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BACKGROUND OF THE INVENTION  
         [0001]    Field of the Invention  
           [0002]    The present invention relates to downhole packers. More particularly, the present invention relates to a downhole packer with feed-through connections for communication conduits and a method for pressure testing the connections.  
         BACKGROUND OF THE RELATED ART  
         [0003]    Field of the Invention  
           [0004]    Downhole packers are typically used to seal an annular area formed between two co-axially disposed tubulars within a wellbore. For example, downhole packers may seal an annulus formed between production tubing disposed within well bore casing. Alternatively, packers may seal an annulus between the outside of a tubular and an unlined borehole. Routine uses of packers include the protection of casing from pressure, both well and stimulation pressures, as well as the protection of the wellbore casing from corrosive fluids. Other common uses include the isolation of formations or leaks within a well bore casing or multiple producing zones, thereby preventing the migration of fluid between zones. Packers may also be used to hold kill fluids or treating fluids within the casing annulus.  
           [0005]    Conventional packers typically comprise a resilient sealing element located between first and second retaining rings. The sealing element is typically a synthetic rubber composite which can be compressed by the retaining rings to expand radially outward into contact with an inner surface of a well casing there-around. The compression and expansion of the sealing element seals the annular area by preventing the flow or passage of fluid across the expanded sealing element.  
           [0006]    Conventional packers are typically run into a wellbore within a string of tubulars and anchored in the wellbore using mechanical compression setting tools or fluid pressure devices. Conventional packers are also typically installed using cement or other materials pumped into an inflatable sealing element.  
           [0007]    During the production of a well, downhole devices are often controlled or otherwise in communication with above-ground equipment. For example, a control panel above the earth&#39;s surface may direct a downhole valve to open or close, a sleeve to shift, or a motor to turn on or off. Data is also collected through the use of downhole devices and transmitted to the surface. For example, data may include pressure readings, temperature readings, flowing velocities, or flow rates. Data sent to and from the surface may be transmitted through a control line such as an electrical wire, fiber optic, or hydraulic conduit.  
           [0008]    Control lines connecting the surface equipment and the downhole devices are typically placed in the annulus between the well casing and the production tubing. For devices above a packer this is easily accomplished since the annulus is unobstructed. However, devices below a packer present a challenge since the annulus is sealed off. Packers of the prior art have provided for control lines to pass through the sealing element. One disadvantage associated with running the control lines through element is that the mechanical integrity of the sealing element is compromised. Another disadvantage is that an effective seal between the sealing element and the control lines traversing there-through is difficult to establish and even more difficult to maintain.  
           [0009]    Therefore, packers have recently provided for the control lines to pass longitudinally there-through. However, one disadvantage associated with packers of this type is pressure testing each and every connection disposed within the packer. Pressure testing each and every connection consumes valuable time prior to running the packer down the hole. Another disadvantage arises in these packers upon the retrieval of the packer from the well bore. Upon retrieval of the packer from the well bore, the control lines are simply stretched until they break. There is no way to determine how much force is required to break the control lines, and there is no way to determine where the control line will physically break.  
           [0010]    Furthermore, retrievable packers typically have a release mechanism disposed within a larger bore of a multi-bore packer because of the weight of the attached tubing string. The cross sectional area of a small bore is simply too small to handle the weight of an attached tubing string. One problem associated with having the release mechanism disposed within the large bore is that the larger bore is often in communication with the production tubing. Often times, the release mechanism becomes jammed or stuck due to an accumulation around the release mechanism of waxy paraffins from within the production fluid, making the packer difficult or near impossible to release.  
           [0011]    Therefore, there is a need for a downhole packer having a release mechanism disposed within a small bore that can withstand the weight of the attached tubing string. There is also a need for a packer with internal communication conduits having a cutting mechanism for controllably severing the control lines disposed there-through. There is further a need for a packer having one or more internal communication conduits having one test port to pressure test each connection of the packer thereby saving time and resources prior to running the packer down the hole.  
