to those skilled in the art and having the benefit of this disclosure. 
         FIG. 1  illustrates a cross-sectional view of a portion of a base pipe and accompanying trigger mechanism, according to one or more embodiments disclosed. 
         FIG. 2  illustrates an enlarged view of the trigger mechanism shown in  FIG. 1 , according to one or more embodiments disclosed. 
         FIG. 3  illustrates a stage of activation of the trigger mechanism, according to one or more embodiments disclosed. 
         FIG. 4  illustrates another stage of activation of the trigger mechanism, according to one or more embodiments disclosed. 
         FIG. 5  illustrates yet another stage of activation of the trigger mechanism, according to one or more embodiments disclosed. 
     
    
    
     DETAILED DESCRIPTION 
     The present invention relates to systems and methods used in down hole applications. More particularly the present invention relates to the remote setting of a down hole tool in various down hole applications. 
     As will be discussed in detail below, several advantages are gained through the systems and methods disclosed herein. For example, the disclosed systems and methods initiate and set a down hole tool, such as a well packer, in order to isolate the annular space defined between a wellbore and a base pipe (e.g., production string), thereby helping to prevent the migration of fluids through a cement column and to the surface. The down hole tool is mechanically-set without the use of electronics or signaling means. Rather, the down hole tool takes advantage of the hydrostatic pressure differential between the ambient environment surrounding the tool itself and within the base pipe. Consequently, the disclosed systems and methods simplify the setting process and reduce potential problems that would otherwise prevent the packer or down hole tool from setting. To facilitate a better understanding of the present invention, the following examples are given. It should be noted that the examples provided are not to be read as limiting or defining the scope of the invention. 
     Referring to  FIG. 1 , illustrated is a cross-sectional view of an exemplary system  100 , according to one or more embodiments. The system  100  may include a base pipe  102  extending within a wellbore  104  that has been drilled into the Earth&#39;s surface to penetrate various earth strata containing, for example, hydrocarbon formations. It will be appreciated that the system  100  is not limited to any specific type of well, but may be used in all types, such as vertical wells, horizontal wells, multilateral (e.g., slanted) wells, combinations thereof, and the like. A casing  106  may be disposed within the wellbore  104  and thereby define an annulus  108  between the casing  106  and the base pipe  102 . The casing  106  forms a protective lining within the wellbore  104  and may be made from materials such as metals, plastics, composites, or the like. In some embodiments, the casing  106  may be expanded or unexpanded as part of an installation procedure and/or may be segmented or continuous. In at least one embodiment, the casing  106  may be omitted and the annulus  108  may instead be defined between the inner wall of the wellbore  104  and the base pipe  102 . 
     The base pipe  102  may include one or more tubular joints, having metal-to-metal threaded connections or otherwise threadedly joined to form a tubing string. In other embodiments, the base pipe  102  may form a portion of a coiled tubing. The base pipe  102  may have a generally tubular shape, with an inner radial surface  102   a  and an outer radial surface  102   b  having substantially concentric and circular cross-sections. However, other configurations may be suitable, depending on particular conditions and circumstances. For example, some configurations of the base pipe  102  may include offset bores, sidepockets, etc. The base pipe  102  may include portions formed of a non-uniform construction, for example, a joint of tubing having compartments, cavities or other components therein or thereon. Moreover, the base pipe  102  may be formed of various components, including, but not limited to, a joint of casing, a coupling, a lower shoe, a crossover component, or any other component known to those skilled in the art. In some embodiments, various elements may be joined via metal-to-metal threaded connections, welded, or otherwise joined to form the base pipe  102 . When formed from casing threads with metal-to-metal seals, the base pipe  102  may omit elastomeric or other materials subject to aging, and/or attack by environmental chemicals or conditions. 
     The system  100  may further include at least one down hole tool  110  coupled to or otherwise disposed about the base pipe  102 . In some embodiments, the down hole tool  110  may be a well packer. In other embodiments, however, the down hole tool  110  may be a casing annulus isolation tool, a stage cementing tool, a multistage tool, formation packer shoes or collars, combinations thereof, or any other down hole tool. As the base pipe  102  is run into the well, the system  100  may be adapted to substantially isolate the down hole tool  110  from any fluid actions from within the casing  106 , thereby effectively isolating the down hole tool  110  so that circulation within the annulus  108  is maintained until the down hole tool  110  is properly actuated. 
