Patent Publication Number: US-2023132558-A1

Title: System and method for hanger and packoff lock ring actuation

Description:
BACKGROUND 
     1. Field of the Disclosure 
     The present disclosure relates to wellbore operations. Specifically, the present disclosure relates to systems and methods for engagement of wellbore components, such as metal-to-metal annulus packoffs and hangers. 
     2. Description of Related Art 
     Oil and gas operations may be conducted in a variety of operations, such as subsea or surface environments, where components are installed on a rig or sea floor. Systems used in oil and gas operations may be heavy, experience extreme temperature or pressure scenarios, and be challenging to move between locations. As a result, reducing the number of components utilized or reducing the number of “runs” or “trips” within a wellbore is desirable. Certain operations may use a series of tubulars that are positioned coaxially within a wellbore, where inner tubulars are “hung” or otherwise suspended from outer tubulars. Normally, these tubulars are separately installed and secured into position, which may increase a number of runs, and thereby, increase costs associated with the wellbore. Similar drawbacks are also present during removal of the components. 
     SUMMARY 
     Applicants recognized the problems noted above herein and conceived and developed embodiments of systems and methods, according to the present disclosure, for wellbore operations. 
     In an embodiment, a wellbore system includes a hanger lock energizing ring, a hanger lock ring, and a shoulder ring, wherein the shoulder ring supports at least a portion of the hanger lock ring on a shoulder. The wellbore system further includes a seal energizing ring coupled to the shoulder ring, the seal energizing ring being positioned axially lower than the shoulder. The wellbore system also includes a seal element associated with the seal energizing ring, the seal element being driven into an energized position by the seal energizing ring. The wellbore system further includes a seal lock energizing ring arranged axially lower than the shoulder ring, the seal lock energizing ring being driven to move via one or more extensions coupled to the seal lock energizing ring. The wellbore system includes a seal lock ring positioned axially lower than the shoulder ring, the seal lock ring being supported, at least in part, by the seal energizing ring. Both the hanger lock ring and the seal lock ring are set, substantially simultaneously, responsive to movement of the one or more extensions. 
     In another embodiment, a method includes landing at least a portion of a seal assembly on a hanger. The method also includes applying a first uphole force to a shoulder ring, the shoulder ring transferring at least a portion of the first uphole force to an upper seal energizing ring to drive the upper seal energizing ring in a downhole direction. The method further includes energizing an upper seal of a seal element via the upper seal energizing ring. The method includes energizing a lower seal of the seal element via a lower seal energizing ring. The method also includes applying a second uphole force to set a hanger lock energizing ring and a seal lock energizing ring. 
     In an embodiment, a seal assembly includes a seal element having an upper seal and a lower seal, the seal element being driven into an energized position via engagement of the upper seal and the lower seal by an upper seal energizing ring and a lower seal energizing ring. The seal assembly further includes a shoulder ring coupled to the upper seal energizing ring, the shoulder ring to transmit a downward force to at least the upper seal energizing ring to drive the upper seal energizing ring in a downward direction after at least a portion of the seal assembly is landed on a hanger. The seal assembly also includes a hanger lock ring positioned on a shoulder of the shoulder ring, the hanger lock ring being driven in a radially outward direction and into a wellhead housing responsive to movement in the downward direction by a hanger lock energizing ring. The seal assembly further includes a seal lock energizing ring coupled to the hanger lock energizing ring, the seal lock energizing ring being set simultaneously with the hanger lock ring. 
     In an embodiment, a wellbore system includes a hanger lock energizing ring, a hanger lock ring, and a shoulder ring, wherein the shoulder ring supports at least a portion of the hanger lock ring on a secondary shoulder and the hanger lock energizing ring coupled to one or more extensions. The wellbore system also includes a seal energizing ring coupled to the shoulder ring, the seal energizing ring being positioned axially lower than the secondary shoulder. The wellbore system further includes a seal element associated with the seal energizing ring, the seal element being driven into an energized position by the seal energizing ring. The wellbore system also includes a seal lock energizing ring arranged axially lower than the shoulder ring, the seal lock energizing ring being driven to move via the one or more extensions coupled to the seal lock energizing ring and the hanger lock energizing ring. The wellbore system further includes a seal lock ring positioned axially lower than the shoulder ring, the seal lock ring being supported, at least in part, by the seal energizing ring. Both the hanger lock ring and the seal lock ring are set, substantially simultaneously, responsive to movement of the one or more extensions. 
    
    
     
       BRIEF DESCRIPTION OF DRAWINGS 
       The foregoing aspects, features, and advantages of the present disclosure will be further appreciated when considered with reference to the following description of embodiments and accompanying drawings. In describing the embodiments of the disclosure illustrated in the appended drawings, specific terminology will be used for the sake of clarity. However, the disclosure is not intended to be limited to the specific terms used, and it is to be understood that each specific term includes equivalents that operate in a similar manner to accomplish a similar purpose. 
