Patent Publication Number: US-10329864-B2

Title: Connector assembly for a mineral extraction system

Description:
BACKGROUND 
     This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art. 
     Natural resources, such as oil and gas, are used as fuel to power vehicles, heat homes, and generate electricity, in addition to a myriad of other uses. Once a desired resource is discovered below the surface of the earth, drilling and production systems are often employed to access and extract the resource. These systems may be located onshore or offshore depending on the location of a desired resource. Further, such systems generally include a wellhead assembly through which the resource is extracted. These wellhead assemblies may include a wide variety of components, such as various spools, housings, pipes, valves, fluid conduits, and the like, that facilitate drilling and/or extraction operations. 
     Certain components of the mineral extraction system, such as conduits, pipes, or other tubulars, may be joined and sealed by locking mechanisms to provide a flow path for fluids during extraction. However, because such locking mechanisms may utilize additional parts and tools (e.g., multiple threaded fasteners or bolts) to lock or unlock the components, the installation, repair, and/or replacement of such components may be tedious and inefficient. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       Various features, aspects, and advantages of the present invention will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein: 
         FIG. 1  block diagram of a mineral extraction system, in accordance with an embodiment of the present disclosure; 
         FIG. 2  is a cross-sectional side view of an embodiment of a connector assembly having a lock ring with multiple grooves that may be utilized to join a first component to a second component of the mineral extraction system of  FIG. 1 ; 
         FIG. 3  is a cross-sectional side view of the connector assembly of  FIG. 2 , wherein the connector assembly is in a locked position that joins the first component to the second component; 
         FIG. 4  is a cross-sectional side view of an embodiment of a port that may be utilized in the connector assembly of  FIGS. 2 and 3 ; 
         FIG. 5  is a cross-sectional side view of an embodiment of a connector assembly having a lock ring with a c-shaped profile that may be utilized to join a first component to a second component of the mineral extraction system of  FIG. 1 ; 
         FIG. 6  is a flow diagram of an embodiment of a method for joining two components of a mineral extraction system to one another using the connector assembly of  FIGS. 1-5 ; 
         FIG. 7  is a cross-sectional side view of an embodiment of a connector assembly having a sliding outer sleeve that may be utilized to join a first component to a second component of the mineral extraction system of  FIG. 1 ; 
         FIG. 8  is a cross-sectional side view of the connector assembly of  FIG. 7 , wherein a lock ring of the connector assembly is aligned with a corresponding portion of the second component; 
         FIG. 9  is a cross-sectional side view of the connector assembly of  FIGS. 7 and 8 , wherein the lock ring of the connector assembly engages the corresponding portion of the second component; 
         FIG. 10  is a cross-sectional side view of the connector assembly of  FIGS. 7-9 , wherein dogs of the connector assembly engage the first component; 
         FIG. 11  is a cross-sectional side view of the connector assembly of  FIGS. 7-10 , wherein the connector assembly is disengaged from the first component and the second component; 
         FIG. 12  is a cross-sectional side view of a connector assembly having a stab that may be utilized to join a first component to a second component of the mineral extraction system of  FIG. 1 ; 
         FIG. 13  is a cross-sectional side view of the connector assembly of  FIG. 12 , wherein the connector assembly engages the first component and the second component; and 
         FIG. 14  is a flow diagram of an embodiment of a method for joining two components of a mineral extraction system to one another using the connector assembly of  FIGS. 7-13 . 
     
    
    
     DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS 
     One or more specific embodiments of the present disclosure will be described below. These described embodiments are only exemplary of the present disclosure. Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers&#39; specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another. Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure. 
     Embodiments of the present disclosure include systems and methods that utilize a connector assembly to connect components (e.g., tubular members) in a mineral extraction system. With the foregoing in mind,  FIG. 1  is a block diagram of an embodiment of a mineral extraction system  10  that may utilize a connector assembly, as discussed in further detail below. The illustrated mineral extraction system  10  may be configured to extract various minerals and natural resources, including hydrocarbons (e.g., oil and/or natural gas), from the earth, or to inject substances into the earth. In some embodiments, the mineral extraction system  10  is land-based (e.g., a surface system) or sub-sea (e.g., a sub-sea system). As illustrated, the system  10  includes a wellhead  12  coupled to a mineral deposit  14  via a well  16 . The well  16  may include a wellhead hub  18  and a well bore  20 . The wellhead hub  18  generally includes a large diameter hub disposed at the termination of the well bore  20  and designed to connect the wellhead  12  to the well  16 . 