     In one or more embodiments, the down hole tool  110  may include a standard compression-set element that expands radially outward when subjected to compression. Alternatively, the down hole tool  110  may include a compressible slip on a swellable element, a compression-set element that partially collapses, a ramped element, a cup-type element, a chevron-type seal, one or more inflatable elements, an epoxy or gel squirted into the annulus  108 , combinations thereof, or other sealing elements. 
     The down hole tool  110  may be disposed about the base pipe  102  in a number of ways. For example, in some embodiments the down hole tool  110  may directly or indirectly contact the outer radial surface  102   b  of the base pipe  102 . In other embodiments, however, the down hole tool  110  may be arranged about or otherwise radially-offset from another component of the base pipe  102 . For example, the system  100  may include a hydrostatic piston  112  arranged external to the base pipe  102 . As illustrated, the hydrostatic piston  112  may include a piston portion  112   a  housed within a hydrostatic chamber  114  and a stem portion  112   b  that extends axially from the piston portion  112   a  and interposes the down hole tool  110  and the base pipe  102 . In one or more embodiments, the hydrostatic piston  112  provides the required energy to properly set the down hole tool  110 . 
     The hydrostatic chamber  114  may be at least partially defined by a ramped retainer element  116  arranged about the base pipe  102  adjacent a first axial end  110   a  of the down hole tool  110 . One or more inlet ports  120  may be defined in the ramped retainer element  116  and provide fluid communication between the annulus  108  and the hydrostatic chamber  114 . The stem portion  112   b  may be coupled to a compression sleeve  118  arranged adjacent to, and potentially in contact with, a second axial end  110   b  of the down hole tool  110 . 
     The hydrostatic chamber  114  contains fluid under hydrostatic pressure from the annulus  108 , and the hydrostatic piston  112  remains in fluid equilibrium until a pressure differential is experienced across the piston portion  112   a . In one embodiment, the pressure differential experienced across the piston portion  112   a  forces the hydrostatic piston  112  to axially translate in a direction A within the hydrostatic chamber  114  as it seeks pressure equilibrium once again. As the hydrostatic piston  112  translates in direction A, the compression sleeve  118  coupled to the stem portion  112   b  is forced up against the second axial end  110   a  of the down hole tool  110 , thereby compressing and radially expanding the down hole tool  110 . As the down hole tool  110  expands radially, it may engage the wall of the casing  106  and effectively isolate portions of the annulus  108  above and below the down hole tool  110 . 
     The system  100  may also include a trigger mechanism  122 . In some embodiments, the trigger mechanism  122  may be activated or otherwise actuated in order to realize a pressure differential sufficient to translate the hydrostatic piston  112 , and thereby cause the down hole tool  110  to set. Among other components described below, the trigger mechanism  122  may include an internal sleeve  124 , a piston port cover  126 , and a trigger housing  128 . The internal sleeve  124  may be disposed against the inner radial surface  102   a  of the base pipe  102  and secured thereto using one or more pins  130  spaced circumferentially about the inner radial surface  102   a . Although three pins  130  are shown in  FIG. 1 , it will be appreciated that any number of pins  130  may be used without departing from the scope of the disclosure. In some embodiments, the pins  130  may be omitted and instead replaced with a shear ring (not shown) that serves substantially the same purpose in securing the internal sleeve  124  to the base pipe  102 . 
     Referring to  FIG. 2 , with continued reference to  FIG. 1 , illustrated is an enlarged view of the trigger mechanism  122 , according to one or more embodiments. As illustrated, the pins  130  may extend through concentric and corresponding holes  132  defined in the internal sleeve  124  and holes  134  defined in the base pipe  102 . In some embodiments, the pins  130  are threaded into either or each of the base pipe  102  and/or the internal sleeve  124 . In other embodiments, the pins  130  are attached to either or each of the base pipe  102  and/or the internal sleeve  124  by welding, brazing, adhesives, combinations thereof, or other attachment means. One or more sealing components  136  may be arranged between the internal sleeve  124  and the inner radial surface  102   a  of the base pipe  102  in order to provide a fluid-tight seal therebetween. In some embodiments, the sealing components  136  may be o-rings. In other embodiments, the sealing components  136  may be other types of seals known to those skilled in the art. 
     In response to a predetermined axial force applied to the internal sleeve  124  in the direction A, the pins  130  may be configured to shear such that the internal sleeve  124  is able to translate along the inner radial surface  102   a  of the base pipe  102 . Specifically, the internal sleeve  124  may be slidable between a closed position, where the internal sleeve  124  effectively covers one or more pressure ports  138  defined in the base pipe  102 , and an open position, where the one or more pressure ports  132  are uncovered or otherwise exposed to the interior of the base pipe  102 . For example,  FIGS. 1-3  show the internal sleeve  124  in its closed position, and  FIGS. 4 and 5  show the internal sleeve  124  in its open position. 