         SUMMARY OF THE INVENTION  
         [0012]    In one aspect, a packer is provided having a release mechanism disposed within a small bore that can withstand the weight of the attached tubing string. In one aspect, the packer comprises a body having one or more conduits formed there-through; a lock body disposed on a first end of the body; a collapsible member threadably engaged to the body at a first end and shouldered against the lock body at a second end; and a slideable member disposed within the collapsible member. In another aspect, the packer comprises a lock body disposed on a first end of the body, wherein the lock body comprises a recessed groove formed in an inner surface thereof; an expandable ring disposed within the recessed groove, wherein the expandable ring comprises concentric grooves disposed on an inner surface thereof which matably engage concentric grooves disposed about an outer surface of the body; a releasable collar at least partially disposed about the expandable ring; and a slideable sleeve at least partially disposed about the releasable collar.  
           [0013]    A packer is also provided with internal communication conduits having a cutting mechanism for controllably severing the control lines disposed therethrough. In one aspect, the packer comprises a body having one or more conduits formed there-through, wherein the one or more conduits comprises an enlarged first end; and a cutting member disposed with the enlarged first end. Movement of the body compresses the cutting member into a control line disposed within the conduit thereby controllably severing the control line.  
           [0014]    A packer is further provided with one or more internal communication conduits having one test port to pressure test each connection of the packer thereby saving time and manpower. In one aspect, the packer comprises a body having one or more conduits formed there-through; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; and an aperture for pressurizing the chamber. Pressurized fluid flows in a first direction through a first conduit to the chamber and flows in a second direction from the fluid chamber through each conduit.  
           [0015]    In addition, a method for retrieving a packer from a well bore is provided. In one aspect, the method comprises attaching a retrieval tool to a body, the body comprising one or more conduits formed there-through; a lock body disposed on a first end of the body, wherein the lock body comprises a recessed groove formed in an inner surface thereof; a ring disposed within the recessed groove, wherein the ring comprises concentric grooves disposed on an inner surface thereof which matably engage concentric grooves disposed about an outer surface of the body; a collar at least partially disposed about the ring; and a sleeve at least partially disposed about the collar; moving the sleeve from a first position to a second position using the retrieval tool; releasing the collar; and then expanding the ring. In another aspect, the method comprises attaching a retrieval tool to a body, wherein the body has one or more conduits formed there-through; a lock body disposed on a first end of the body; a collapsible member threadably engaged to the body at a first end and shouldered against the lock body at a second end; and a slideable member disposed within the collapsible member. The retrival tool is used to move the slideable member from a first position to a second position thereby disengaging the collapsible member from the lock body. Movement of the slideable member allows the collapsible member to collapse inwardly and release the packer.  
           [0016]    Further, a method of severing a control line in a well bore is provided. The method comprises releasing a body, the body comprising: one or more conduits formed there-through, wherein the one or more conduits comprises an enlarged first end; one or more control lines disposed within the one or more conduits; and a cutting member disposed with the enlarged first end; and compressing the cutting member. The cutting member has a sharp edge disposed thereto that controllably severs the control lines disposed through the conduits.  
           [0017]    Still further, a method of pressure testing conduits of a packer is provided. In one aspect, the packer comprises flowing a fluid into a body, wherein the body has one or more conduits formed there-through, wherein the one or more conduits comprises a seal mandrel disposed therein and an annular cavity formed between an outer surface of the seal mandrel and an inner surface of the body; and a chamber disposed within the body, wherein the chamber is in fluid communication with the annular cavities. The chamber acts as a manifold for pressure testing the one or more conduits. The pressurized fluid flows in a first direction through a first annular cavity to the chamber and flows in a second direction from the fluid chamber through each annular cavity. 
       
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0018]    So that the manner in which the above recited features, advantages and objects of the present invention are attained and can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof which are illustrated in the appended drawings.  
         [0019]    It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.  
         [0020]    FIGS.  1 A- 1 D are a section view of a packer of the present invention shown in a run position.  
         [0021]    [0021]FIG. 2 is section view along line  2 - 2  of FIG. 1C.  
         [0022]    [0022]FIG. 3 is section view along angled lines  3 - 3  of FIG. 2.  
         [0023]    FIGS.  4 A- 4 D are a section view of the packer of FIGS.  1 A- 1 D shown in a set position.  
         [0024]    FIGS.  5 A- 5 D are a section view of the packer of FIGS.  1 A- 1 D shown in a released position.  
         [0025]    [0025]FIG. 6 is a section view of a control line assembly along lines  6 - 6  of FIG. 2.  
         [0026]    [0026]FIG. 7 is a section view of a packer of the present invention in a run-in position having a release mechanism disposed within a small diameter bore.  
