WO2020010307A1

WO2020010307A1 - Tie down screw for a wellhead assembly

Info

Publication number: WO2020010307A1
Application number: PCT/US2019/040686
Authority: WO
Inventors: Weng Chun Isaac KAM; Su Tuan TAN; Li Yeung Melvyn HO; Chee Hoo LUM; Shuang Yong CHEAH
Original assignee: Cameron International Corporation; Cameron Technologies Limited
Priority date: 2018-07-06
Filing date: 2019-07-05
Publication date: 2020-01-09

Abstract

A mineral extraction system includes a wellhead assembly configured to be disposed into a wellbore and a tie down screw configured to be disposed at least partially into a component of the wellhead assembly. The tie down screw is configured to extend radially outward from the component of the wellhead assembly and the wellhead assembly is configured to pass through an opening of a rotary table when the tie down screw is disposed at least partially into the component of the wellhead assembly.

Description

TIE DOWN SCREW FOR A WELLHEAD ASSEMBLY

CROSS-REFERENCE TO RELATED APPLICATION

[0001] This application claims the benefit of U.S. Provisional Application No. 62/694,714, filed on July 6, 2018, the entirety of which is incorporated herein by reference.

BACKGROUND

[0002] This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.

[0003] As will be appreciated, oil and natural gas have a profound effect on modern economies and societies. Indeed, devices and systems that depend on oil and natural gas are ubiquitous. For instance, oil and natural gas are used for fuel in a wide variety of vehicles, such as cars, airplanes, boats, and the like. Further, oil and natural gas are frequently used to heat homes during winter, to generate electricity, and to manufacture an astonishing array of everyday products.

[0004] In order to meet the demand for such natural resources, companies often invest significant amounts of time and money in searching for and extracting oil, natural gas, and other subterranean resources (e.g., coal) from the earth. Particularly, once a desired resource is discovered below the surface of the earth, drilling and production systems are often employed to access and extract the resource. These systems may be located onshore or offshore, depending on the location of a desired resource. Further, such systems generally include a wellhead assembly through which the resource is extracted. These wellhead assemblies may include a wide variety of components, such as various casings, hangers, valves, fluid conduits, and the like, that control drilling and/or extraction operations. In some drilling and production systems wellhead assemblies may be utilized to secure a hanger or casing string in place within the wellbore and/or otherwise actuate seals of the hanger. Unfortunately, existing wellhead assemblies may not fit through an opening of a rotary table, such that the rotary table is removed during drilling or production operations to enable the wellhead assembly to be disposed into and/or extracted from the wellbore. As such, the drilling or extraction process may be time-consuming and lead to increased costs.

BRIEF DESCRIPTION OF THE DRAWINGS

[0005] Various features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein:

[0006] FIG. 1 is a block diagram that illustrates a mineral extraction system, in accordance with an embodiment of the present disclosure;

[0007] FIG. 2 is a perspective view of an embodiment of a wellhead assembly of the mineral extraction system of FIG. 1 , in accordance with an embodiment of the present disclosure;

[0008] FIG. 3 is a cross section of an embodiment of the wellhead assembly extending through an opening of a rotary table, in accordance with an embodiment of the present disclosure;

[0009] FIG. 4 is a partial cross section of an embodiment of a tie down screw for the wellhead assembly, in accordance with an embodiment of the present disclosure; and

[0010] FIG. 5 is a flowchart of a process for disposing the wellhead assembly into a wellbore of the mineral extraction system, in accordance with an embodiment of the present disclosure. DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS

[0011] One or more specific embodiments of the present disclosure will be described below. These described embodiments are only exemplary of the present disclosure. Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers’ specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another. Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.

[0012] 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. Moreover, the use of “top,”“bottom,” “above,”“below,” and variations of these terms is made for convenience, but does not require any particular orientation of the components.

[0013] As set forth above, existing mineral extraction systems may utilize wellhead assemblies to secure various components within the wellbore and/or actuate seals or other devices of the components. In certain embodiments, tie down screws protrude from the wellhead assembly. Unfortunately, the protruding tie down screws (e.g., lock screws) increase a diameter of the wellhead assembly, such that the wellhead assembly cannot fit through a rotary table that is present at a surface of a drilling rig or disposed in the wellbore. Alternatively, the wellhead assembly may include a recessed tie down screw that reduces a diameter of the wellhead system. Unfortunately, the recessed tie down screws do not enable an operator to verify that the tie down screws are fully engaged with another component of the wellhead system. In other words, the recessed tie down screws do not provide a visual indication to the operator to determine a position of the tie down screws within the wellhead assembly. Therefore, the operator may not verify that the tie down screws are in a proper position to secure a component within the wellbore and/or to actuate a device of the component.