         FIG.  1    is a schematic side view of an embodiment of an offshore drilling operation, in accordance with embodiments of the present disclosure; 
         FIG.  2    is a cross-sectional view of an embodiment of a seal assembly, in accordance with embodiments of the present disclosure; 
         FIG.  3    is a perspective view of an embodiment of a seal assembly, in accordance with embodiments of the present disclosure; 
         FIG.  4    is a detailed cross-sectional view of an embodiment of an anti-rotation configuration, in accordance with embodiments of the present disclosure; 
         FIGS.  5 A- 5 D  are cross-sectional views of an embodiment of a setting sequence, in accordance with embodiments of the present disclosure; 
         FIGS.  6 A- 6 D  are cross-sectional views of an embodiment of a retrieval sequence, in accordance with embodiments of the present disclosure; 
         FIG.  7    is a flow chart of an embodiment of a method for setting a seal, in accordance with embodiments of the present disclosure; and 
         FIG.  8    is a flow chart of an embodiment of a method for retrieving a seal, in accordance with embodiments of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     The foregoing aspects, features, and advantages of the present disclosure will be further appreciated when considered with reference to the following description of embodiments and accompanying drawings. In describing the embodiments of the disclosure illustrated in the appended drawings, specific terminology will be used for the sake of clarity. However, the disclosure is not intended to be limited to the specific terms used, and it is to be understood that each specific term includes equivalents that operate in a similar manner to accomplish a similar purpose. 
     When introducing elements of various embodiments of the present disclosure, the articles “a”, “an”, “the”, and “said” are intended to mean that there are one or more of the elements. The terms “comprising”, “including”, and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements. Any examples of operating parameters and/or environmental conditions are not exclusive of other parameters/conditions of the disclosed embodiments. Additionally, it should be understood that references to “one embodiment”, “an embodiment”, “certain embodiments”, or “other embodiments” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. Furthermore, reference to terms such as “above”, “below”, “upper”, “lower”, “side”, “front”, “back”, or other terms regarding orientation or direction are made with reference to the illustrated embodiments and are not intended to be limiting or exclude other orientations or directions. It should be further appreciated that terms such as approximately or substantially may indicate +/−10 percent. 
     Embodiments of the present disclosure are directed toward systems and method for simultaneous or near-simultaneous actuation for engagement of an inner annulus packoff lock ring with a casing/tubing hanger and an outer hanger lock ring with a wellhead housing. In at least one embodiment, both upper and lower lock rings are actuated into engagement with a corresponding groove using one or more solid actuators, which may be coupled using load members which extend through a lock down carrier. Various embodiments simplify operational tooling and allow one or more seals to be locked down from above (e.g., from an uphole position), which improves debris tolerance and installation reliability. 
     Various embodiments are directed toward simultaneous or near-simultaneous locking of packoff and hanger lock rings in one stroke via one or more solid actuation rings for actuating and backing up the lock ring. In at least one embodiment, a pair of solid actuation rings are used (e.g., at top and bottom locations). In at least one embodiment, a lock down carrier serves as a primary load transferring body that allows a tool to set a seal. The tool applies a force to this body that sets the seal directly. In various embodiments, the lock down carrier houses one or more load transfer members, which may be an arrangement of bolts or extensions, that are contained in a series of corresponding holes that are formed through the lock down carrier body. These bolts or extensions may be threaded into a seal lock actuation ring (e.g., a solid ring seal lock actuation sleeve) that sets a seal lock down ring. In certain embodiments, the upper section of the shoulder bolts are housed and secured in a series of holes in the hanger lock actuation ring. In at least one embodiment, once the seal is set, a second function of the tool drives the hanger lock actuation sleeve down to drive the hanger lock ring out and into engagement with a wellhead housing. At the same time or substantially the same time, the shoulder bolts are driven down through the lock ring carrier. Because the seal lock actuation sleeve is fastened to the ends of these shoulder bolts, the seal lock ring is driven into engagement with the hanger neck. In at least one embodiment, the lock down carrier has a secondary load shoulder that allows the hanger lock down force to be transferred through the lock down carrier, into the hanger lock ring, and directly into the housing without going through the seal elements. The secondary load shoulder is thereby not the primary hanger neck shoulder and does not take any or a significant portion of the subsequent hanger weight from a hanger landed above or pressure end load from a test plug or other equipment that may land above the hanger. It should be appreciated that a variety of configurations may be utilized for the respective load shoulders in order to distribute forces within the wellbore. By way of example only, the secondary load shoulder may be arranged at an angle sloping downwards and away from a bore axis and, in contrast, the primary load shoulder may be arranged at an angle sloping downwards toward the bore axis. 
     Various embodiments overcome present challenges of locking a seal to hanger body at the same or substantially the same time as locking the hanger to the wellhead. As a result, embodiments may reduce a number of trips into the wellbore, thereby decreasing costs, among other benefits. In at least one embodiment, embodiments enable the annulus packoff to be set through the lockdown carrier directly, which may enable the lock rings to be energized on a separate tool function. Accordingly, the setting forces to set the seal are applied directly to the seal and not through a selective mechanism, like a shear ring. In this manner, the seal can be set directly through the lock down carrier and the lock rings are set with a separate tool function at substantially the same time. 