         [0027]    [0027]FIG. 8 is a section view along lines  8 - 8  of FIG. 7.  
         [0028]    [0028]FIG. 9 is a section view of the packer of FIG. 7 shown in a released position.  
         [0029]    [0029]FIG. 10 is a section view along lines  10 - 10  of FIG. 9. 
     
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT  
       [0030]    FIGS.  1 A- 1 D are a section view of a packer  100  of the present invention shown in a run position. The packer  100  includes a body  102  having an engagement assembly, a body lock ring assembly, a retrieval assembly, and one or more control line assemblies disposed thereon. For ease and clarity of description, the packer  100  will be described in more detail below as if disposed within a tubular in a vertical position as oriented in the FIGS.  1 - 10 . It is to be understood, however, that the packer  100  may be disposed in any orientation, whether vertical or horizontal. It is also to be understood that the packer  100  may be disposed in a bore hole without a tubular there-around.  
         [0031]    Referring to FIGS.  1 A- 1 D, the body  102  is a cylindrical member having one or more longitudinal bores formed there-through. As shown, the body includes two longitudinal bores  120 ,  130 , for communication with tubing string. The first bore  120  typically has a smaller inner diameter and is known as the “small” bore. The second bore  130  typically has a larger inner diameter and is known as the “large” bore. During operation, the small bore  120  is often used to flow inhibitors, diluents, or other chemicals to a selected zone of a well bore that has been chemically treated, for example. Conversely, the large bore  130  is often connected to, or otherwise in fluid communication, with a production string carrying production fluids from within the well bore.  
         [0032]    The body  102  also includes one or more communication conduits  140  formed longitudinally there-through as shown in FIG. 2. Hydraulic, fiber optic, and/or electrical control lines  160  are often disposed through the conduits  140  to communicate surface equipment with sub-surface equipment. The control lines  160  are sealed within the packer  100  using a control line assembly which is disposed within a lock body  150 . The lock body  150  is disposed on the second end of the body  102 , and is essentially an extension of the body  102 , as shown in FIG. 1C. Like the body  102 , the lock body  150  includes the bores  120 ,  130 , and the one or more communication conduits  140  disposed longitudinally there-through.  
         [0033]    Considering the engagement assembly in more detail, the engagement assembly includes a sealing element  210 , first and second gauge rings  212 ,  215 , first and second cones  220 ,  250 , cylinder  230 , first and second pistons  235 ,  240 , and slip  255 , each disposed about the body  102 . The engagement assembly further includes one or more snap rings  263 ,  265 ,  267 , a first variable volume chamber  270 , and a second variable volume chamber  280 . A first port  275  formed in an outer surface of the body  102  allows for fluid communication between the large bore  130  and the first variable volume chamber  270 , which is adjacent a first end of the first piston  235  and a second end of the second gauge ring  215 . A second port  285  formed in the outer surface of the body  102  allows for fluid communication between the large bore  130  and the second variable volume chamber  280  (shown in FIG. 4C).  
         [0034]    The engagement assembly further includes one or more “dogs”  260  to fix the cylinder  230  to the body  102 . The “dogs” therefore prevent any pre-mature activation or movement of the packer  100  caused by an unavoidable contact against the borehole as the packer  100  is run down into the hole. The “dogs”  260  are housed within apertures formed in the second section of the cylinder  230 , and a recessed groove formed in the outer surface of the body  102 . The first section of the second piston  240  is disposed about the “dogs”  260  to keep the “dogs”  260  within the groove formed about the body  102 . The operation of the dogs  260 , the snap rings  263 ,  265 , and  267  and the second chamber  280 , will be discussed below with the operation of the packer  100 .  
         [0035]    The slip  255  is disposed about the body  102  between the first cone  220  and the second cone  250 . An outer surface of the slip  255 , preferably includes at least one outwardly extending serration or edged tooth  256 , to engage an inner surface of a tubular  700  disposed there-around (shown in FIGS.  4 A- 4 D). The slip  255  typically includes at least one recessed groove (not shown) milled therein to fracture under stress allowing the slip  255  to expand radially outward to engage the inner surface of the tubular  700 . For example, the slip  255  may include four evenly sloped segments separated by equally spaced recessed grooves to contact the tubular  700  and become evenly distributed about the outer surface of the body  102 .  