[0014] Embodiments of the present disclosure are directed to an enhanced tie down screw for a wellhead assembly that enables the wellhead assembly to fit through the rotary table of the mineral extraction system, as well as to provide a visual indicator to the operator as to a position of the tie down screw within a body of the wellhead assembly. As used herein, a tie down screw refers to a sealing and securement feature of the wellhead assembly that is configured to secure a tubing hanger or other components within the wellbore, as well as provide one or more seals that are resistant to relatively high pressures within the wellbore. Further, the tie down screws of the present disclosure may be utilized to actuate devices of components of the wellhead assembly. As discussed in detail herein, the tie down screws enable the wellhead assembly to fit through the rotary table as well as provide a visual indication of a position of the tie down screw. For instance, a portion of the tie down screw that protrudes beyond the body of the wellhead assembly may visually indicate that the tie down screw is in a fully engaged position, a partially engaged position, or a disengaged (e.g., fully retracted) position. Accordingly, the tie down screws may facilitate the drilling process by eliminating removal of the rotary table to install various components in the wellbore, such as a hanger or a casing. Additionally, the drilling process may be further facilitated by providing the operator with an indication of a position of the tie down screw within the body of the wellhead assembly.

[0015] Turning now to the drawings, FIG. 1 is a block diagram that illustrates an embodiment of a mineral extraction system 10 (e.g., hydrocarbon extraction system). The illustrated mineral extraction system 10 can be configured to extract various minerals and natural resources, including hydrocarbons (e.g., oil and/or natural gas), or configured to inject substances into the earth. In some embodiments, the mineral extraction system 10 is land-based (e.g., a surface system) or subsea (e.g., a subsea system). As illustrated, the system 10 includes a wellhead assembly 12 coupled to a mineral deposit 14 via a well 16, where the well 16 includes a wellhead hub 18 and a wellbore 20. The wellhead hub 18 generally includes a large diameter hub that is disposed at the termination of the wellbore 20. The wellhead hub 18 provides for the connection of the wellhead assembly 12 to the well 16.

[0016] The wellhead assembly 12 typically includes multiple components that control and regulate activities and conditions associated with the well 16. For example, the wellhead assembly 12 generally includes bodies, valves and seals that route produced minerals from the mineral deposit 14, provide for regulating pressure in the well 16, and provides for the injection of chemicals or fluids into the wellbore 20 (e.g., down-hole), such as during a fracturing process. In the illustrated embodiment, the wellhead assembly 12 includes what is colloquially referred to as a Christmas tree 22 (hereinafter, a tree), a tubing spool 24, a casing spool 25, and a hanger 26 (e.g., a tubing hanger or a casing hanger). The system 10 may include other devices that are coupled to the wellhead assembly 12, and devices that are used to assemble and control various components of the wellhead assembly 12. For example, in the illustrated embodiment, the system 10 includes a tool 28 suspended from a drill string 30. In certain embodiments, the tool 28 includes a running tool that is lowered (e.g., run) from an offshore vessel to the well 16 and/or the wellhead assembly 12. In other embodiments, such as surface systems, the tool 28 may include a device suspended over and/or lowered into the wellhead assembly 12 via a crane or other supporting device. Additionally, the mineral extraction system 10 includes a rotary table 29 configured to rotate during a drilling process to facilitate production of the wellbore 20.

[0017] The tree 22 generally includes a variety of flow paths (e.g., bores), valves, fittings, and controls for operating the well 16. For instance, the tree 22 may include a frame that is disposed about a tree body, a flow-loop, actuators, and valves. Further, the tree 22 may provide fluid communication with the well 16. For example, the tree 22 includes a tree bore 32. The tree bore 32 provides for completion and workover procedures, such as the insertion of tools (e.g., the hanger 26) into the well 16, the injection of various chemicals into the well 16 (e.g., down-hole), and the like. Further, minerals extracted from the well 16 (e.g., oil and natural gas) may be regulated and routed via the tree 22. For instance, the tree 12 may be coupled to a jumper or a flowline that is tied back to other components, such as a manifold. Accordingly, produced minerals flow from the well 16 to the manifold via the wellhead assembly 12 and/or the tree 22 before being routed to shipping or storage facilities. A blowout preventer (BOP) 31 may also be included, either as a part of the tree 22 or as a separate device. The BOP may consist of a variety of valves, fittings and controls to prevent oil, gas, or other fluid from exiting the well in the event of an unintentional release of pressure or an overpressure condition.