       FIG.  1    is a side schematic view of an embodiment of a subsea drilling operation  100 . It should be appreciated that one or more features have been removed for clarity with the present discussion and that removal or inclusion of certain features is not intended to be limited, but provided by way of example only. Furthermore, while the illustrated embodiment describes a subsea drilling operation, it should be appreciated that one or more similar processes may be utilized for surface applications and, in various embodiments, similar arrangements or substantially similar arrangements described herein may also be used in surface applications. The drilling operation includes a vessel  102  floating on a sea surface  104  substantially above a wellbore  106 . A wellbore housing  108  sits at the top of the wellbore  106  and is connected to a blowout preventer (BOP) assembly  110 , which may include shear rams  112 , sealing rams  114 , and/or an annular ram  116 . One purpose of the BOP assembly  110  is to help control pressure in the wellbore  106 . The BOP assembly  110  is connected to the vessel  102  by a riser  118 . During drilling operations, a drill string  120  passes from a rig  122  on the vessel  102 , through the riser  118 , through the BOP assembly  110 , through the wellhead housing  108 , and into the wellbore  106 . It should be appreciated that reference to the vessel  102  is for illustrative purposes only and that the vessel may be replaced with a floating platform or other structure. The lower end of the drill string  120  is attached to a drill bit  124  that extends the wellbore  106  as the drill string  120  turns. Additional features shown in  FIG.  1    include a mud pump  126  with mud lines  128  connecting the mud pump  126  to the BOP assembly  110 , and a mud return line  130  connecting the mud pump  126  to the vessel  102 . A remotely operated vehicle (ROV)  132  can be used to make adjustments to, repair, or replace equipment as necessary. Although a BOP assembly  110  is shown in the figures, the wellhead housing  104  could be attached to other well equipment as well, including, for example, a tree, a spool, a manifold, or another valve or completion assembly. 
     One efficient way to start drilling a wellbore  106  is through use of a suction pile  134 . Such a procedure is accomplished by attaching the wellhead housing  108  to the top of the suction pile  134  and lowering the suction pile  134  to a sea floor  136 . As interior chambers in the suction pile  134  are evacuated, the suction pile  134  is driven into the sea floor  136 , as shown in  FIG.  1   , until the suction pile  134  is substantially submerged in the sea floor  136  and the wellhead housing  108  is positioned at the sea floor  136  so that further drilling can commence. As the wellbore  106  is drilled, the walls of the wellbore are reinforced with concrete casings  138  that provide stability to the wellbore  106  and help to control pressure from the formation. It should be appreciated that this describes one example of a portion of a subsea drilling operation and may be omitted in various embodiments. In at least one embodiment, systems and methods of the present disclosure may be used for drilling operations that are completed through a BOP and wellhead, where a casing hanger and string are landed in succession. 
       FIG.  2    is a cross-sectional side view of an embodiment of a sealing system  200  (e.g., seal assembly). In at least one embodiment, the sealing system  200  may include one or more components associated with a hanger, a wellhead, and the like. It should be appreciated that the system  200  may include more or fewer components, and certain components have been eliminated for simplicity with the following discussion. In this example, a hanger lock energizing ring (E-ring)  202  is axially aligned with a shoulder ring  204  such that at least a portion of the hanger lock E-ring  202  overlaps at least a portion of the shoulder ring  204 . For example, at least part of an upper portion of the shoulder ring  204  may be overlapped by the hanger lock E-ring  202 . As such, at least part of an outer diameter of the shoulder ring  204  is smaller than at least part of an inner diameter of the hanger lock E-ring  202 . 
     In at least one embodiment, a hanger lock ring  206  is positioned circumferentially with respect to the shoulder ring  204  such that at least a portion of the hanger lock ring  206  is radially outward of at least a portion of the shoulder ring  204 , with respect to an assembly axis  208 . In operation, the assembly axis  208  is parallel to a wellbore axis, but it should be appreciated that certain components may bend or otherwise be positioned at an angle such that the assembly axis  208  is not always in a straight vertical position as shown in  FIG.  2   . The hanger lock ring  206  includes locking elements  210  that extend radially outward to form, at least in part, a lock ring recess  212  that may, in combination, form a hanger lock ring profile  214 . As will be described below, in various embodiments the hanger lock ring  206  may be driven in a radially outward direction, with respect to the assembly axis  208 , such that the hanger lock ring profile  214  engages a mating hanger profile. 
     Various embodiments include a hanger rock ring passage  216  and a shoulder ring passage  218  that enables an extension  220 , which is shown here as a shoulder bolt, to extend toward and couple to a seal lock energizing ring (E-ring)  222 . For example, in the illustrated configuration the extension  220  is coupled to a lip  224  of the hanger lock r-ring  202  and movement with respect to the lip may be blocked, for example via one or more fasteners  226 , such as a set screw. That is, a gap between the fasteners  226  and the extension  220  may enable predetermined movement or sliding of the extension  220 , but movement beyond a certain degree would be blocked by the fasteners  226 . The extension  220  is then positioned within the respective passages  216 ,  218  and coupled to the seal lock E-ring  222 , for example via one or more mating connections, such as threads. It should be appreciated that various embodiments may include different extension configurations, such as a solid or semi-solid piece, a piece that includes a circumferential span, or the like. Moreover, in at least one embodiment, different configurations may be provided for coupling the illustrated components together, such as one or more overlapping regions between the extension  220  and the hanger lock E-ring  202 , among other options. In at least one embodiment, a back face of the lock ring  206  includes one or more relief slots, which may be spaced circumferentially. These relief slots may have varying widths and be positioned to accommodate the extensions  220 . Accordingly, as the lock ring  206  expands, the relief slots enable expansion around the extensions  220  without interference. 