         [0036]    An inner surface of the slip  255  has a first tapered end and a second tapered end corresponding to tapered surfaces of the first and second cones  220 ,  250 . The tapered end of the first cone  220  rests underneath the first tapered end of the slip  255 , and the tapered end of the second cone  250  rests underneath the second tapered surface of the slip  255 . As will be explained in more detail below, the second cone  250  travels toward the first cone  220  which is securely held to the body  102 . As a result, the slip  255  is forced radially outward and over the opposing tapered surfaces of the cones  220 ,  250  until the slip  255  engages the inner surface of the tubular  700 .  
         [0037]    The element  210  may have any number of configurations to effectively seal the annulus between the body  102  and the inner surface of the tubular  700 . For example, the element  210  may include grooves, ridges, indentations, or extrusions designed to allow the element  210  to conform to variations in the shape of the interior of the tubular  700 . The element  210  can be constructed of any expandable or otherwise malleable material which creates a permanent set position and stabilizes the body  102  relative to the tubular  700 . For example, the element  210  may be a metal, plastic, elastomer, or any combination thereof.  
         [0038]    The element  210  is disposed about the body  102  between the first gauge ring  212  and the second gauge ring  215 . The first gauge ring  212  is threadably engaged to an outer surface of the second cone  220 . As a result, the two members move together during the activation and release of the packer  100  which will be described below. The second gauge ring  215  consists of a first section and a second section having different outer diameters. The outer diameter of the first section is greater than the outer diameter of the second section thereby forming an interface or shoulder between the two sections.  
         [0039]    The cylinder  230  has a first section and a second section whereby the first section of the cylinder  230  has a greater inner diameter and a greater outer surface than the second section. The first section is disposed about the second section of the second gauge ring  212  and abuts the shoulder formed by the two sections of the second gauge ring  212 . The inner diameter of the second section abuts the outer diameter of the body  102 . Annular grooves are disposed about an outer surface and an inner surface of the second section to house an elastomeric seal or the like to form a fluid barrier within the first chamber  270  formed between the body  102  and the ring housing  410 .  
         [0040]    More particularly, the first chamber  270  is formed within the inner diameter of the first section of the cylinder  230  and the outer surface of the body  102 , between the second end of the second gauge ring  215  and a first end of the first piston  235 . The first port  275  is formed through the body  102  to place the bore  130  in fluid communication with the first chamber  270 . The first piston  235  and snap ring  263  are disposed about the body  102  within the chamber  270 . The snap ring  263  prevents axial movement of the first piston  235  in a direction opposite the second gauge ring  215 . Annular grooves are disposed about an outer surface and an inner surface of the first piston  235  to house an elastomeric seal or the like to form a fluid barrier between the cylinder  230  and the body  102 . As will be explained below in more detail, fluid from the bore  130  travels through the port  275  into the chamber  270  and asserts a force against the second gauge ring  215  in a first direction and against the piston  235  in a second direction.  
         [0041]    Considering the body lock ring assembly in more detail, the assembly includes a lock ring  410  and a ring housing  420 . The body lock ring  410  is a cylindrical member radially disposed between the ring housing  420  and the lock body  150 . The lock ring  410  includes an inner surface having profiles disposed thereon to mate with profiles formed on the outer surface of the lock body  150 . A longitudinal cut within the lock ring  410  allows the lock ring  410  to expand radially and contract as it movably slides or ratchets in relation to the outer surface of the lock body  150 .  
         [0042]    The ring housing  420  is radially disposed about the cylinder  230  at a first end and the body lock ring  410  at a second end. At the first end, the ring housing  420  abuts the shoulder formed in the outer surface of the cylinder  230  and is threadably engaged to the second section of the cylinder  230 . At the second end, the ring housing  420  has a jagged inner surface to engage a mating jagged outer surface of the lock ring  410 . The relationship between the jagged surfaces creates a gap there-between allowing the lock ring  410  to expand radially as the profiles formed thereon move across mating profiles formed on the lock body  150 . The profiles formed on the lock ring  410  have a tapered leading edge allowing the lock ring  410  to move across the mating profiles formed on the lock body  150  in one axial direction while preventing movement in the other direction.  