[0018] The tubing spool 24 provides a base for the tree 22. The tubing spool 24 is one of many components in a modular subsea or surface mineral extraction system 10 that is run from an offshore vessel or surface system. The tubing spool 24 includes a tubing spool bore 34. The tubing spool bore 34 connects (e.g., enables fluid communication between) the tree bore 32 and the well 16. Thus, the tubing spool bore 34 may provide access to the wellbore 20 for various completion and worker procedures. For example, components can be run down to the wellhead assembly 12 and disposed in the tubing spool bore 34 to seal-off the wellbore 20, to inject chemicals down-hole, to suspend tools down-hole, to retrieve tools down-hole, and the like.

[0019] The wellbore 20 generally contains elevated pressures. For example, the wellbore 20 may include pressures that exceed 10,000 pounds per square inch (PSI), that exceed 15,000 PSI, and/or that even exceed 20,000 PSI. Accordingly, the mineral extraction system 10 employs various mechanisms, such as seals, plugs and valves, to control and regulate the well 16. For example, plugs and valves are employed to regulate the flow and pressures of fluids in various bores and channels throughout the mineral extraction system 10. For instance, the illustrated hanger 26 (e.g., tubing hanger or casing hanger) is disposed within the wellhead assembly 12 to secure tubing and casing suspended in the wellbore 20, and to provide a path for hydraulic control fluid, chemical injections, and the like. The hanger 26 includes a hanger bore 38 that extends through the center of the hanger 26, and that is in fluid communication with the tubing spool bore 34 and the wellbore 20. The tubing hanger 26 may be suspended in the tubing spool 24 or the casing spool 36 via one or more tie down screws that insert through the spool 24 or 36 and engage the tubing hanger 26.

[0020] In some embodiments, the various components of the mineral extraction system 10 may be secured to one another via the tie down screws described above. For example, FIG. 2 is a perspective view of at least a portion of the wellhead assembly 12 having tie down screws 40 in accordance with an embodiment of the present disclosure. The wellhead assembly 12 includes the tubing spool 24, which may be coupled to other components of the wellhead assembly 12, such as a tree or blowout preventer, by an adapter flange 42. It will be appreciated that a variety of additional components may be coupled to the tubing spool 24 to facilitate production from the well 16.

[0021] As shown in the illustrated embodiment of FIG. 2, the tie down screws 40 may extend into a body 44 of the tubing spool 24 and engage components disposed within the tubing spool bore 34 and/or otherwise within the wellhead assembly 12. Each of the tie down screws 40 may include a first portion 46 (e.g., an outer portion or a gland portion) and a second portion 48 (e.g., an inner portion or a lock screw portion). As discussed in detail herein, a length (e.g., a first length) of the first portion 46 and a length (e.g., a second length) of the second portion 48 of the tie down screws 40 may be reduced to enable the wellhead assembly 12 to extend through an opening of the rotary table 29 (see e.g., FIGS. 1 and 3). As such, the wellhead assembly 12 may facilitate installation of various components throughout a drilling process and/or an extraction process of the mineral extraction system 10.

[0022] Despite the reduction in length of the first portion 46 and the second portion 48 of the tie down screws 40, the tie down screw 40 may remain visible when in a fully engaged position (e.g., the tie down screw 40 does not completely extend into an opening of the wellhead assembly 12). In other words, the tie down screw 40 protrudes from the body 44 of the tubing spool 24 in the fully engaged position. As such, an operator may determine whether the tie down screw 40 is in an appropriate position based on a distance 50 between an end 52 of the tie down screw 40 and a surface 54 of the body 44 of the tubing spool 24. In some embodiments, the distance 50 between the end 52 of the tie down screw 40 and the surface 54 of the body 44 of the tubing spool 24 may be relative to a thickness 55 of the tubing spool 24 or another component of the wellhead assembly 12. For example, the distance 50 may be between 50% and 300%, between 60% and 200%, or between 75% and 150% of the thickness 55 of the tubing spool 24 or another component of the wellhead assembly 12. In some embodiments, the surface 54 of the body 44 are milled or otherwise machined to be substantially flat (e.g., linear). Machining the surface 54 may facilitate determining the distance between the end 52 of the tie down screw 40 and the surface 54 by providing a planar surface that is substantially parallel to the end 52 of the tie down screw 40. Accordingly, an operator may quickly assess whether the tie down screw 40 is in an appropriate position by determining the distance between the end 52 of the tie down screw 40 and the surface 54, thereby facilitating the drilling process.