     In this example, the extension  220  extends from the hanger lock E-ring  202  and axially beyond an end of the shoulder ring  204 . That is, an end of the extension  220  is axially lower than an end of the shoulder ring  204 . It should be appreciated that, in various embodiments, the extension  220  may vary in length. Moreover, there may be multiple extensions where some extend at different lengths than others. As will be described in detail below, movement of the hanger lock E-ring  202  in an axially downward direction along the assembly axis  208  is transmitted to the extension  220 , which further drives the seal lock E-ring  222  in an axially downward direction. This movement will facilitate energizing both the lock rings simultaneously. 
     An upper seal E-ring  228  may be coupled to the shoulder ring  204 , for example using one or more fastening mechanisms  230  such as threads, fasteners, or the like. In various embodiments, the upper seal E-ring  228  is arranged below a shoulder  232  of the shoulder ring  204 , where the shoulder  232  is an extension that projects radially outward with respect to a body portion of the shoulder ring  204 . As illustrated, the shoulder  232  includes an uphole side  234  (e.g., a top side, an axially higher side) and a downhole side  236  (e.g., a bottom side, an axially lower side) where the hanger lock ring  206  is positioned on the uphole side  234  and the upper seal E-ring  228  is positioned to abut the downhole side  236 . It should be appreciated that while contact between the upper seal E-ring  228  and shoulder  232  is shown in  FIG.  2   , other embodiments may include a gap or intermediate component between the upper seal E-ring  228  and the shoulder  232 . 
     In the illustrated embodiment, the seal lock E-ring  222  is arranged circumferentially within the upper seal E-ring  228  in that at least portions of the upper seal E-ring  228  is positioned radially outward of the seal lock E-ring  222 , with respect to the assembly axis  208 . In at least one embodiment, a seal lock E-ring  222  position within the upper seal E-ring  228  is based, at least in part, on dimensions of one or more of the hanger lock E-ring  202 , the shoulder ring  204 , and/or the extension  220 . By way of example only, a longer (e.g., axially longer) shoulder ring  204  may change a position of the seal lock E-ring  222  with respect to the upper seal E-ring  228 . 
     Further illustrated is a shelf  238  extending radially inward from a body of the upper seal E-ring  228 . The illustrated shelf  238  is positioned axially lower than the seal lock E-ring  222  and is further separated from the fastening mechanism  230 . In various embodiments, a radial extent of the shelf  238  may be based, at least in part, on one or more additional component within the system, such as one or more tubulars or the illustrated seal lock ring  240 . For example, as shown in  FIG.  2   , the seal lock ring  240  may be positioned on the shelf  238  such that axial movement in a downward (e.g., downhole) direction is blocked by the shelf  238 . It should be appreciated that, in various embodiments, one or more dimensions of the shelf  238  and/or the seal lock ring  240  may be particularly selected such than an inner diameter at the shelf  238  is substantially equal to an inner diameter with respect to the seal lock ring  240 . As will be described below, in operation movement of the hanger lock E-ring  202  in a downward direction may also drive movement of the seal lock E-ring  222  in a downward direction, and once in a selected position, the seal lock ring  240  may be utilized to secure the seal lock E-ring  222  into position. 
     Continuing with the upper seal E-ring  228 , a groove is illustrated to receive one or more retainer segments  242 . The retainer segments  242  are positioned within the groove and extend radially inward, with respect to the assembly axis  208 , and may be utilized to position or otherwise retain a seal element  244 , which as described below may include both an upper seal and a lower seal. The illustrated retainer segments  242  may include a span (not shown) of a certain circumferential extent. That is, the retainer segments  242  may correspond to a plurality of segments  242 , where segments  242  may have equal or different circumferential extends. As will be described, segments  242  may be installed through one or more apertures formed within upper seal E-ring  228 . The retainer segments  242  support the seal element  244  along an edge  246  that contacts an overhang  248  of the seal element  244 . Accordingly, at least a portion of the retainer segments  242  are radially overlapped by the seal element  244 . It should be appreciated that, in at least one embodiment, one or more fasteners may be utilized to secure the seal element  244  to the upper seal E-ring  228  and/or to the retainer segments  242 . Furthermore, it should be appreciated that the retainer segments  242  may act as a passive restraint with respect to the seal element  244  such that the retainer segments  242  block movement of the seal element  244  in a downward (e.g., downhole) direction but permit movement in an upward (e.g., uphole) direction. Additionally, it should be appreciated that the movement between the seal element  244  and the retainer segments  242  may be driven by movement of the upper seal E-ring  228 , rather than movement of the seal element  244 . However, one or both of the components may move axially with respect to one another. In this example, the retainer segments  242  extend into a notch  250  formed, at least in part, by a reduced outer diameter portion axially below the overhang  248 . 