         [0043]    In particular, the profiles formed on both the outer surface of the lock body  150  and the inner surface of the lock ring  410  consist of formations having one side which is sloped and one side which is perpendicular to the outer surface of the lock body  150 . The sloped surfaces of the mating profiles allows the lock ring  410  to move across the body  102  in a single axial direction, whereas the perpendicular sides of the mating profiles prevent movement in the opposite axial direction. Therefore, the lock ring  410  may move or “ratchet” in one axial direction, but not the opposite axial direction.  
         [0044]    The second chamber  280  is formed within the inner diameter of the ring housing  420  and the outer surface of the body  102 , between the second end of the cylinder  230  and a first end of the lock body  150 . The second port  285  formed in an outer surface of the body  102  provides for fluid communication between the bore  130  and the chamber  280 .  
         [0045]    The second piston  240  and snap rings  265  and  267  are disposed about the body  102  within the chamber  280 . The second piston  240  is an annular member disposed about the body  102  adjacent the second end of the second gauge ring  215  and the lock body  150 . The second piston  240  has a first section and a second section, whereby the first section has a greater inner diameter than the second section. The first section is disposed about an annular channel formed in the outer surface of the second section cylinder  230 . The second section is disposed directly about the body  102 . Annular grooves are disposed about an outer surface and an inner surface of the second section to house an elastomeric seal or the like to form a fluid barrier between the ratchet housing  420  and the body  102 . As will be explained below in more detail, fluid from the bore  130  travels through the port  285  into the chamber  280  and asserts a force against the cylinder  230  in a first direction and against the piston  240  in a second direction. Within the chamber  280 , the snap ring  265  prevents the axial movement of the piston  240  in a direction opposite the lock body  150 , while the snap ring  267  prevents axial movement of the piston  240  in a direction opposite the cylinder  230 .  
         [0046]    Considering the retrieval assembly in more detail, the retrieval assembly includes a collet  510  and a support sleeve  520 . The collet  510  is an annular, cylindrical member having a first section and a second section. The first section is a solid member which is threadably engaged to the body  102 . The second section includes a plurality of collapsible members or fingers which are shouldered out against an inner surface of the lock body  150 . The lock body  150 , therefore, is held to the body  102  through the fingers of the collet  510 .  
         [0047]    The support sleeve  520  is an annular member disposed about the inner surface of second section of the collect release  510 . The support sleeve  520  is affixed to the collet  510  through one or more shearable members  530 , such as shear pins, for example. The removal of the support sleeve  520  allows the fingers of the collet  510  to collapse and thereby release the lock body  150 . As will be described below, upon the collapse of the fingers, the fingers will disengage from the inner surface of the lock body  150  and allow the lock body  150  to travel away from the body  102 , which thereby activates a cutting mechanism that severs the control line disposed there-through.  
         [0048]    Referring to FIGS. 2 and 3, each conduit  140  of the lock body  150  contains a control line assembly to sever the control lines  160  running through the respective conduit  140 . Each control line assembly includes a seal sleeve  302 , a wedge housing  305 , one or more cutting wedges  310 , and a ferrule fitting  320 . The seal sleeve  302  is an annular, cylindrical member having a first end that is threadably engaged to the body  102 . A first end of the wedge housing  305  is threadably engaged to a second end of the seal sleeve  302 . A second end of the wedge housing  305  is a hexagonal head  307  or a comparable configuration, which is connectable to a tool, not shown, for operating the ferrule  320 . The wedge housing  305  also has a plurality of apertures formed axially therein to be used in conjunction with the cutting wedges  310 .  
         [0049]    The cutting wedges  310  are disposed about the wedge housing  305  and housed within a flared second end of each conduit  140 . The cutting wedges  310  are aligned with the apertures formed in the wedge housing  305 , and when activated, the flared second end of the conduit  140  travels over the cutting wedges  310 , forcing the cutting wedges  310  radially inward toward the control line  160 . Accordingly, the cutting wedges  310  are forced into the apertures, thereby severing the control line  160 .  
         [0050]    As shown in FIG. 3, an annulus  399  is formed between an outer surface of each seal sleeve  302  and an inner surface of each communication conduit  140 . A fluid chamber  350  is also formed between the interface of the body  102  and the lock body  150  such that each annulus  399  is in fluid communication with the fluid chamber  350 . The fluid chamber  350 , therefore, acts a manifold providing fluid communication between each annulus  399  for transferring fluid from one annulus  399  to another.  