     The trigger housing  128  may be disposed about the outer radial surface  102   b  of the base pipe  102  and have a first end  128   a  and a second end  128   b . In conjunction with the base pipe  102 , the trigger housing  128  at least partially defines an atmospheric chamber  140 . At the first end  128   a , the trigger housing  128  may be coupled to a hydraulic pressure transmission coupling  142 . At its second end  128   b , the trigger housing  128  may either directly or indirectly engage the outer radial surface  102   b  of the base pipe  102 . At least one sealing component  144 , such as an o-ring or the like, may be used to seal the connection between the first end  128   a  and the hydraulic pressure transmission coupling  142 . Likewise, one or more sealing components  146  (two shown), such as o-rings or the like, may be used to seal the engagement between the second end  128   b  and the base pipe  102 . 
     In at least one embodiment, the first end  128   a  is threaded onto the hydraulic pressure transmission coupling  142 . In other embodiments, however, the first end  128   a  may be coupled to the hydraulic pressure transmission coupling  142  using, for example, mechanical fasteners or the like. The opposing end of the hydraulic pressure transmission coupling  142 , as shown in  FIG. 1 , may be coupled, either threadedly or via mechanical fasteners, to the ramped retainer element  116 . In some embodiments, the hydraulic pressure transmission coupling  142  may define a hydrostatic conduit  148  that provides fluid communication between the hydrostatic chamber  114  and the atmospheric chamber  140 . The hydrostatic conduit  148  may be rifle-drilled directly into the hydraulic pressure transmission coupling  142 . In other embodiments, however, the hydrostatic conduit  148  may be defined external to the hydraulic pressure transmission coupling  142 , such as an external conduit adapted to connect the hydrostatic chamber  114  to the atmospheric chamber  140 . 
     Before the trigger mechanism  122  is actuated, the atmospheric chamber  140  may be filled with a fluid generally at atmospheric pressure. For example, the atmospheric chamber  140  may be filled with air. In other embodiments, however, the atmospheric chamber  140  may be filled with other fluids such as, but not limited to, hydraulic fluid, water, oil, combinations thereof, or the like. 
     Still referring to  FIG. 2 , the piston port cover  126  may be disposed about the base pipe  102  and arranged within the atmospheric chamber  140 . The piston port cover  126  may be made of aluminum, composite, steel, combinations thereof, or other rigid materials. In one embodiment, the piston port cover  126  may include a piston portion  126   a  and a sleeve portion  126   b  extending axially from the piston portion  126   a . The piston port cover  126  may be movable within the atmospheric chamber  140  between a first, blocking position and a second, exposed position. Examples of the piston port cover  126  in the blocking position can be seen in  FIGS. 1-4 , and an example of the piston port cover  126  in its exposed position can be seen in  FIG. 5 . 
     In the blocking position, the sleeve portion  126   b  of the piston port cover  126  may substantially interpose portions of the hydraulic pressure transmission coupling  142  and the trigger housing  128 . Moreover, in the blocking position, the sleeve portion  126   b  may substantially block or otherwise occlude the hydrostatic conduit  148  such that fluid communication between the hydrostatic chamber  114  and the atmospheric chamber  140  is substantially prevented. One or more sealing components  150 , such as o-rings or the like, may be disposed between the hydraulic pressure transmission coupling  142  and the sleeve portion  126   b , such that fluid leakage between the hydrostatic chamber  114  and the atmospheric chamber  140  is substantially prevented while the piston port cover  126  is in its blocking position. 
     In the exposed position, the piston port cover  126  may be shifted axially in direction A such that the sleeve portion  126   b  no longer blocks the hydrostatic conduit  148 , thereby exposing the hydrostatic conduit  148  to the atmospheric chamber  140 . As a result, fluid communication between the hydrostatic chamber  114  and the atmospheric chamber  140  may occur. 
     Referring now to  FIGS. 3-5 , with continued reference to  FIGS. 1 and 2 , illustrated are various stages of exemplary operation of the system  100 , according to one or more embodiments. Specifically,  FIGS. 3-5  illustrate the trigger mechanism  122  as it may be activated or actuated and thereby cause the down hole tool  110  ( FIG. 1 ) to set. In  FIG. 3 , for example, illustrated is a wellbore device  152  that may be introduced or otherwise dropped down the well, within the base pipe  102 , and configured to engage and move the internal sleeve  124 . In at least one embodiment, the wellbore device  152  is a plug, as known by those skilled in the art. In other embodiments, however, the wellbore device  152  may be another type of down hole device such as, but not limited to, a ball or a dart. The wellbore device  152  may be made of, for example, aluminum, composite, rubber, combinations thereof, or the like. 