     The wellhead  12  may include multiple components that control and regulate activities and conditions associated with the well  16 . For example, the wellhead  12  generally includes conduits, valves, and seals that route produced minerals from the mineral deposit  14 , regulate pressure in the well  16 , and inject chemicals down-hole into the well bore  20 . In the illustrated embodiment, the wellhead  12  includes what is colloquially referred to as a Christmas tree  22  (hereinafter, a tree), a tubing spool  24 , a casing spool  26 , and a hanger  28  (e.g., a tubing hanger and/or a casing hanger). The system  10  may include other components that are coupled to the wellhead  12 , and devices that are used to assemble and control various components of the wellhead  12 . For example, in the illustrated embodiment, the system  10  includes a running tool  30  suspended from a drill string  32 . In certain embodiments, the running tool  30  includes a running tool that is lowered (e.g., run) from an offshore vessel to the well  16  and/or the wellhead  12 . In other embodiments, such as surface systems, the running tool  30  may be suspended over and/or lowered into the wellhead  12  via a crane or other supporting device. 
     The tree  22  generally includes a variety of flow paths (e.g., bores), valves, fittings, and controls for operating the well  16 . For instance, the tree  22  may include a frame that is disposed about a tree body, a flow-loop, actuators, and valves. Further, the tree  22  may provide fluid communication with the well  16 . For example, the tree  22  includes a tree bore  34 . The tree bore  34  provides for completion and workover procedures, such as the insertion of tools into the well  16 , the injection of various chemicals into the well  16 , and so forth. Further, minerals extracted from the well  16  (e.g., oil and natural gas) may be regulated and routed via the tree  22 . For instance, the tree  22  may be coupled to a jumper or a flowline that is tied back to other components, such as a manifold. Accordingly, produced minerals flow from the well  16  to the manifold via the wellhead  12  and/or the tree  22  before being routed to shipping or storage facilities. A blowout preventer (BOP)  36  may also be included, either as a part of the tree  22  or as a separate structure. The BOP  36  may consist of a variety of valves, fittings, and controls to prevent oil, gas, or other fluid from exiting the well in the event of an unintentional release of pressure or an overpressure condition during drilling operations, for example. 
     The tubing spool  24  provides a base for the tree  22 . The tubing spool  24  is one of many components in a modular sub-sea or surface mineral extraction system  10  that is run from an offshore vessel or surface system. The tubing spool  24  includes a tubing spool bore  38 . The tubing spool bore  38  connects (e.g., enables fluid communication between) the tree bore  34  and the well  16 . Thus, the tubing spool bore  38  may provide access to the well bore  20  for various completion and workover procedures. For example, components can be run down to the wellhead  12  and disposed in the tubing spool bore  38  to seal off the well bore  20 , to inject chemicals down-hole, to suspend tools down-hole, to retrieve tools down-hole, and so forth. 
     The well bore  20  may contain elevated pressures. For example, the well bore  20  may include pressures that exceed 10,000, 15,000, or even 20,000 pounds per square inch (psi). Accordingly, the mineral extraction system  10  may employ various mechanisms, such as seals, plugs, and valves, to control and regulate the well  16 . For example, plugs and valves are employed to regulate the flow and pressures of fluids in various bores and channels throughout the mineral extraction system  10 . For instance, the illustrated hanger  28  (e.g., tubing hanger or casing hanger) may be disposed within the wellhead  12  to secure casing suspended in the well bore  20 , and to provide a path for hydraulic control fluid, chemical injections, and so forth. The hanger  28  includes a hanger bore  40  that extends through the center of the hanger  28 , and that is in fluid communication with the tubing spool bore  38  and the well bore  20 . One or more seal assemblies and/or landing assemblies may be disposed between the hanger  28  and the tubing spool  24  and/or the casing spool  26 . As shown, the wellhead  12  include various tubular members (e.g., a tubular member of the wellhead hub  18 , the casing spool  26 , the tubing spool  24 , the tree  22 , the BOP  36 , or various spools, housings, adapters, or pipes that define respective bores or fluid flow paths), and the various tubular members may be joined to one another to facilitate drilling and extraction operations. 