     In at least one embodiment, a space  252  is present between the shelf  238  and the overhang  248 . In at least one embodiment, the space  252  is substantially equivalent in length to a gap  254  between the retainer segments  242  and a bottom of the notch  250 . In operation, the space  252  and the gap  254  may, at least in part, restrict or otherwise define a movement length of one or more of the upper seal E-ring  228  and/or the seal element  244 . By way of example, the upper seal E-ring  228  may be driven in an axially downward direction such that a bottom of the shelf contacts the overhang  248  and/or such that the retainer segments  242  are moved to a bottom of the notch  250 . Such movement may serve to activate the seal element  244 . 
     The illustrated seal element  244  includes an upper opening  256  and a lower opening  258 , where the upper opening  256  receives an end  260  of the upper seal E-ring  222  and the lower opening  258  receives an end  262  of a lower seal E-ring  264 . In this example, the respective ends  260 ,  262  are shaped to have respective variable diameters such that a first end diameter  266 A,  266 B is smaller than a second end diameter  268 A,  268 B. Accordingly, as the respective ends  260 ,  262  are driven further into their associated openings  256 ,  258  the seal element  244  undergoes greater expansion to form the seal with the housing (not pictured) on the seal OD side. It should be appreciated that a seal is also formed on the seal ID side. By way of example, the ID side seals are energized by the interference between the seal element  244  and a hanger neck (not pictured). In at least one embodiment, movement of the seal element  244  past the straight hanger seal pocket forms the ID seal. 
     In a configuration that substantially mirrors at least a portion of the upper seal E-ring  222 , the lower seal E-ring  264  is associated with one or more retainer segments  242  that include respective edges  246  that interact with overhangs  248 . In contrast to the configuration described above, the position of the respective space  252  and gap  254  associated with the lower seal E-ring  264  may move in an axially upward direction and/or the seal element  244  may move an in axially downward direction, thereby reducing lengths of the spaces  252  and/or gap  254  as the lower seal E-ring  264  is driven into the lower opening  258 . 
     Further illustrated is a retainer ring  270  that is positioned axially lower, at least in part, than the seal element  244  and is positioned against a lower shoulder  272  of the lower seal E-ring  264 . In at least one embodiment, the retainer ring  270  is utilized to lock the lower seal E-ring  264  into place, for example by moving into a groove or slot formed within a hanger, among other options. In operation, the retainer ring  270  may further be deenergized to allow removal of the seal system  200 , for example retainer ring  270  may maintain a position of the lower seal E-ring  264  to prevent dragging the seal element  244  in an energized position during removal. 
     Embodiments of the present disclosure may also include a wiper o-ring  274 , which in this example is positioned axially below (e.g., downhole) of the retainer ring  270  and is positioned within a groove formed within at least a portion of the lower shoulder  272 . The wiper o-ring may be utilized to clean one or more surfaces, such as an outer diameter of a hanger neck, among other options. 
     As will be described below, various embodiments of the present disclosure may be utilized to set and retrieve the seal system  200  where one or more components are set and/or energized substantially simultaneously. By way of example, in a seal setting sequence, one or more portions of the seal assembly  200  may be landed on a hanger shoulder. For example, a back side of the lower shoulder  272  may be landed on a hanger shoulder, where the hanger is positioned within a wellbore that may, in certain embodiments, include a wellhead housing radially outward from and co-axial with the hanger. A running tool may be utilized to apply a force from an uphole direction (e.g., a downward force), where the force is applied to the shoulder ring  204 , either directly or via connections with one or more components, such that the force is transmitted to the upper seal E-ring  228 , which drives the end  260  into the upper opening  256 . As a portion of the seal element  244  is energized, load may continue to be applied until the lower seal E-ring  264  is driven into the lower opening  258 . Such a force will energize the seal element  244  and also engage the retainer ring  270 , for example within an opening or groove of the hanger. As force continues to be applied and/or a second force function on the tool is applied, the extensions  220  may be driven in a downward direction against the seal lock E-ring  222 , where the downward movement of the attached hanger lock E-ring  202  may drive the hanger lock ring  206  into mating grooves of the housing, while also activating the seal lock E-ring  222  and the seal lock ring  240 . In this manner, both the seal and hanger lock rings may be simultaneously or substantially simultaneously be energized. It should be appreciated that the order in which the upper and lower seals are set may be reversed such that the upper seal (e.g., the seal associated with the upper opening  256 ) is set second and the lower seal (e.g., the seal associated with the lower opening  258 ) is set first. Furthermore, in embodiments, both seals may be set simultaneously or substantially simultaneously. In at least one embodiments, the seals are set based on a friction balance between different sliding parts, and as a result, the ordering may vary based on one or more operational factors. 