     In some embodiments, the wellbore device  152  may be configured to engage an upper end  154  of the internal sleeve  124 . In  FIG. 3 , for example, the wellbore device  152  is biased against a seat  156  defined at the upper end  154  of the internal sleeve  124 . In other embodiments, however, the wellbore device  152  may be configured to engage any portion of the internal sleeve  124 . Likewise, any portion of the wellbore device  152  may be adapted to engage any corresponding portion of the internal sleeve  124 , without departing from the scope of the disclosure. In yet other embodiments, the internal sleeve  124  may be hydraulically-operated, where a plug or similar device (not shown) is landed below the internal sleeve  124  and configured to shut off further fluid flow therebelow, and thereby allowing a pressure increase sufficient to cause the internal sleeve  124  to shift to an open position. Such an embodiment would be somewhat similar in design to the Type HES cementer opening seat, available through Halliburton Energy Services, Houston, Tex. 
     Referring to  FIG. 4 , illustrated is the trigger mechanism  122  showing the internal sleeve  124  moved into its open position. In order to move the internal sleeve  124  within the base pipe  102 , the pins  130  must be sheared or otherwise removed from engagement with the base pipe  102 . In some embodiments, the wellbore device  152  may be configured to apply a predetermined axial force to the internal sleeve  124  such that the pins  130  are sheared and the internal sleeve  124  is thereafter able to translate axially. As can be appreciated, the size and number of the pins  130  will define what magnitude of axial force is required to shear the pins  130  in order to move the internal sleeve  124 . Accordingly, upon design of the system  100 , the size and number of the pins  130  may be taken into account and thereby provide a user with the predetermined axial force necessary to shear the pins  130  and thereby move the internal sleeve  124  into its open position. 
     In some embodiments, the predetermined axial force may be applied to the internal sleeve  124  by increasing the fluid pressure in the base pipe  102 . For instance, the wellbore device  152  may have an outer circumference  158  adapted to engage or otherwise substantially seal against the inner radial surface  102   a  of the base pipe  102 . A fluid may be pumped from the surface and into the base pipe  102  such that the wellbore device  152  is forced against the internal sleeve  124 . By increasing the pressure of the fluid within the base pipe  102 , the axial force applied by the wellbore device  152  on the internal sleeve  124  correspondingly increases. Further increasing the pressure of the fluid within the base pipe  102  may achieve the predetermined axial force required to shear the pins  130  and thereby move the internal sleeve  124  into its open position. In other embodiments, however, the predetermined axial force may be applied to the internal sleeve  124  in other ways, such as a mechanical force applied to the wellbore device  152  and which transfers its force to the internal sleeve  124 . In yet other embodiments, the internal sleeve  124  may be hydraulically-actuated, as discussed above. In yet further embodiments, a workstring or the like may be lowered into the well with an end adapted to fit into or otherwise engage the seat, whereby weight slacked off from above could serve to shift the internal sleeve  124  downward. 
     In other embodiments, the internal sleeve  124  may be attached to the base pipe  102  via a c-ring or collet (not shown), allowing the wellbore device  152  to be introduced into the system  100 , such that when wellbore device  152  engages the internal sleeve  124  and shifts downward, the collet or c-ring may fall into a corresponding recess provided in the base pipe  102 . Without being constrained by the c-ring or collet, the internal sleeve  124  may be allowed to shift sufficiently to expose the pressure ports  138 . 
     Referring to  FIG. 5 , as the internal sleeve  124  is moved into its open position, the one or more pressure ports  138  become exposed and provide a conduit that fluidly communicates the atmospheric chamber  140  with the interior of the base pipe  102 . Until the trigger mechanism  122  is actuated, the atmospheric chamber  140  may be substantially filled with air or another fluid at atmospheric pressure. Accordingly, once the pressure ports  138  are exposed, the pressurized fluids within the base pipe  102  may escape into the lower pressure atmospheric chamber  140 . In some embodiments, the influx of the pressurized fluid from the base pipe  102  into the atmospheric chamber  140  may cause the piston port cover  126  to shift axially in direction A within the atmospheric chamber  140 . In at least one embodiment, the piston port cover  126  may be shifted axially until engaging an inner surface  160  of the trigger housing  128 . 