     One or more connector assemblies (e.g., tubular connector assemblies) may also be utilized to join components of the mineral extraction system  10  to one another. For example, a connector assembly may be utilized to join a first component to a second component (e.g., a first tubular to a second tubular, such as the wellhead hub  18  to the casing spool  26 , the casing spool  26  to the tubing spool  24 , the tubing spool  24  to the tree  22 , the tree  22  to the BOP  36 , portions of the tree  22  to one another, or to join any of a variety of other components, such as spools, housings, adapters, or pipes to one another or to the wellhead hub  18 , the casing spool  26 , the tubing spool  24 , the tree  22 , the BOP  36 ) within the mineral extraction system  10 . The disclosed connector assemblies may effectively and efficiently join components to one another, thereby increasing operational efficiency, for example. To facilitate discussion, the components of the mineral extraction system  10 , including the connector assemblies, may be described with reference to an axial axis or direction  42 , a radial axis or direction  44 , and a circumferential axis or direction  46 . 
       FIG. 2  is a cross-sectional side view of an embodiment of a connector assembly  50  that may be utilized to join a first component  52  (e.g., a first tubular component) to a second component  54  (e.g., a second tubular component) within the mineral extraction system  10  of  FIG. 1 . As noted above, the first component  52  and the second component  54  may be any of a variety of structures, including wellhead hub  18 , the casing spool  26 , the tubing spool  24 , the tree  22 , the BOP  36 , or any of a variety of other components, such as spools, housings, adapters, or pipes that may be utilized with the wellhead  12  or other portions of the mineral extraction system  10 . 
     In the illustrated embodiment, the first component  52  supports the connector assembly  50 , which includes a first body  56  (e.g., annular body) and a second body  58  (e.g., annular body). In some embodiments, the first body  56  or the second body  58  may be an adapter coupled to the first component  52  (e.g., via one or more fasteners, such as bolts). In some embodiments, the first body  56  and/or the second body  58  may be or form part of a main body (e.g., tubular section or pipe) of the first component  52 . For example, in  FIG. 1 , the first body  56  is part of a main body of the first component  52 , and the first body  56  contacts fluid that flows through the second component  54 . As shown, multiple fasteners  60  extend axially through corresponding openings  62  formed in the first body  56  and into corresponding openings  64  (e.g., threaded openings) formed in the second body  58 . Thus, each fastener  60  is coupled (e.g., threadably coupled) to the second body  58  via a respective threaded interface  65 . 
     A respective groove  66  is formed in the first body  56  of the first component  52  at the location of each fastener  60 , and each fastener  60  extends through a seal  68  (e.g., annular seal). The seal  68  is positioned within the groove  66  to form a sealed space  70  (e.g., annular space or hydraulic chamber). As shown, additional seals  72  (e.g., o-ring seals or annular seals) are positioned at various locations to block fluid flow and to seal the sealed space  70 . The multiple fasteners  60  (e.g., 2, 3, 4, 5, 6, 7, 8, 9, 10, or more) and associated features (e.g., the seals  68 , the grooves  66 , etc.) may be positioned circumferentially about the connector assembly  50 . 
     The connector assembly  50  may move between a first position (e.g., unlocked position) and second position (e.g., unlocked position). In the first position, a lock ring  74  (e.g., segmented ring or c-shaped ring) is in an expanded position (e.g., radially-expanded position) in which the lock ring  74  does not protrude radially into a bore  75  (e.g., central bore) and/or enables the lock ring  74  to receive the second component  54  (e.g., the connector assembly  50  can be moved axially, as shown by arrow  77 , to a position in which the lock ring  74  circumferentially surrounds the second component  54 ). As shown, the lock ring  74  includes a first tapered surface  90  (e.g., circumferentially-extending surface) in contact with a corresponding tapered surface  92  (e.g., tapered annular surface, conical surface, camming surface, energizing surface) of the first body  56  of the first component  52  and a second tapered surface  94  (e.g., circumferentially-extending surface) in contact with a corresponding tapered surface  96  (e.g., tapered annular surface, conical surface, camming surface, energizing surface) of the second body  58 . 