     Various embodiments may further be drawn toward a seal retrieval sequence. In at least one embodiment, one or more retrieval faces may be utilized, where a tool may couple to at least one of the hanger lock ring E-ring  202  and/or the shoulder ring  204 . It should be appreciated that other retrieval interfaces may also be utilized in various embodiments. A force may be applied in an upward direction (e.g., an uphole force, a force toward a surface location, etc.) to disengage both lock rings  206 ,  240 . As the shoulder ring  204  is moved in an upward direction, the upper seal of the seal element  244  (e.g., the seal associated with the upper opening  256 ) is unenergized due to the movement of the end  260 . However, due to the location of the retainer ring  270 , the lower seal E-ring  264  associated with the lower seal (e.g., the seal associated with the lower opening  258 ) may be maintained at the landed elevation. As the upper seal E-ring  228  is moved in an upward direction, the retainer segments  242  may contact the associated overhang  248 , which may lead to deenergizing the lower seal and deenergizing the retainer ring  270 . As a result, the assembly  200  may then be removed after the seal element  244  is deenergized. 
       FIG.  3    is a perspective view of an embodiment of the seal system  200 . In at least one embodiment, the seal system  200  includes one or more annular components, such as the illustrated hanger lock E-ring  202 , hanger lock ring  206 , shoulder ring  204 , upper seal E-ring  228 , lower seal E-ring  264 , and seal element  244 , among other components. It should be appreciated that various components have variable outer diameter portions, as shown in  FIG.  3   , and that different dimensions may be particularly selected based on expected operating conditions, such as wellbore diameter, other associated components, and the like. 
     In this example, the extensions  220  are illustrated as individual components that are circumferentially positioned about the assembly axis  208 . For example, the extensions  220  may correspond to bolts or shoulder bolts that extend through the lock ring passage  216  and the shoulder ring passage  218  to couple to the seal lock r-ring  222 . In various embodiments, there are more or fewer extensions  220  than the number illustrated in  FIG.  3   , and it should be appreciated that a number of extensions  220  may be particularly selected based, at least in part, on one or more design conditions. Furthermore, it should be appreciated that the extensions  220  may not be individual bolts or components, but may be a single annular component. Additionally, in one or more embodiments, each of the extensions  220  may not have an equal circumferential extent and may, instead, have different sizes at different locations about the assembly axis  208 . That is, each of the extensions  220  may not be similarly sized. 
     As shown in  FIG.  3   , each of the upper seal E-ring  228  and the lower seal E-ring  264  include respective passages  300  to receive retainer segments  242 . The passages  300  may enable a retainer segment  242  to be installed within an outer diameter of the respective E-rings  228 ,  264 , be pushed or rotated circumferentially, and then have another retainer segment  242  be installed. Retainer segments  242  may be installed until an entire inner circumference is filled with retainer segments  242 . In various embodiments, there are multiple passages  300  and passages  300  may have different circumferential lengths, based, at least in part, on dimensions of the retainer segments  242 . In certain embodiments, one or more fasteners may be utilized to secure one or more retainer segments  242  into position. 
       FIG.  4    is a detailed cross sectional view of an embodiment of an anti-rotation configuration  400  that includes the hanger lock E-ring  202 , the shoulder ring  204 , and the hanger lock ring  206 . In this example, the hanger lock ring  206  is arranged along the uphole side  234  of the shoulder  232 . In one or more embodiment, an interface  402  between the hanger lock ring  206  and the uphole side  234  is particularly selected based, at least in part, on one or more expected operating conditions. In various embodiments, the angle of the interface  402  is selected to facilitate force transfer to drive the hanger lock ring  206  radially outward and into a mating profile  404  of a wellhead housing  406 . That is, the hanger lock ring profile  214  ( FIG.  2   ) may be driven outwardly to interact with the mating profile  404 . 
     In this embodiment, the hanger lock ring  206  is secured to the shoulder ring  204  via a pin  408 . The pin  408  extends through respective apertures  410 ,  412  formed through the hanger lock ring  206  and the shoulder ring  404 . In at least one embodiment, the pin  408  is positioned approximately 180-degrees from the lock ring split opening. In at least one embodiment, a plurality of pins  408  are used, which may be in a stacked configuration. In one or more embodiments, more than one pin may be aligned or stacked, but in this configuration, only a single pin is shown. In operation, the pin  408  may prevent rotation or torsion of the hanger lock ring  206 . For example, the pin  408  may block twisting during installation or during activation of the hanger lock E-ring  202 . As will be described below, a position of one or more of the hanger lock ring  206  and/or the shoulder ring  204  along a length  414  of the pin  408  may change during different phases of installation and removal. That is, as the hanger lock ring  206  is driven radially outward toward the wellhead housing  406 , the hanger lock ring  206  may slide along the length  414  of the pin. 
     In various embodiments, the hanger lock E-ring  202  may include one or more openings  416  positioned to align with the pin  408 . For example, the hanger lock E-ring  202  may receive a force from an uphole location and be driven in an axially downward direction, which may, at least in part, facilitate radially outward movement of the hanger lock ring  206 . Accordingly, one or more embodiments, a bottom end of the hanger lock E-ring  202  may move downward and toward the pin  408 . To prevent the pin  408  from blocking or restricting movement, the one or more openings  416  may enable passage of the pin  408  without restricting the axial movement of the hanger lock E-ring  202 . Furthermore, it should be appreciated that, in other embodiments, a length of the hanger lock E-ring  202  is particularly selected such that at full insertion of the hanger lock E-ring  202  the pin  408  is not contacted. 