     Referring now to  FIGS. 1 and 5 , as the piston port cover  126  shifts in direction A, the seal provided by the sealing components  150  on the sleeve portion  126   b  is broken and the hydrostatic conduit  148  is thereby exposed to the atmospheric chamber  140 . Exposing the hydrostatic conduit  148  to the atmospheric chamber  140  may provide a means for fluid communication between the hydrostatic chamber  114  and the atmospheric chamber  140 . As a result, the higher pressure fluid from the hydrostatic chamber  114  flows into the lower pressure atmospheric chamber  140  and the hydrostatic equilibrium across the hydrostatic piston  112  is lost. Moreover, high pressure formation or wellbore fluids from the annulus  108  may also enter the hydrostatic chamber  114  via the one or more inlet ports  120  defined in the ramped retainer element  116 . As the hydrostatic piston  112  attempts to regain hydrostatic equilibrium, it may move axially in direction A. The influx of the high pressure fluids via the inlet ports  120  may provide additional axial force on the hydrostatic piston  112 , thereby forcing it further in direction A. 
     As the hydrostatic piston  112  moves axially in direction A, the compression sleeve  118  is forced up against the second axial end  110   a  of the down hole tool  110 , thereby resulting in the compression and radial expansion of the down hole tool  110 . As a result, the down hole tool  110  expands radially and engages the wall of the casing  106  to effectively isolate portions of the annulus  108  above and below the down hole tool  110 . 
     Accordingly, the disclosed system  100  and related methods may be used to remotely set the down hole tool  110 . The trigger mechanism  122  activates the setting action of the down hole tool  110  without the need of electronic devices or magnets, but instead relies on mechanical and fluid forces, especially ambient fluid pressures present around the tool  110  itself. Because the system  100  provides one or more pressure ports  138  defined within the base pipe  102 , fluid communication between both the atmospheric chamber  140  and the hydrostatic chamber  114  is provided. 
     Methods of using the system  100  may include a method for remotely setting a down hole tool disposed about a base pipe. The method may include engaging an internal sleeve arranged within the base pipe with a wellbore device. The internal sleeve may be slidable between a closed position and an open position, and the base pipe may define one or more pressure ports. A predetermined axial force may be applied on the internal sleeve with the wellbore device in order to move the internal sleeve into the open position. In the open position, the one or more holes may be exposed to an interior of the base pipe. With the one or more holes exposed, a fluid from the interior of the base pipe may flow into an atmospheric chamber via the one or more holes. The atmospheric chamber may be defined by a trigger housing disposed about the base pipe. The method may further include moving a piston port cover arranged within the atmospheric chamber from a blocking position into an exposed position using the fluid from the interior of the base pipe. When the piston port cover is in its exposed position, a hydrostatic conduit becomes exposed and provides fluid communication between the atmospheric chamber and a hydrostatic chamber. With fluid communication between the atmospheric chamber and a hydrostatic chamber, wellbore fluids can flow into the hydrostatic chamber and thereby move a hydrostatic piston arranged therein. The hydrostatic piston may be configured to set the down hole tool. 
     In some embodiments, the predetermined axial force on the internal sleeve is applied by applying fluid pressure against the wellbore device. In other embodiments, the predetermined axial force on the internal sleeve is applied by simply applying a mechanical force on the wellbore device. Applying the predetermined axial force on the internal sleeve may include shearing one or more pins that secure the internal sleeve to the base pipe. In other embodiments, however, applying the predetermined axial force on the internal sleeve may include removing or otherwise breaking other types of engagements with the base pipe including, but not limited to shear rings, c-rings, collets, combinations thereof, or the like. In some embodiments, the method may further include sealing the hydrostatic conduit from communication with the atmospheric chamber when the piston port cover is in the closed position. Moreover, allowing an influx of wellbore fluids into the hydrostatic chamber may further include creating a pressure differential across the hydrostatic piston such that the hydrostatic piston translates within the hydrostatic chamber. 
     In the following description of the representative embodiments of the invention, directional terms, such as “above”, “below”, “upper”, “lower”, etc., are used for convenience in referring to the accompanying drawings. In general, “above”, “upper”, “upward” and similar terms refer to a direction toward the earth&#39;s surface along a wellbore, and “below”, “lower”, “downward” and similar terms refer to a direction away from the earth&#39;s surface along the wellbore. 
     Therefore, the present invention is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended due to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered, combined, or modified and all such variations are considered within the scope and spirit of the present invention. In addition, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the elements that it introduces. If there is any conflict in the usages of a word or term in this specification and one or more patent or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted.