Patent Publication Number: US-10767435-B2

Title: Slip hanger assembly

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application claims benefit of U.S. Provisional Application No. 62/534,044 filed Jul. 18, 2017, entitled “SLIP HANGER ASSEMBLY SYSTEM AND METHOD,” which is incorporated by reference in its entirety. 
    
    
     BACKGROUND 
     1. Field of Invention 
     This disclosure relates in general to wellhead assemblies, and in particular, to a hanger for supporting a tubular member within a wellhead assembly. 
     2. Description of the Prior Art 
     When drilling and completing subterranean wells, such as wells used for hydrocarbon production, successive joints of tubular members are run into the well through a wellhead. The successive joints of tubular members can be connected together with collars. Collars generally have a larger outer diameter than the outer diameter of the tubular members. There can be times when the tubular members become stuck and cannot move upwards or downwards. In such a situation, the tubular member may not be able to be supported by the wellhead by the planned or existing support mechanism and a backup or emergency support for the tubular member is installed. 
     Current methods for providing such backup or emergency support can include cutting off the tubular member within the outer well member and installing slips over an end of the tubular member that can land on a support shoulder in the outer well member and grip the tubular member. After cutting the tubular member, the tubular member can remain suspended within the outer well member without being secured or supported, providing a possibility of the tubular member falling within the outer well member and causing potential damage to the well, creating a possible safety and environmental risk, and requiring time and money to retrieve the fallen tubular member. 
     If the tubular member is not cut, a collar may be located along the tubular member above the support shoulder. The slips used in this instance will have a sufficiently large inner diameter to pass by such a collar and still be able to grip the tubular member having a smaller outer diameter. Some current slip hangers used to pass over a collar are expandable. However when the expandable slip hanger and slips contract to grip the tubular member, there is a gap between the outer diameter of the slip hanger and the inner diameter of the outer well member. As such, the slip hanger can move radially outward and the slips can potentially lose their grip on the tubular member. 
     SUMMARY 
     Applicant recognized the problems noted above herein and conceived and developed embodiments of systems and methods, according to the present disclosure, for slip hanger assemblies. 
     In an embodiment, a system for installing a slip hanger assembly in a wellbore includes a slip bowl comprising a stepped inner profile and an aperture extending from an outer diameter of the slip bowl to the stepped inner profile. The system also includes a slip coupled to the slip bowl, the slip having a mating external profile and being arranged against the stepped inner profile, the slip further comprising teeth on an inner face and a slot for receiving a shear pin extending through the aperture. The system further includes a running tool coupled to the slip bowl. The system includes a housing coupled to the running tool, the housing including a cylinder for receiving a reciprocating piston, the piston being movable between a first position and a second position, wherein the slip is in stored position while the piston is in the first position and an engaged position when the piston is in the second position. 
     In an embodiment, a system for installing a downhole tool onto a wellbore tubular includes a winch arranged at a surface location, the winch including a cable controllable via movement of the winch. The system also includes a blow out preventer coupled to a wellbore and a slip hanger assembly. The slip hanger assembly is coupled to the winch via the cable and installed through the blow out preventer and includes a housing, the housing having a cylinder that contains a piston. The slip hanger assembly also includes a running tool coupled to the housing. The slip hanger assembly further includes a slip bowl coupled to the running tool via a releasable coupling, wherein activation of the piston at a first predetermined force releases the running tool from the slip bowl. The slip hanger assembly includes a plurality of slips arranged within and releasably coupled to the slip bowl, wherein activation of the piston at a second predetermined force releases the plurality of slips from the slip bowl to engage the wellbore tubular at an outer diameter of the wellbore tubular. 
     In a further embodiment, a method for installing a downhole tool into a wellbore includes releasably coupling a slip to a slip bowl, the slip bowl being arranged on a slip hanger assembly including a piston arrangement for releasing the slips from the slip bowl at a first predetermined force and for releasing the slip bowl from the slip hanger assembly at a second predetermined force. The method also includes coupling the slip hanger assembly to a surface conveyance system, the surface conveyance system controlling a descent rate of the slip hanger assembly into the wellbore. The method further includes positioning the slip hanger assembly into the wellbore through a blow out preventer arranged at a surface location. The method also includes landing the slip hanger assembly onto a wellbore tubular. The method includes activating the piston arrangement at the first predetermined force to release the slip from the slip bowl, the slip biting into an outer diameter of the wellbore tubular via teeth. The method also includes activating the piston arrangement at the second predetermined force to release the slip bowl from the slip hanger assembly. The method includes removing the slip hanger assembly from the wellbore while the slip bowl remains coupled to the wellbore tubular via the slips. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The present technology will be better understood on reading the following detailed description of non-limiting embodiments thereof, and on examining the accompanying drawings, in which: 
         FIG. 1  is a schematic cross-sectional view of an embodiment of a drilling system, in accordance with embodiments of the present disclosure; 
         FIG. 2  is a perspective view of an embodiment of a slip hanger assembly, in accordance with embodiments of the present disclosure; 
         FIG. 3  is a cross-sectional view of the slip hanger assembly of  FIG. 1 , in accordance with embodiments of the present disclosure; 
         FIG. 4  is a detailed cross-sectional view of the slip hanger assembly of  FIG. 1 , in accordance with embodiments of the present disclosure; 
         FIG. 5  is a detailed cross-sectional view of a slip of the slip hanger assembly of  FIG. 1 , in accordance with embodiments of the present disclosure; 
         FIG. 6  is a detailed cross-sectional view of a conveyance assembly arranged on the slip hanger assembly of  FIG. 1 , in accordance with embodiments of the present disclosure; 
         FIG. 7  is a detailed cross-sectional view of an embodiment of a coupling of the slip hanger assembly of  FIG. 1 , in accordance with embodiments of the present disclosure; 
         FIG. 8  is a cross-sectional view of a slip hanger assembly, in accordance with embodiments of the present disclosure; 
         FIG. 9  is a detailed cross-sectional view of an embodiment of a slip of the slip hanger assembly of  FIG. 1 , in accordance with embodiments of the present disclosure; 
         FIG. 10  is a schematic view of an embodiment of a winch and skid, in accordance with embodiments of the present disclosure; 
         FIG. 11  is a schematic cross-sectional view of an embodiment of a slip hanger assembly, in accordance with embodiments of the present disclosure; 
         FIG. 12  is a detailed cross-sectional view of the slip hanger assembly of  FIG. 10 , in accordance with embodiments of the present disclosure; 
         FIG. 13  is a detailed cross-sectional view of the slip hanger assembly of  FIG. 10 , in accordance with embodiments of the present disclosure; 
         FIG. 14  is a detailed cross-sectional view of the slip hanger assembly of  FIG. 10 , in accordance with embodiments of the present disclosure; 
         FIG. 15  is a detailed cross-sectional view of the slip hanger assembly of  FIG. 10 , in accordance with embodiments of the present disclosure; 
         FIG. 16  is a detailed cross-sectional view of the slip hanger assembly of  FIG. 10 , in accordance with embodiments of the present disclosure; 
         FIG. 17  is a detailed cross-sectional view of the slip hanger assembly of  FIG. 10  and a dummy hanger, in accordance with embodiments of the present disclosure; and 
         FIG. 18  is a flow chart of an embodiment of a method for installing a slip hanger assembly, in accordance with embodiments of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
     The foregoing aspects, features and advantages of the present technology will be further appreciated when considered with reference to the following description of preferred embodiments and accompanying drawings, wherein like reference numerals represent like elements. In describing the preferred embodiments of the technology illustrated in the appended drawings, specific terminology will be used for the sake of clarity. The present technology, however, 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 invention, 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 invention 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 are made with reference to the illustrated embodiments and are not intended to be limiting or exclude other orientations. 
     Embodiments of the present disclosure include a slip hanger assembly that may be installed through a blow out preventer (BOP) while including an inner diameter that is larger than an outer diameter of a collar, thereby enabling installation of the slip hanger assembly over a collar coupling two tubular segments together. In various embodiments, the slip hanger assembly includes a housing having an annular piston arranged therein, the annular piston driving slips stored in a slip bowl from a stored position to an engaged position. In the engaged position, the slips grip a tubular segment, such as a casing segment or production tubing, and secure the slip bowl to the tubular segment. As a result, additional downhole tools may be lowered into the wellbore and landed on the slip bowl, which enables continued downhole operations. In various embodiments, the slip hanger assembly further includes a running tool coupled between the housing and the slip bowl. In various embodiments, the piston is configured to shear one or more pins coupling the running tool to the slip bowl to enable removal of the housing and running tool from the wellbore while the slip bowl remains coupled to the tubular. In various embodiments, different pressures applied by the piston may enable different operations in the downhole environment. For example, at a first pressure, one or more pins coupling the slips to the slip bowl may be sheared to transition the slips between the stored position and the engaged position. At a second pressure, for example, the slips may be further engaged and tested. At a third pressure, one or more pins coupling the running tool to the slip bowl may be sheared. In various embodiments, the first, second, and third pressures are different, with subsequent pressures being greater than previous ones. In operation, the slip hanger assembly may include a conveyance system that enables the slip hanger assembly to be lowered into the wellbore from a surface location. For example, the conveyance system may include one or more pulleys coupled to pulleys of a winch at the surface via a rope, wire, cable, or the like. The slip hanger assembly may be lowered and positioned in the wellbore through the BOP at the surface, which reduces the number of components that are removed at the surface location to install the slip hanger assembly. Accordingly, the slip hanger assembly may be deployed faster and more economically than other methods. 
       FIG. 1  is a schematic side view of an embodiment of a downhole drilling system  10  (e.g., drilling system) that includes a rig  12  and a production string  14  coupled to the rig  12 . In the illustrated embodiment, production string  14  extends into a wellbore  16  having an annulus  18  between a sidewall  20  of the wellbore  16  and the production string  14 . While the illustrated wellbore  16  is not cased, it should be appreciated that, in various embodiments, the wellbore  16  may including casing along at least a portion of the wellbore  16 . 
     In various embodiments, the production string  14  is formed from joints or segments  22  of tubulars (e.g., pipe) coupled together. In certain embodiments, the segments  22  may be threaded together or coupled together via one or more collars  24 . As described above, in various embodiments the production string  14  may become stuck within the wellbore  16 , for example due to reduced diameter portions of the wellbore  16 , deviated sections of the wellbore  16 , or the like. Various embodiments of the present disclosure describe a slip hanger system for supporting sections of the production string  14  that may be cut or otherwise separated due to being stuck within the wellbore  14 . However, it should be appreciated that while various embodiments may be discussed with reference to production strings  14 , that systems and methods of the present disclosure may be utilized with any downhole tubulars, such as sections of casing and the like. Furthermore, it should be appreciated that various components of the drilling system  10  have been removed for clarity with the present disclosure. For example, the drilling system  10  may include a blow out preventer (BOP) coupled to a wellhead assembly. 
       FIG. 2  is a front perspective view of an embodiment of a slip hanger assembly  30  that may be utilized with embodiments of the present disclosure. The illustrated embodiment includes the segment  22  having the collar  24  arranged at an upper end thereof. The slip hanger assembly  30  is arranged over the collar  24 . That is, the slip hanger assembly  30  is a larger outer diameter  32  than an outer diameter  34  of the collar  24 . In various embodiments, the outer diameter  32  is particularly selected to be smaller than an inner diameter of the BOP and, as a result, the slip hanger assembly  30  may be installed through the BOP, thereby reducing the removal of components at the surface. As will be described below, in various embodiments one or more conveyance systems  36 , such as the illustrated pulleys, may be used to lower the slip hanger assembly  30  into the wellbore  16 . 
     In the illustrated embodiment, the slip hanger assembly  30  includes a housing  38 , a running tool  40 , and a slip bowl  42 . The housing  38  is positioned at a top of the slip hanger assembly  30  and includes one or more mounting regions for the conveyance system  36 . The housing  38  may have a length that is particularly selected based on the applications. For example, it may be desirable to have a longer housing  38  to increase the weight of the slip hanger assembly  30 . A heavier slip hanger assembly  30  may be advantageous in maintaining a taught cable or rope as the slip hanger assembly  30  is lowered into the wellbore  16 . Furthermore, in various embodiments, the increased weight may provide stability and security as the slip hanger assembly  30  is landed on a load shoulder. In various embodiments, the running tool  40  is arranged axially below the housing  38 , followed by the slip bowl  42  axially below the running tool  40  at a bottom of the slip hanger assembly  30 . In the illustrated embodiment, the slip bowl  42  includes apertures  44  arranged circumferentially about the annual body of the slip bowl  42 . The apertures  44  may receive one or more shear pins, which as will be described below, may be used to set the slip hanger assembly  30  into position to grip the collar  24 . In operation, setting slips arranged within the slip bowl  42  may decouple the running tool  40  from the slip bowl  42  and enable removal of the housing  38  and the running tool  40 . 
       FIG. 3  is a schematic cross-sectional view of an embodiment of the slip hanger assembly  30  arranged over the collar  24 . As described above, the collar  24  is coupled to an outer diameter of the segment  22 . In various embodiments, the segment  22  originally coupled to the top of the collar  24  may be cut or removed. In operation, the slip hanger assembly  30  may be lowered into the wellbore  16  via the conveyance system  36  and arranged along the outer diameter  34  of the collar  24 . As illustrated, an inner diameter  50  of the slip hanger assembly  30  is larger than the outer diameter  34 , thereby enabling the installation of the slip hanger assembly  30 . 
     As shown in  FIG. 3 , the outer diameter  34  of the collar  24  is larger than an outer diameter  52  of the segment  22 . The stepped profile at the transition between the collar  24  and the segment  22  poses a challenge for installation of the slip hanger assembly  30 , as the change in diameters  34 ,  52  may be difficult to seal against. As will be described below, embodiments of the present disclosure enable installation of the slip hanger assembly  30 , even with the stepped profile. Furthermore, in various embodiments, the slip hanger assembly  30  is sized such that installation is performed without removing several components at the surface, for example, without removing the BOP. 
     The illustrated conveyance system  36  includes pulleys coupled to a top of the housing  38 . In various embodiments, the conveyance system  36  may further include ropes or cables to control a descent rate of the slip hanger assembly  30 . For example, as will be described below, in various embodiments a winch may be arranged at the surface to gradually lower the slip hanger assembly  30  into the wellbore  16 . In the illustrated embodiment, the conveyance system  36  is coupled to the housing  38  via pins or fasteners, but it should be appreciated that other coupling means may be used, such as adhesives, clips, and the like. 
     The illustrated embodiment further includes ports  54  that may introduce a fluid to drive an annular piston  56  arranged radially inward from the housing  38 . That is, the piston  56  is radially closer to a longitudinal axis  58  of the slip hanger assembly  30 . The piston  56  extends along the axis  58  such that the piston  56  extends beyond the housing  38  toward a bottom  60  of the slip hanger assembly  30 . In the illustrated embodiment, the piston  56  is radially inward of the running tool  40  and further extends towards slips  62  arranged within the slip bowl  42 . As will be described below, in operation the piston  56  is activated, for example by hydraulic pressure, to shear one or more shear pins to transfer the slips  62  from the illustrated stored position to a deployed position (not shown). In various embodiments, one or more seals may be positioned to regulate operation of the piston and maintain substantially fluid tight barriers between different portions of the slip hanger assembly. Furthermore, in various embodiments, the piston  56  may also shear one or more pins coupling the running tool  40  to the slip bowl  42 . 
     In various embodiments, the running tool  40  is coupled to the housing  38  and, in various embodiments, at least a portion of its outer diameter is substantially equal to an outer diameter of the housing  38 . As illustrated, the running tool  40  is further coupled to the slip bowl  42 , for example via one or more pins or couplings. In operation, movement of the piston  56  to a predetermined position or with a predetermined force/pressure may shear the pins couplings to disengage the slip bowl  42  from the running tool  40 , which allows the running tool  40  to be removed from the wellbore  16  along with the housing  38 . The pins may be arranged circumferentially about the slip hanger assembly  30 . For example, there may be six total shear pins, or three pairs of two. It should be appreciated that any number of shear pins may be used. The shear pins may have a capacity of approximately 8000 pounds each 
     The embodiment illustrated in  FIG. 3  further illustrates the slip bowl  42  which includes radially inward slips  62 . In operation, the slips  62  are driven from the illustrated stored position to a deployed position to engage the collar  24  and/or segment  22 . The slip bowl  42  includes a profile  64  that substantially matches a profile  66  of the slips  62 . The profile  64  facilitates driving the slips  62  radially inwardly against the collar  24  to secure the slips  62  to the collar  24  and/or segment  22 . The slips  62  may be arranged within the slip bowl  42  and include a set of teeth  68  on an inner face  70  closest to the collar  24 . The inner face  70  may be opposite the profile  66 . In certain embodiments, there may be slips  62  arranged circumferentially about the slip hanger assembly  30 . For example, there may be ten total slips  62 . 
     In various embodiments, the slip bowl  42  includes one or more apertures  72  extending toward the slips  62 . The apertures  72  may receive pins that, upon activation of the piston  56  to a predetermined location, may shear to release the slips  62  from the slip bowl  42 . In certain embodiments, the pins have a capacity of approximately 900 pounds. As the piston  56  is activated, the piston  56  moves in a downward direction toward the slip  62  and drives the slip  62  downward to shear the shear pin and move the slip  62  to the engaged position (not pictured). Accordingly, the slips  62  may move into engagement with the smaller diameter tubular  22  and/or collar  24  to grip the tubular  22  and/or collar  24 . The illustrated slip  62  also includes a snap ring  74  positioned on the rear end by the teeth  68 . The snap ring  74  is utilized to control the activation of the slips  62  such that each slip  62  activates at approximately the same time, thereby securely engaging the tubular  22  without tilt or sway. 
       FIG. 4  is a detailed cross-sectional view of an embodiment of the piston  56  arranged proximate the slips  62  in the slip bowl  42 . The illustrated slips  62  are in the stored position because the piston  56  has not been activated. Furthermore, the above described stepped profile between the collar  24  and the segment  22  is illustrated in  FIG. 4 . As will be illustrated herein, movement of the slips  62  may extend beyond the collar  24  to engage the segment  22 . 
     The illustrated piston  56  is arranged within a cylinder  80  and includes an extension  82  extending radially outward from the axis  58 . The extension includes a seal  84  that bears against a wall of the cylinder  80  to block fluid passage between the extension  82  and the cylinder wall, thereby driving movement of the piston  56 . Furthermore, a second seal  84  is arranged uphole from the extension  82  and uphole of the cylinder  80 . It should be appreciated that a variety of seals may be utilized with embodiments of the present disclosure to provide particularly selected fluid isolation for driving movement of the piston  56 . 
     The embodiment further illustrates a coupling  86  including pins  88  between the running tool  40  and the slip bowl  42 . The coupling includes a block  90  having openings  92  for receiving the pins  88 . In operation, movement of the piston  56  drives the running tool  40  downward and against the block  90 . The block  90  then applies pressure to the pins  88 , shearing the pins to enable removal of the running tool  40  while the slip bowl  42  remains within the wellbore  16 . 
       FIG. 4  also illustrates a shear pin  94  extending through the aperture  72  to secure the slip  62  to the slip bowl  42 . Moreover, the snap ring  74  is illustrated on the inner face proximate the teeth  68 . As described above, in operation a lower portion  96  of the piston  56  applies a force to the slip  62 , which shears the shear pin  94  and drives the slip  62  in a downward direction to engage the segment  22 . 
       FIG. 5  is a detailed cross-sectional view of an embodiment of the shear pin  94  coupling the slip  62  to the slip bowl  42 . It should be appreciated that the length of the shear pin  94  is shown for illustrate purposes only, and that in various embodiments, the shear pin  94  may be longer or shorter. Furthermore, a diameter of the shear pin  94  may be particularly selected based on a desired breaking force. In the illustrated embodiment, the shear pin  94  is arranged within the aperture  72  at an angle  100  relative to the axis  58 . The angle  100  may be particularly selected to increase or reduce the force used to shear the shear pin  94 . 
       FIG. 6  is a detailed cross-sectional view of an embodiment of the conveyance system  36  arranged on the housing  38 . The illustrated conveyance system  36  is a pulley, which may be referred to as a block pulley. The conveyance system  36  includes a fastener  102 , such as a bolt, for coupling to the housing  38 . In operation, wire rope or cable is arranged around the sheave of the pulley, which may be free to rotate about an axis, to support the slip hanger assembly  30  as it is lowered into the wellhead. Additionally, the block pulley may be utilized to remove the housing  38  and running tool  40  from the wellbore  16  after the slips  62  are set in the engaged position. 
       FIG. 7  is a detailed cross-sectional view of an embodiment of the coupling  86  used for connecting the running tool  40  to the slip bowl  42 . As described above, in various embodiments the coupling includes pins  88  extending through the running tool  40  and the slip bowl  42 . As shown, the pins  88  are separate from one another, however a single pin may be used, for example that is arranged at an angle to extend between both the running tool  40  and the slip bowl  42 . The block  90  includes openings  92  for receiving the pins  88 . The pins  88  couple the running tool  40  to the slip bowl  42  until the piston  56  is activated and supplies sufficient force to break the pins  88  and decouple the running tool  40  from the slip bowl  42 . For example, in various embodiments the running tool  40  may move in the downward direction such that a gap  110  is removed between the running tool and the block  90 . Accordingly, the force from the running tool  40 , which it receives from the piston  56 , is transferred to the block  90  and subsequently the pins  88 . It should be appreciated that a length of the pins  88  may be longer than illustrated in  FIG. 7 . Moreover, the pins  88  may not be the same size. 
       FIG. 8  is a cross-sectional view of an embodiment of the slip hanger assembly  30  coupled to the segment  22  via the slips  62 . In the illustrated embodiment, the piston  56  has moved in a downward direction  112  to drive the slips  62  into an engaged position. As shown, the profile  64  of the slip bowl  42  and the profile  66  of the slips  62  are no longer proximate one another as the slips are moved downward and radially inward. In various embodiments, the force supplied by the piston  56  is particularly selected to shear the shear pin  94 , but not the pins  88 . As a result, different levels of forces may be utilized to activate different portions of the setting and release process of the slip hanger assembly  30 . In the illustrated engaged position, the slips  62  dig into the tubular  22  via the teeth  68 . 
       FIG. 9  is a detailed cross-sectional view of an embodiment of the slip  62  in the engaged position. In the illustrated embodiment, the gap  110  in the coupling  86  is arranged to enable the block  90  to shear the pins  88  and facilitate removal of the housing  38  and the running tool  40  from the wellbore  16  upon activation of the piston  56 , for example at a predetermined pressure. In various embodiments, the force of the piston  56  may be different in terms of shearing the pins  88  and the shear pin  94 . For example, the force to shear the pins  88  may be greater than the force to shear the shear pin  94 . Accordingly, the slips  62  may be set before shearing the pins  88 , thereby providing options to the operator to either leave the slip hanger assembly  30  within the wellbore  16  or conduct other operations prior to removing the slip hanger assembly  30 . 
     Engaging the slips  62  eliminates the gap between the slip  62  and the tubular  22  shown in  FIG. 4 . The teeth  68  on the rear end of the slip  62  dig into the tubular  22  to form a secure fitting. In the illustrated embodiment, the slip bowl  42  does not move with the slip  62 . The friction between the tubular  22  and the teeth  68  of the slip  62  maintain a position of the slip  62  even after the running tool  40  is removed, thereby enabling further wellbore operations. Moreover, because the housing  38  and running tool  40  may be removed while the slip bowl  42  and slip  62  remain downhole, the housing  38  and running tool  40  may be reused in different downhole operations. 
       FIG. 10  is a schematic elevational view of an embodiment of a winch  120  arranged on a skid  122  for installing the slip hanger assembly  30  within the wellbore  16 . It should be appreciated that, for clarity, features have been removed from  FIG. 10 . For example, the wellhead assembly and associated components, such as the BOP, are not illustrated. However, as described above, in various embodiments the components of the slip hanger assembly  30  are particularly selected to facilitate installation through the BOP so as to reduce the amount of equipment removed or modified at the surface. 
     The illustrated embodiment includes a plurality of pulleys  124  which may be utilized in combination with a cable or rope  126  for installation and removal of the slip hanger assembly  30 . In the illustrated embodiment, a first pulley  124 A is arranged farther from the wellbore  16  than a second pulley  124 B and a third pulley  124 C. Furthermore, the first pulley  124 A is larger than the second and third pulleys  124 B,  124 C. It should be appreciated that the location, number, and size of the pulleys  124  may be particularly selected based on the operational parameters at the well site. 
     The cable  126  is threaded around the pulleys  124  and coupled to the slip hanger assembly  30  to enable installation and removal of the slid hanger assembly  30  from the wellhead  16 . It should be appreciated that the winch  120  may not be mounted on the skid  122 . For example, individual pulleys  124  may be positioned at the wellhead based on the operating conditions at the wellhead. Moreover, in certain embodiments, the winch  120  may include various instrumentation systems, motors, controllers, and the like to control installation and removal of the slip hanger assembly  30 . For example, the motor and instrumentation systems may monitor a descent rate of the slip hanger assembly  30  and the controller may be utilized to send instructions to the motor to increase or decrease the rate. 
     Embodiments of the present disclosure may be assembled at an off-site shop or at the well site. That is, the slips  62  may be positioned within the slip bowl  42  and coupled to the running tool  40  and housing  38  at a variety of locations, thereby increasing the flexibility and usability of the slip hanger assembly  30 . Furthermore, in various embodiments, different components may be assembled at different locations. For example, the slip bowl  42  may be assembled to include the slips  62  at an off-site location and be shipped to the well site. At the wellsite, the slip bowl  42  may be coupled to the running tool  40  if needed. Accordingly, shipping may be easier since smaller, lighter components may be transported and stored at the well site and used when needed. 
       FIG. 11  is a cross-sectional view of an embodiment of the slip hanger assembly  30  in which the piston  56  is arranged at a higher vertical position relative to the running tool  40 . As a result, a bottom portion of the piston  56  (e.g., a portion which contacts the slips  62  to drive movement of the slips  62 ) is not aligned with the pins  88  and/or the coupling  86 , in the illustrated embodiment. Accordingly, the pins  88  are readily accessible without dismantling the tool. In other words, the position of the piston  56  does not interfere with providing access to the pins  88  in the illustrated embodiment. 
     The embodiment illustrated in  FIG. 11  further differs from the embodiment illustrated in  FIG. 2  in that a length of the housing  38  is increased. As described above, the longer housing  38  increases the weight of the tool to assist with driving the tool into position, for example, by maintaining tightness in the cable  126  as the slip hanger assembly  30  is installed within the wellbore  16 . 
     Further illustrated in  FIG. 11  are guides  140  coupled to the slip bowl  42 . In various embodiments, the guides  140  may be referred to as centralizers. The illustrated guides  140  include an elongated body  142  that extends downwardly and has a tapered end  144 . In various embodiments, the tapered end  144  may be substantially symmetrical, as illustrated in  FIG. 11 , or in other embodiments the tapered end  144  may not be symmetrical. The tapered end  144  may facilitate alignment with the collar  24  and/or the segment  22 . For example, if the slip hanger assembly  30  where not substantially aligned with the collar  24 , the tapered end  144  may contact the collar  24  and drive the slip hanger assembly  30  into alignment with the collar  24 . Furthermore, in certain embodiments, the wellbore  16  and/or casing of the wellbore  16  may be offset or include variances regarding diameter. The guides  140  enable the slip hanger assembly  30  to pass through regions having the variances to assist with engagement of the tubular. 
       FIGS. 12-17  are cross-sectional views of the slips  62  transferring from the stored position to an engaged position via a force applied by the piston  56 .  FIG. 12  illustrates the slips  62  stored within the slip bowl  42  and retained via the shear pin  94 . The illustrated shear pin  94  is arranged at the angle  100 , however it should be appreciated that the shear pin  94  may be in different orientations in other embodiments. As shown, the gap  110  is arranged within the coupling  86 , which will be closed as the piston  56  moves in the downward direction to drive the slips  62  toward the engaged position. In the embodiment illustrated in  FIG. 12 , the piston  56  is arranged at the top of the cylinder  80 . That is, the extension  82  is arranged such that the piston  56  is at a top of its stroke.  FIG. 13  illustrates the beginning of the transition from the stored position to the engaged position, for example via the introduction of fluid into the cylinder  80  via one or more ports  54 . As shown, the extension  82  of the piston  56  has moved in the downward direction. The movement has not closed the gap  110 , in the illustrated embodiment, but has transitioned the bottom  96  of the piston  56  into contact with the slips  62 . 
     Continuing to  FIG. 14 , further movement of the piston  56  in the downward direction  112  is illustrated as the extension  82  travels through the cylinder  80 . The slips  62  illustrated in  FIG. 14  have disengaged the profile  64  of the slip bowl  42  and being to transition in the downward direction due to the force of the piston  56 . As shown, the shear pin  94  has broken to enable movement of the slips  62 . As the slips  62  move in the downward direction, they also move inwardly such that the teeth  68  engage the segment  22 . Turning to  FIG. 15 , as the piston  56  continues to move in the downward direction, the gap  110  is eliminated due to movement of the running tool  40 . As a result, the block  90  of the coupling  86  bears against the pins  88 , which breaks the pins  88  to decouple the running tool  40  from the slip bowl  42 . As illustrated, such movement of the piston  56  continues to drive the slips  62  against the segment  22 .  FIG. 16  illustrates the slip bowl  42  coupled to the tubular  22  via the slips  62  with the running tool  40  and the housing  38  removed, for example via the conveyance system  36 . The tubular  22 , in the illustrated embodiment, is cut to enable attachment of other wellbore equipment, such as, for example, dummy hangers and the like.  FIG. 17  illustrates a dummy hanger  150  that is landed on the slip hanger assembly  30 . As a result, further wellbore operations may commence. In the illustrated embodiment, at least a portion of the weight of the dummy hanger  150  is supported by the slip bowl  42 . 
     Embodiments of the present disclosure may be utilized with a variety of drilling and/or production systems. For example, in embodiments where a top drive is utilized to drill a well, the top drive may be removed from a casing while the tubular  22  is held with slips or tongs. The slip hanger assembly  30  may then be positioned over the casing. Subsequently, the casing is held using the top drive. Next, the cable may be threaded through the various pulleys  124  of the winch  120  and the slip hanger assembly  30 . Then, the tool may be lowered into the wellhead using the cable. For example, the winch  120  may include a controller on one or more of the pulleys  124  to control the rate of descent of the slip hanger assembly  30 . 
     In various embodiments, the slip hanger assembly  30  may be installed within the wellbore  16  and then the piston  56  may be activated in order to set the slips  62 . It should be appreciated that, in various embodiments, different loads may be applied in order to perform different actions in the wellbore  16 . In various embodiments, a location to position the slip hanger assembly  30  is tagged and a neutral load is positioned on the conveyance system  36  when the slip hanger assembly  30  is landed on a load shoulder. Next, the slip hanger assembly  30  is activated. For example, the piston may apply approximately 250 pounds per square inch (e.g., approximately 10,600 pounds) to shear the shear pins  94  holding the slips  62 . Thereafter, the slips  62  travel a distance, for example, approximately 1.35 inches to make up with an outer diameter of the segment  22  (which, as described above, may be production tubing, a casing, or the like). Then, the pressure is increased to approximately 500 pounds per square inch (e.g., approximately 20,600 pounds) to ensure a positive bite is made up with the teeth  68  of the slip  62 . Additionally, the segment  22  may be partially released to test the bite between the teeth  68  and the segment  22 . Subsequently, the pressure may be further increased to approximately 1225 pounds per square inch (e.g., 51,900 pounds) to shear the pins  88  between the running tool  40  and the slip bowl  42 . Then, the running tool  40  may be retrieved from the wellbore  16  via the cable  126  and the winch  120 . Subsequent operations in the wellhead  16  may be performed after the slips  62  are set. For example, in certain embodiments, the slip supported casing may be cut to a specific elevation to leave the landing surface for a dummy hanger assembly, an internal seal, and an external seal. 
       FIG. 18  is a flow chart of an embodiment of a method  160 . It should be appreciated that for methods described herein that the steps may be performed in any order, or in parallel, unless otherwise stated. Moreover, there may be more or fewer steps. In various embodiments, the slips  62  are coupled to the slip bowl  42  (block  162 ). As noted above, the slips  62  may be coupled to the slip bowl  42  at the well site or prior to delivery to the well site. The method also includes coupling the slip bowl  42  to the running tool  40  (block  164 ). For example, in various embodiments the coupling  86  is utilized such that the block  90  extends between the slip bowl  42  and the running tool  40  and includes pins  88  within openings  92 . The slip hanger assembly  30  is lowered into the wellbore  16  (block  166 ), for example via cables  126  coupled to the winch  120 . In various embodiments, the slip hanger assembly  30  is landed within the wellbore  16 , for example on a load shoulder or other structure within the wellbore  16  (block  168 ). 
     Once the slip hanger assembly  30  is positioned within the wellbore  16 , the piston  56  may be activated to shear the shear pin  94  coupling the slips  62  to the slip bowl  42  (block  170 ). In certain embodiments, the shear pin  94  is particularly selected such that a first pressure is utilized to shear the shear pin  94 , but does not shear other pins of the assembly  30 , such as the pins  88 . Shearing the shear pin  94  releases the slips  62 , which may be driven downwardly and inwardly to grip the tubular  22  via teeth  68 . The slips  62  may be tested at a second pressure (block  172 ). For example, the pressure acting on the piston  62  may be increased to further set the slips  62  and to determine whether the slips  62  have set. Furthermore, in various embodiments, the segment  22  may be partially released to test the bite between the teeth  68  and the segment  22 . The bite of the teeth  68  may be evaluated (block  174 ) to determine whether the bite is secure. If not, the slips  62  may be reset (block  176 ). If the slips  62  are secure, the piston  56  may be activated at a third pressure to shear the pins  88  coupling the running tool  40  to the slip bowl  42 . When the pins  88  are sheared, the running tool  40  may be removed from the wellbore (block  178 ) while the slip bowl  42  remains coupled to the tubular  22 . Thereafter, additional downhole tools may be landed on the slip bowl  42  (block  180 ) to continue wellbore operations. 
     Although the technology herein has been described with reference to particular embodiments, it is to be understood that these embodiments are merely illustrative of the principles and applications of the present technology. It is therefore to be understood that numerous modifications may be made to the illustrative embodiments and that other arrangements may be devised without departing from the spirit and scope of the present technology as defined by the appended claims.