         [0051]    A test port  360  is disposed on the lock body  150  and is used to simultaneously pressure test each control line assembly disposed in the packer  100 . The test port  360  is in fluid communication with a first annulus  399  formed about a first seal sleeve  302 . A test fluid, preferably a liquid, is introduced through the test port  360  to the first annulus  399 . The test fluid travels within the first annulus  399  to the fluid chamber  350 . From the fluid chamber  350 , the fluid travels via each annulus  399  to the test holes  330  disposed on the ferrule fittings  320 . Accordingly, each ferrule fitting  320  can be pressure tested simultaneously to ensure a proper fluid seal within each conduit.  
         [0052]    FIGS.  4 A- 4 D are a section view of the packer  100  shown in a set position within a tubular  700 . To set or actuate the packer  100 , the packer  100  is first attached within a string of tubulars (not shown) and control lines (not shown), and run down a wellbore to a desired location. Fluid pressure within the bore  130  is supplied to the first and second chambers  270 ,  280 , through their respective ports  275 ,  285 . The fluid pressure within the chambers  270 ,  280 , is substantially equal to the pressure within the bore  130 .  
         [0053]    Within the second chamber  280 , the fluid pressure forces the second piston  240  in a second direction toward the snap ring  267 . The second piston  240  transfers force through the snap ring  267  to the body  102  which transfers the force into the lock body  150 . Since the ratchet housing  420  is threadably engaged to the cylinder  230 , the lock body  150  moves relative to the body lock ring assembly which causes the lock ring  410  to ratchet across the lock body  150  in the first direction. Movement of the second piston  240  also uncovers the “dogs”  260  which disconnects the cylinder  230  from the body  102 . Consequently, the fluid pressure moves the cylinder  230  in a first direction toward the engagement assembly.  
         [0054]    Within the first chamber  270 , the fluid pressure moves the first piston  235  in the second direction against the snap ring  263 . The snap ring  263  transfers the force to the body  102 . In the first direction, the fluid pressure exerts a force against the second gauge ring  215 , moving the ring  215  toward the engagement assembly. Since the second gauge ring  215  and the cylinder  230  are threadably engaged as well as shouldered out, the two members  215 ,  230  move in the first direction together. Moreover, since the two members  215 ,  230  are tied together, the sum of the forces within the volumes of the first chamber  270  and the second chamber  280  is asserted against the members  215 ,  230  in the first direction. Accordingly, the volumes of the respective chambers  270 ,  280  can be smaller than if they were to operate individually.  
         [0055]    Continuing in the first direction, the cylinder  230  and second gauge ring  215  transfer the force through the sealing element  210  to the first gauge ring  212 , which is threaded to the second cone  250 . The first cone  220  is held securely to the body  102 , thereby exerting an equal and opposite force against the members moving in the first direction. Accordingly, the second cone  250  moves underneath the slip  255 , driving the slip  255  up an over the tapered surfaces of the first cone  220  and the second cone  250 , and radially outward toward the tubular  700 , as shown in FIGS. 4A and 4B. At the same time, the first and second gauge rings  212 ,  215 , longitudinally compress and radially expand the element  210  toward the tubular  700 , as shown in FIG. 4B.  
         [0056]    To retrieve the packer  100  and controllably sever the control lines  160 , a retrieval tool, not shown, is attached to the support sleeve  520 . The tool applies a force in the first direction to the support sleeve  520  to shear the shearable members  530  holding the support sleeve  520  to the collet  510 . Referring to FIGS.  5 A-FD, once the shareable members  530  release, the support sleeve  520  travels axially in the first direction along the collet  510  from a first position to a second position. The release of the support sleeve  520  allows the fingers of the collet  510  to collapse radially inward, thereby disengaging the lock body  150  from the collet  510 . Consequently, the lock body  150  is free to move independently of the body  102  in the second direction by the weight of the tubing string attached thereto.  
         [0057]    As the lock body  150  moves in the second direction away from the body  102 , the body lock ring assembly ratchets in the first direction across the lock body  150  until the lock ring  410  contacts the shoulder formed in the outer surface of the first end of the lock body  150 . At this point, the body lock ring assembly now moves with the lock body  150 . Since the lock ring housing  420  is threadably engaged to the cylinder  230  which is threadably engaged to the second gauge ring  215 , the slip  255  and the element  210  are allowed to relax and move radially inward away from the tubular  700 , thereby disengaging the packer  100  from the wellbore.  
         [0058]    In addition, movement of the lock body  150  away from the body  102  activates the control line assemblies which controllably sever the control lines  160  as shown in FIG. 6. In particular, movement of the lock body  150  in the second direction, opposite the body  102 , causes the wedges  310  to travel up the slope of the tapered second end of the conduits  140  thereby forcing the wedges  310  into the apertures of the wedge housing  305 . Consequently, the sharp surfaces of the wedges contact the control lines  160  and sever the control lines  160  at the point of contact.  
         [0059]    In addition to the packer  100  described above, FIG. 7 is a section view of a packer  200  shown in a run position having a release mechanism disposed in the first bore  120 . Due to the physical properties of the production fluid, a release mechanism in the production tubing may become unreliable. For example, paraffins in the production fluid have a tendency to accumulate and collect on the release mechanism and thereby effectively prevent the operation of the mechanism. Therefore, it is desirable to have the release mechanism disposed within the non-production bore  120 , as shown in FIGS.  7 - 10 .  
         [0060]    The packer  200  includes an engagement assembly, one or more control line assemblies, a body lock ring assembly, and a retrieval assembly. The engagement assembly, body lock ring assembly, and control line assembly are similar to those described above for the packer  100 , and therefore, utilize the same numeric identification. The different retrieval assembly of the packer  200  includes a support sleeve  600 , a containment ring  610 , a stopper  620 , and a release sleeve  630 .  
         [0061]    The support sleeve  600  is disposed within the second bore  130 , and connects the lock body  150  to the body  102 . The support sleeve  600  is a cylindrical member and is threadably engaged to the second bore  130  at a first end thereof. At a second end, the support sleeve  600  has a plurality of concentric grooves formed in an outer surface thereof to engage mating concentric grooves formed in an inner surface of the containment ring  610 .  
         [0062]    The containment ring  610  is a split-ring disposed about the second end of the support sleeve  600 , and is disposed within a window formed in an inner surface of the lock body  150 . As stated above, the containment ring  610  has a plurality of concentric grooves formed in an inner surface thereof to matably engage the grooves of the support sleeve  600 . The containment ring  610  also has at least two axially recessed grooves  612 ,  614 , formed in an outer surface thereof, as shown in FIG. 8.  
         [0063]    Referring to FIGS. 7 and 8, the stopper  620  is disposed about the containment ring  610  and has one or more legs  625  extending from an inner surface thereof that are disposed within the recessed grooves  612 ,  614 , of the containment ring  610 . The legs  625  prevent the containment ring  610  from splitting open until retrieval of the packer  200  is desired.  
         [0064]    The release sleeve  630  is disposed within the first bore  120  and covers an outer surface of the stopper  620 . The release sleeve  630  holds the stopper  620  against the containment ring  610 . A first end of the release sleeve  630  is attached to the body  102  through a shearable member  635 , such as a shear pins, for example. Upon the release of the release sleeve  630 , the stopper  620  is uncovered and allowed to disengage from the containment ring  610  as shown in FIGS. 9 and 10. Once the stopper  620  is released, the containment ring  610  expands open, disengaging its concentric grooves from the concentric grooves formed in the support sleeve  600 . The lock body  150  is therefore released from the body  102 . As described above, axial movement of the lock body  150  in the second direction, away from the body  102 , activates the cutting mechanisms disposed within the control line assemblies, and also disengages the slip  255  and element  210  from the tubular  700  there-around.  
         [0065]    The aspects of the invention described herein are not limited to uses in a packer and could have similar uses in any wellbore component. Furthermore, while foregoing is directed to the preferred embodiment of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.

Summary:
A packer and method for sealing an annulus in a wellbore is provided. In one aspect the packer comprises a body having one or more conduits formed there-through; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; and an aperture for pressurizing the chamber. In another aspect, the packer comprises a body having one or more conduits formed there-through; a lock body disposed on a first end of the body; a collapsible member threadably engaged to the body at a first end and shouldered against the lock body at a second end; and a slideable member disposed within the collapsible member. In yet another aspect, the packer comprises a body having one or more conduits formed there-through, wherein the one or more conduits comprises an enlarged first end; and a cutting member disposed with the enlarged first end.