     In certain embodiments, the lock ring  74  may be a segmented ring or c-shaped ring having a first circumferential end and a second circumferential end that define a space (e.g., a gap) at a circumferential location about the ring. Such a configuration enables radial adjustment of the lock ring  74 , as discussed in more detail below. As shown, a radially-inner surface  76  (e.g., annular surface) of the lock ring  74  includes multiple grooves or teeth  78  that are configured to engage corresponding grooves  80  formed in a radially-outer surface  80  (e.g., annular surface) of the second component  54 . However, it should be understood that the radially-inner surface  76  and the radially-outer surface  80  may have any of a variety of corresponding surfaces or features that facilitate coupling the lock ring  74  to the second component  54  (e.g., blocking relative axial movement). 
     In operation, the first component  52  supporting the connector assembly  50  and/or the second component  54  may be moved relative to one another to position the second component  54  within the lock ring  74  of the connector assembly  50 . For example, the second component  54  may be in a fixed position over a well, and the connector assembly  50  may be lowered axially, as shown by arrow  77 , until the multiple teeth and grooves  78  of the lock ring  74  are axially aligned with the corresponding teeth and grooves  80  of the second component  54 . As discussed in more detail below, fluid (e.g., hydraulic fluid, liquid, or gas) may then be provided to the sealed space  70  to drive the first body  56  of the first component  52  axially relative to the second body  58 . The axial movement of the first body  56  of the first component  52  drives the lock ring  74  radially-inwardly (e.g., via a wedging action due to contact between the tapered surfaces  90 ,  92 ,  94 ,  96 ) to engage the teeth and grooves  78  with the corresponding teeth and grooves  80  of the second component  54 , thereby locking the first component  52  to the second component  54  (e.g., blocking axial movement of the first component  52  relative to the second component  54 ). As discussed in more detail below, the connector assembly  50  includes an outer sleeve  98  (e.g., annular sleeve) which may be utilized to hold the first component  52  and the second component  54  together. 
       FIG. 3  is a cross-sectional side view of the connector assembly  50  of  FIG. 2 . In  FIG. 3 , the connector assembly  50  is in a second position  100  (e.g., locked position). In the second position  100 , the lock ring  74  is in a contracted position (e.g., radially-contracted position) in which the lock ring  74  contacts the second component  54 , engages the second component  54 , and/or blocks axial movement of the second component  54  relative to the lock ring  74  and the first component  52 , for example. 
     To achieve the second position  100 , fluid may be provided to the sealed space  70 , such as via one or more ports  102 , as shown in  FIG. 4 . As shown in  FIG. 4 , the one or more ports  102  are supported by the seal  68  and are configured to provide fluid to the sealed space  70 . The one or more ports  102  may be positioned between adjacent fasteners  60  about the circumference of the first body  56  of the first component  52 . In some embodiments, multiple ports  102  (e.g., 2, 3, 4, 5, 6, or more) may be positioned about the circumference in any suitable location. It should be understood that the ports  102  may be positioned at any suitable location of the connector assembly  50  and that the fluid may be provided to the sealed space  70  via any suitable technique. 
     When the fluid is provided to the sealed space  70  (e.g., via the one or more ports  102 ), the fluid may cause the first body  56  of the first component  52  and the second body  58  to move toward one another, thereby reducing a space  101  (e.g., annular space) between the first body  56  of the first component  52  and the second body  58  along the axial axis  44 . In particular, when fluid is provided to the sealed space  70 , the fluid may drive the first body  56  of the first component  52  axially, as shown by arrow  104 , and/or the fluid may drive the second body  58  axially, as shown by arrow  106  (e.g., because the fastener  60  is threadably coupled to the second body  58  via the threaded interface  65 ). Therefore, when the fluid is provided to the sealed space  70  and as an axial distance across the space  101  is reduced, the first body  56  of the first component  52  and the second body  58  drive the lock ring  74  radially-inwardly, as shown by arrow  108 , to engage the second component  54 . 
     In particular, contact between the tapered surface  90  and the corresponding tapered surface  92  of the first body  56  of the first component  52  and contact between the tapered surface  94  and the corresponding tapered surface  96  of the second component  54  as the fluid is provided to the sealed space  70  drives the lock ring  74  radially-inwardly until the multiple grooves  76  of the lock ring  76  engage the corresponding grooves  80  of the second component  54 , thereby locking the first component  52  to the second component  54  (e.g., blocking axial movement of the first component  52  relative to the second component  54 ). 
     While the fluid is within the sealed space  70  and the lock ring  74  engages the second component  54 , the outer sleeve  98  may be positioned about the first component  52  and the second component  54 , and then rotated to threadably couple the outer sleeve  98  to the second component  54  via a threaded interface  110 . The outer sleeve  98  may be rotated and move axially relative to the first component  52  and the second component  54  until a lip  112  (e.g., radially-inwardly expanding portion) of the outer sleeve  98  contacts and engages a corresponding portion  114  (e.g., radially-outwardly expanding portion) of the first body  56  of the first component  52 . Once the outer sleeve  98  is in place about the first component  52  and component  54 , the outer sleeve  98  may maintain the connector assembly  50  in the locked position  100 , thereby locking the first component  52  to the second component  54 . In some embodiments, the fluid pressure within the sealed space  70  may be reduced or removed, and the outer sleeve  98  may maintain the locked position  100 . As shown, one or more seals  116  (e.g., o-rings or annular seals) may be positioned between the first component  52  and the second component  56  to block fluid flow from the bore  75 , for example. 
       FIG. 5  is a cross-sectional side view of an embodiment of the connector assembly  50  having a lock ring  120  (e.g., segmented ring or c-shaped ring) with a c-shaped profile (e.g., cross-section taken in a plane parallel to the axial axis  44 ) that may be utilized to join the first component  52  to the second component  54 . As noted above, the first body  56  and/or the second body  58  may be or form part of a main body (e.g., tubular section or pipe) of the first component  52 . In  FIG. 5 , the second body  58  is part of a main body of the first component  52 , and the second body  58  contacts fluid that flows through the second component  54 . In the illustrated embodiment, the threaded fastener  60  extends axially through the first body  56  and is threadably coupled to the second body  58  via the threaded interface  65 . As fluid is provided to the sealed space  70  (e.g., via ports, such as the ports shown in  FIG. 4 ), the first body  56  and the second body  58  may move toward one another, thereby reducing the axial distance across the space  101  and driving the lock ring  120  radially inwardly to engage a corresponding recess  122  (e.g., annular recess) in the second component  54 . The outer sleeve  98  may be threadably coupled to the second body  58 , thereby maintaining the illustrated locked position  100 . As discussed above, the first component  52  and the second component  54  may be any of a variety of tubular members or other components within the mineral extraction system  10 , and thus, may support or include various ports, seals, hangers, or the like, as shown in  FIGS. 2, 3, and 5 , for example. 
       FIG. 6  is a flow diagram of an embodiment of a method  130  for joining two components (e.g., the first component  52  and the second component  54 ) of the mineral extraction system  10  to one another using the connector assembly  50  illustrated in  FIGS. 2-5 . The method  130  includes various steps represented by blocks. It should be noted that some or all of the steps of the method  130  may be performed as an automated procedure by an automated system and/or some or all of the steps of the method  130  may be performed manually by an operator. Although the flow chart illustrates the steps in a certain sequence, it should be understood that the steps may be performed in any suitable order and certain steps may be carried out simultaneously, where appropriate. Further, certain steps or portions of the method  130  may be omitted and other steps may be added. 
     The method  130  may begin by positioning the first component  52  that supports the connector assembly  50  about the second component  54 , as shown in step  132 . For example, the first component  52  may be moved relative to the second component  54  until the lock ring  74 ,  120  is axially aligned with a corresponding feature (e.g., grooves  80 , recess  122 ) of the second component  54 , as shown in step  134 . A fluid may then be provided to the sealed space  70 , which causes portions of the connector assembly  50  (e.g., the first body  56  and the second body  58 ) to move toward one another, which in turn drives the lock ring  74 ,  120  radially-inwardly (e.g., via a wedging or camming action due to contact between surface  90 ,  92 ,  94 ,  96 ) to engage the corresponding feature of the second component  54 , as shown in step  136 . The outer sleeve  98  may be applied about the first body  56  and the second body  56  to maintain the locked position  100  (e.g., the outer sleeve  98  may be coupled to the second body  58  via the threaded interface  110  and the lip  112  of the outer sleeve  98  may engage the first body  56 , thereby maintaining the locked position  100 ). 
       FIG. 7  is a cross-sectional side view of an embodiment of a connector assembly  50  having a sliding outer sleeve  200  (e.g., annular sleeve) that may be utilized to join the first component  52  to the second component  54  of the mineral extraction system  10 . As noted above, the first component  52  and the second component  54  may be any of a variety of structures, including the wellhead hub  18 , the casing spool  26 , the tubing spool  24 , the tree  22 , the BOP  36 , or any of a variety of other components, such as spools, housings, adapters, or pipes that may be utilized with the wellhead  12  or other portions of the mineral extraction system  10 . 
     As shown, the connector assembly  50  includes the sliding outer sleeve  200  and a body  202  (e.g., annular body). In the illustrated embodiment, the body  202  contacts and circumferentially surrounds the first component  52 , and the sliding outer sleeve  200  contacts and circumferentially surrounds the body  202 . The body  202  supports a lock ring  204  (e.g., segmented ring or c-shaped ring) and one or more locking dog assemblies  206 . In  FIG. 7 , the connector assembly  50  is in a first position  210  (e.g., unlocked position). In the first position  210 , the lock ring  204  and/or the locking dog assemblies  206  are in an expanded position (e.g., radially-expanded position) in which the lock ring  204  and/or the locking dog assemblies  206  do not protrude radially inwardly beyond a radially-inner surface  212  of the body  202 , enable the body  202  may move relative to the first component  52 , and/or enable the lock ring  204  to receive the second component  54  (e.g., the connector assembly  50  can be moved axially to a position in which the lock ring  204  circumferentially surrounds the second component  54 ). 
     In certain embodiments, the lock ring  204  may be a segmented ring or c-shaped ring having a first circumferential end and a second circumferential end that define a space (e.g., a gap) at a circumferential location about the ring. Such a configuration enables radial adjustment of the lock ring  204 , as discussed in more detail below. As shown, a radially-inner surface  216  (e.g., annular surface) of the lock ring  204  includes multiple grooves or teeth  218  that are configured to engage corresponding teeth and grooves  220  formed in a radially-outer surface  222  (e.g., annular surface) of the second component  54 . However, it should be understood that the radially-inner surface  216  and the radially-outer surface  222  may have any of a variety of corresponding surfaces or features that facilitate coupling the lock ring  204  to the second component  54  (e.g., blocking relative axial movement).  FIG. 8  is a cross-sectional side view of the connector assembly  50  of  FIG. 7  with the lock ring  204  aligned with the corresponding teeth and grooves  220  of the second component  54 . When the corresponding teeth and grooves  218  of the lock ring  204  and the corresponding teeth and grooves  220  of the second component  54  are aligned, a contacting surface  224  (e.g., annular surface, axially-facing surface) of the first component  52  may contact a contacting surface  226  (e.g., annular surface, axially-facing surface) of the second component  54 , as shown. A seal  228  (e.g., o-ring or annular seal) may be positioned between the surfaces  224 ,  226  to block fluid flow from a bore  230  (e.g., central bore or fluid flow path) defined by the first component  52  and the second component  54 . 
       FIG. 9  is a cross-sectional side view of the connector assembly  50  of  FIGS. 7 and 8 , wherein the connector assembly  50  is in a second position  240  (e.g., locked position). In the second position  240 , the lock ring  204  is in a contracted position (e.g., radially-contracted position) in which the lock ring  204  contacts the second component  54 , engages the second component  54 , and/or blocks axial movement of the second component  54  relative to the lock ring  204  and/or the first component  52 , for example. 
     To achieve the second position  240 , a fluid (e.g., hydraulic fluid, liquid, or gas) may be provided to a sealed space  242  (e.g., annular space) defined between the sliding outer sleeve  200  and the body  202  along the radial axis  44 . The fluid may be provided via one or more ports  244  and corresponding passageways  246  extending through the body  202  of the connector assembly  50 , for example. When the fluid is provided to the sealed space  242 , the fluid pressure drives the sliding outer sleeve  200  axially, as shown by arrow  248 . As the sliding outer sleeve  200  moves relative to the body  202 , a tapered inner surface  250  (e.g., tapered annular surface or conical surface) of the sliding outer sleeve  200  moves along a corresponding tapered outer surface  252  (e.g., tapered annular surface or conical surface) of a push ring  254  (e.g., annular push ring) until a contacting surface  256  (e.g., radially-inner surface, annular surface) of the sliding outer sleeve  200  is positioned circumferentially about the push ring  254 , thereby driving the push ring  254  and the lock ring  204  radially inwardly to engage the corresponding grooves  220  of the second component  54 . 
       FIG. 10  is a cross-sectional side view of the connector assembly  50  of  FIGS. 7-9 , wherein the locking dog assemblies  206  of the connector assembly  50  engage the first component  52 . In operation, once the lock ring  204  engages the second component  54 , additional fluid may be provided to the sealed space  242  (e.g., via the one or more ports  244  and corresponding passageways  246 ), and the fluid pressure drives the sliding outer sleeve  200  axially, as shown by arrow  248 . As the sliding outer sleeve  200  moves relative to the body  202 , a tapered inner surface  260  (e.g., tapered annular surface or conical surface) of the sliding outer sleeve  200  moves along a corresponding tapered outer surface  262  (e.g., tapered annular surface or conical surface) of a push ring  264  (e.g., annular push ring) until a contacting surface  266  (e.g., radially-inner surface, annular surface) of the sliding outer sleeve  200  is positioned circumferentially about the push ring  264 , thereby driving the push ring  264  and a dog  268  (e.g., protrusion, key, bump, or the like) radially inwardly to engage a corresponding feature  270  (e.g., groove) of the first component  52 . As shown, a width  272  (e.g., along the radial axis  44 ) varies along a length  274  of the sliding outer sleeve  200 . This variation in width  272  enables the sliding outer sleeve  200  to include and/or support various features, such as the tapered outer surfaces  252 ,  260 , the sealed space  242 , and contacting surfaces  256 ,  266  that drive and hold both push rings  254 ,  264  radially inwardly, for example. Furthermore, in some embodiments, the geometry of the contacting surfaces  256 ,  266  and/or the interface between the contacting surfaces  256 ,  266  and the push rings  254 ,  264  (e.g., straight cylindrical contacting surfaces, axially-extending surfaces) may enable the sliding outer sleeve  200  to maintain the locked position  240  even after fluid pressure within the sealed space  242  is reduce or removed. 
       FIG. 11  is a cross-sectional side view of the connector assembly  50  of  FIGS. 7-10 , wherein the connector assembly  50  is disengaged from the first component  52  and the second component  54  and is in the first position  210 . The connector assembly  50  may return to the first position  210  by providing fluid to a sealed space  280  (e.g., annular space) defined between the sliding outer sleeve  200  and the body  202  along the radial axis  44 . A seal ring  281  (e.g., annular seal ring) may be provided to seal the sealed space  280 . The fluid may be provided via one or more ports  282  and corresponding passageways  284  extending through the body  202  of the connector assembly  50 , for example. When the fluid is provided to the sealed space  280 , the fluid pressure drives the sliding outer sleeve  200  axially, as shown by arrow  286 . As the sliding outer sleeve  200  moves axially, the contacting surface  256  of the sliding outer sleeve  200  may move to a position that is axially above the push ring  254 , thereby enabling the push ring  254  and the lock ring  204  to move radially outwardly to disengage from the corresponding groove  220  of the second component  54 . Similarly, as the sliding outer sleeve  200  moves axially, the contacting surface  266  of the sliding outer sleeve  200  may move to a position that is axially above the push ring  264 , thereby enabling the push ring  264  and the dogs  268  to move radially outwardly to disengage from the corresponding groove  270  of the first component  52 . Once the lock ring  204  is disengaged from the second component  54 , the second component  54  may be moved relative to and/or separated from the first component  52  and the connector assembly  50 . Once the dog assemblies  206  are disengaged from the first component  52 , the first component  52  may be moved relative to and/or separated from the connector assembly  50 . 
     With reference to  FIGS. 7-11 , it should be understood that in some embodiments, the connector assembly  50  may include an adapter body  290  (e.g., annular body) that is coupled (e.g., via one or more fasteners, such as bolts) to the first component  52  positioned at a first end  292  (e.g., proximal end) of the adapter body  290 . In such cases, the body  202  is positioned circumferentially about the adapter body  290  and coupled to the adapter body  290  (e.g., via a threaded interface, friction fit, fasteners, etc.), and the one or more dog assemblies  206  may engage the adapter body  290  to further support the connector assembly  50  and/or to energize the seal  228  as it joins the first component  52  to the second component  54 . 
       FIG. 12  is a cross-sectional side view of the connector assembly  50  having a stab  300  (e.g., annular extension) that may be utilized to join the first component  52  to the second component  54 . As noted above, the first component  52  and the second component  54  may be any of a variety of structures, including wellhead hub  18 , the casing spool  26 , the tubing spool  24 , the tree  22 , the BOP  36 , or any of a variety of other components, such as spools, housings, adapters, or pipes that may be utilized with the wellhead  12  or other portions of the mineral extraction system  10 . 
     As shown, the connector assembly  50  includes the sliding outer sleeve  200 , the body  202 , the lock ring  204 , and the one or more dog assemblies  206 , as well as other features discussed above with respect to  FIGS. 7-11 , for example. In the illustrated embodiment, the connector assembly  50  includes an adapter body  302  (e.g., annular body) that extends from a first end  304  (e.g., proximal end) to a second end  306  (e.g., distal end). The first component  52  is coupled to the first end  304  of the adapter body  302  and the stab  300  extends to the second end  306  of the adapter body  302 . The adapter body  302  may have a first width  308  proximate the first end  304  and a second width  310  proximate the second end  306  due to the stabs  300 . The second component  54  may be received into a space  312  (e.g., annular space) defined between the stab  300  and the lock ring  204  along the radial axis  44 . 
       FIG. 13  is a cross-sectional side view of the connector assembly  50  of  FIG. 12 , wherein the connector assembly  50  engages the first component  52  and the second component  54 . As shown, in the locked position  240 , an end  314  of the second component  54  is positioned between the stab  300  and the body  202  of the connector assembly  52  along the radial axis  44 . A seal  316  (e.g., o-ring or annular seal) is provided at the end  314  of the second component  54  and a seal  318  (e.g., o-ring or annular seal) is provided about a radially-outer surface  320  (e.g., annular surface) of the stab  300  to block fluid flow out of a bore  322  (e.g., central bore). In some embodiments, the stab  300  may protect the seal  316  from fluid within the bore  322 , thereby reducing wear on the seal  316  during certain operations (e.g., where the connector assembly  50  is used to join a frac tree assembly to a spool of the wellhead  12  for fracing operations). 
       FIG. 14  is a flow diagram of an embodiment of a method  350  for joining two components (e.g., the first component  52  and the second component  54 ) of the mineral extraction system  10  to one another using the connector assembly  50  illustrated in  FIGS. 7-13 . The method  250  includes various steps represented by blocks. It should be noted that some or all of the steps of the method  250  may be performed as an automated procedure by an automated system and/or some or all of the steps of the method  250  may be performed manually by an operator. Although the flow chart illustrates the steps in a certain sequence, it should be understood that the steps may be performed in any suitable order and certain steps may be carried out simultaneously, where appropriate. Further, certain steps or portions of the method  250  may be omitted and other steps may be added. 
     The method  250  may begin by coupling the connector assembly  50  to the first component  52 , in step  252 . In operation, the body  202  of the connector assembly  50  is positioned about the first component  52  and may be coupled to the first component  52  (e.g., via a threaded interface, friction fit, fasteners, etc.). As discussed above, in some embodiments, the connector assembly  50  may include the adapter  290  that is coupled to the first component  52  (e.g., via one or more threaded fasteners). 
     The lock ring  204  of the connector assembly  50  may then be aligned with the corresponding teeth and grooves  222  of the second component  54 , in step  254 . For example, the connector assembly  50  may be moved relative to the second component  54  until the lock ring  204  is axially aligned with the corresponding teeth and grooves  222  of the second component  54 . The fluid may then be provided to the sealed space  242 , which causes the sliding outer sleeve  200  to move axially, which in turn drives the push ring  254  and the lock ring  204  radially-inwardly to engage the corresponding grooves  222  of the second component  54 , as shown in step  256 . Additional fluid may then be provided to the sealed space  242 , which causes the sliding outer sleeve  200  to continue to move axially, which in turn drives the push ring  264  and the dogs  268  radially-inwardly to engage the corresponding grooves  270 , which may be formed in the first component  52  or the adapter body  290 , depending on the configuration. Thus, the first component  52  and the second component  54  may be joined to one another via the connector assembly  50 . 
     While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed. Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims. 
     The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical. Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ” or “step for [perform]ing [a function] . . . ”, it is intended that such elements are to be interpreted under 35 U.S.C. 112(f). However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. 112(f).