       FIGS.  5 A- 5 D  are cross-sectional side views of embodiments of a seal setting sequence  500  in which  FIG.  5 A  represents the seal landing on the hanger,  FIG.  5 B  represents energizing the upper seal,  FIG.  5 C  represents energizing the lower seal, and  FIG.  5 D  represents energizing the lock rings, among other features. In this example, the seal assembly  200  is landed on a hanger  502 . The illustrated hanger  502  includes a hanger shoulder  504  that receives the lower seal E-ring  264 . As illustrated, this landing blocks further downward movement (e.g., movement into the wellbore) by the seal assembly  200 . In various embodiments, one or more tools may be utilized to position and land the seal assembly  200 , such as a running tool or the like. 
     The configuration of  FIG.  5 A  illustrates the seal element  244  in a non-energized position, in that the seal element  244  has not been energized via the E-rings  228 ,  264 . Furthermore, as shown in the illustrated embodiment, one or more components of the seal assembly are not aligned with or positioned to interact with a mating component, including at least the hanger lock ring  206  with respect to the wellbore housing  406 . In various embodiments, components may be particularly selected and dimensioned to facilitate the landing position shown in  FIG.  5 A , such as the position of the shoulder ring  204  with respect to the hanger  502 , and the like. 
       FIG.  5 B  illustrates energizing an upper seal  506  of the seal element  244  via the upper seal E-ring  228 . In operation, a running tool may apply a force (e.g., an uphole force) in a downward direction at one or more of the hanger lock E-ring  202  and/or the shoulder ring  204 , as shown by the arrow. The force may be translated through the shoulder ring  204  and directed toward the upper seal E-ring  228 , which is driven into the upper opening  256 , thereby expanding the upper seal  506 . 
     When comparing the position of various components in  FIGS.  5 A and  5 B , it can be seen that various features associated with the seal assembly  200  have moved axially downward. By way of example, the shoulder  232  of the upper seal E-ring  228  has transitioned to align with a groove  508  formed in the hanger  502 . Furthermore, the hanger lock ring  206  is now closer to the mating profile  404  of the wellhead housing  406 . As noted above, the connection via the pin  408  between the shoulder ring and the hanger lock ring  206  may, at least in part, facilitate the movement of the hanger lock ring  206 . 
       FIG.  5 C  illustrates energizing a lower seal  510  of the seal element  244  via the lower seal E-ring  264 . In this example, the downward force continues to be applied until both the lower seal  510  and the retainer ring  270  are engaged. In at least one embodiment, a positive stop at an upper hanger shoulder  512  (e.g., secondary shoulder) by the shoulder ring  204  will indicate the seal element  244  is fully engaged. That is, as shown in the transition between  FIGS.  5 A to  5 C , downward movement of the shoulder ring  204  continues until the upper hanger shoulder  512  is contacted. In at least one embodiment, at least a portion of a lock down force is transferred from the casing hanger  502  to the hanger lock ring  206 . 
     Further illustrated in  FIG.  5 C  is the activation of the lower seal  510  via movement of the lower seal E-ring  264  into the lower opening  258 . As noted above with respect to the upper seal  506 , the lower seal E-ring  264  expands the outer leg of the lower seal  510 , thereby setting the seal with the housing  406 . In this example, the ID seal with the hanger  502  is set by a nominal interference between the seal element  244  and the hanger neck. The ID seal is energized by moving the seal element  244  down relative to the hanger  204 . It should be appreciated that such sealing is present at both the upper and lower ID seals (e.g., seals associated with the upper seal  506  and the lower seal  510 ). In this example, the retainer ring  270  is positioned on the lower shoulder  272 , and as a result of the movement of the seal element  244  (as shown by the different locations in  FIGS.  5 B and  5 C ), the retainer ring  270  is driven into a lower groove  514 . The retainer ring  270  may maintain a position of the lower seal E-ring  264  during removal of the seal, as will be described below. 
       FIG.  5 D  illustrates energizing both the seal and hanger lock rings  240 ,  206 . In this example, a second function of the tool provides a downward force that drives movement of the hanger lock E-ring  202  in a downward direction, which applies, at least in part, an outward radial force to the hanger lock ring  206  via a slanted interface  516  between the hanger lock ring  206  and the hanger lock E-ring  202 . It should be appreciated that various embodiments may include separate tool functions for applying a force. Moreover, embodiments may further enable a continuous application of force. Accordingly, the hanger lock ring profile  214  may mate with the mating profile  404  of the wellhead housing  406 . At substantially the same time, in various embodiments, the downward movement also drives the extensions  220  with the seal lock E-ring  222 , which is applied to the seal lock ring  240 , driving the seal lock ring  240  into the groove  508 . Accordingly, the seal can be set and wellbore operations may take place. 
       FIGS.  6 A- 6 D  are cross-sectional side views of embodiments of a seal retrieval sequence  600  in which  FIG.  6 A  represents engagement of a retrieval tool,  FIG.  6 B  represents deenergizing lock rings,  FIG.  6 C  represents deenergizing an upper seal, and  FIG.  6 D  represents deenergizing a lower seal and retainer ring, among other features. In this example one or more retrieval tools are engaged, for example along the hanger lock ring E-ring  202  and/or the shoulder ring  204  to apply an upward force (e.g., in an uphole direction) to retrieve the hanger lock E-ring  202 , where may facilitate disengagement of the lock rings  206 ,  240 . In at least one embodiment, the upward force applied to the shoulder ring  204  deenergizes the upper seal  506  by removing the upper seal E-ring  228 , due to a connection to the shoulder ring  204 . However, as shown, the lower seal  510  remains engaged due to the position of the retainer ring  270 . Continued application of forces will deenergize the lower seal  510  and the retainer ring  270 , thereby enabling retrieval in a single piece. 
       FIG.  6 A  illustrates the seal assembly  200  in a set position, such as the position from  FIG.  5 D . In this example, one or more features include respective retrieval interfaces  602 ,  604  such as the interface along the hanger lock E-ring  202  and the shoulder ring  204 . The interface  602  may include one or more overhanging features or other engagement mechanisms that may enable a retrieval tool to engage the hanger lock E-ring  202 . In contrast, the illustrated embodiment includes threads at the retrieval interface  604 , but it should be appreciated that one or both of the interfaces  602 ,  604  may include threads. In operation, a tool may be tripped into the wellbore to engage the interface  602 ,  602  to facilitate removal. 
       FIG.  6 B  illustrates the hanger lock ring  206  being moved out of engagement with the wellhead housing  406 , such that the profile  214  and the mating profile  404  are no longer engaged. As will be appreciated the upward movement of the hanger lock E-ring  202  removes the force at the slanted interface  516 , thereby enabling the hanger lock ring  206  to move radially inward and away from the wellhead housing  406 . 
     Furthermore, the upward movement of the hanger lock ring  206  also drives upward movement of the extensions  220 , which are coupled to the seal lock E-ring  222 . Accordingly, removal of the downward force also disengages the seal lock ring  240  such that the seal lock ring  240  transitions out of the groove  508 . 
       FIG.  6 C  illustrates the upper seal  506  being deenergized due to the upward movement of the upper seal E-ring  228 , which is coupled to the shoulder ring  204 . As shown when looking at a position of the shoulder ring  204  in  FIGS.  6 B and  6 C , the shoulder ring  204  in  FIG.  6 C  is no longer seated on the hanger shoulder  504  and has been transitioned in an uphole direction. Accordingly, the end  260  is moved out of the opening  256 . During this movement, the retainer segment  242 A is also driven upward along the gap  254 A to engage the overhang  248 A. This engagement will apply an upward force to the seal element  244  to deenergize the lower seal  510 , as shown in  FIG.  6 D . As shown, the retainer ring  270  keeps the lower seal E-ring  264  in place, thereby avoiding dragging the seal in the energized position. Instead, the upward force applied to the seal element  244  deenergizes the lower seal  510 , which moves the retainer ring  270  out of the lower groove  514 . Furthermore, the retainer segments  242 B shown to transition along the gap  254 B to engage the overhang  248 B, which translates a force to the lower seal E-ring  264  and enables retrieval of the seal assembly  200 . 
       FIG.  7    is a flow chart of an embodiment of a method  700  for setting a seal. It should be appreciated for this method, and all methods described herein, that there may be more or fewer steps. Moreover, the steps may be conducted in a different order, or in parallel, unless otherwise specifically stated. In this example, at least a portion of a seal assembly is landed on a hanger  702 . By way of example, and as shown in at least  FIG.  5 A , one or more portions may be landed on a shoulder or stop point of a hanger. In at least one embodiment, a downward force (e.g., a first downward first associated with a first function of the tool) is applied to the seal assembly, such as to one or more E-rings  704 . The downward force may be transmitted to one or more seal E-rings, which may energize an upper seal. Continued application of the downward force may also cause a lower seal to energize  706 . In at least one embodiment, a downward force (e.g., a second downward force associated with a second function of the tool) may transition one or more lock rings into an energized position at substantially the same time  708 . 
       FIG.  8    is a flow chart of an embodiment of a method  800  for disengaging and/or retrieving a seal. In this example, one or more retrieval interfaces are engaged  802 , for example using a downhole tool that may engage locking features or mechanical fasteners. In at least one embodiment, an upward force (e.g., a first upward force associated with a first function of the tool) is applied to deenergize an upper seal  804 , such as an upward force to transition an E-ring out of an opening in a seal element. In various embodiments, the upward force is further applied  806 , which may deenergize a lower seal. In at least one embodiment, an upward force (e.g., a second upward force associated with a second function of the tool) may be applied to transition a retainer ring out of a groove or other locking features. As a result, the seal assembly may be retrieved from the wellbore  808 . 
     The foregoing disclosure and description of the disclosed embodiments is illustrative and explanatory of the embodiments of the invention. Various changes in the details of the illustrated embodiments can be made within the scope of the appended claims without departing from the true spirit of the disclosure. The embodiments of the present disclosure should only be limited by the following claims and their legal equivalents.