[0023] FIG. 3 is a cross-sectional view of the wellhead assembly 12 having the tie down screws 40. As shown in the illustrated embodiment of FIG. 3, the wellhead assembly 12 is disposed within an opening 60 of the rotary table 29. As should be understood, the rotary table 29 may include a drive that is configured to rotate a drill string during the drilling process of the wellbore 20. In existing mineral extraction systems, the rotary table 29 may be removed when inserting and/or installing components within, or removing components from, the wellhead assembly 12, such as the hanger 26 and/or the casing spool 25. Embodiments of the present disclosure are directed to the tie down screws 40 having a reduced length to enable the wellhead assembly 12 to pass through the rotary table 29, thereby avoiding removal of the rotary table 29 when installing various other components of the mineral extraction system 10.

[0024] For example, a total length 62 of the tie down screws 40 enables the wellhead assembly 12 to fit within a diameter 64 of the opening 60. In other words, a diameter 66 of the wellhead assembly 12 is less than the diameter 64 of the opening 60. In some embodiments, the diameter 66 of the wellhead assembly 12 is less than the diameter 64 of the opening 60 by an amount that is between 0.5 centimeter (cm) and 10 cm, between 0.75 cm and 5 cm, or between 1 cm and 2 cm. In other embodiments the diameter 64 of the opening 60 is approximately (e.g., within 10% of, within 5% of, or within 1 % of) 1.27 cm greater than the diameter 66 of the wellhead assembly 12. The diameter 64 of the opening 60 may be between 50 cm and 100 cm, between 60 cm and 75 cm, or between 65 cm and 70 cm. The diameter 66 of the wellhead assembly 12 may be any suitable value that is less than the diameter 64 of the opening 60. In some embodiments, the diameter 66 of the wellhead assembly 12 may be between 1 percent (%) and 10 %, between 2% and 8%, or between 3% and 6% of the diameter 64 of the opening 60. In any case, the diameter 66 is less than the diameter 64 by a sufficient amount to enable the wellhead assembly 12 to pass through the opening 60 of the rotary table 29 when the tie down screws 40 are disposed within the body 44 of the tubing spool 24 and extend radially outward from the surface 54 of the body 44 of the tubing spool 24.

[0025] In accordance with embodiments of the present disclosure, the tie down screws 40 may be configured to extend radially outward from the body 44 of the tubing spool 24 at varying distances depending on a position of the tie down screws 40 and whether the tie down screws 40 are securing a component (e.g., the hanger 26) of the wellhead assembly 12 and/or energizing or engaging a component of the wellhead assembly 12. For instance, the first portion 46 and/or the second portion 48 may extend outward from the body 44 of the tubing spool 24 at greater distances when in a disengaged position and at smaller distances when in an engaged position. In some embodiments, the tie down screws 40 may be configured to maintain the diameter 66 of the wellhead assembly 12 at a value that is less than the diameter 64 of the opening 60 of the rotary table 29 at any position of the first portion 46 and the second portion 48. Accordingly, the wellhead assembly 12 may be configured to pass through the opening 60 of the rotary table 29 regardless of a position of the tie down screws 40.

[0026] Additionally, an operator of the mineral extraction system 10 may determine whether the tie down screws 40 are in an appropriate position based on the distance 50 that the tie down screws 40 extend from the body 44. For example, a measurement device 70 (e.g., a camera, an optical sensor, a position sensor, another suitable device), may be secured to the wellhead assembly 12 and communicatively coupled to a control system 72 of the mineral extraction system 10. As such, the operator may monitor the control system 72 to determine whether the distance 50 indicates whether one or more of the tie down screws 40 is in a desired position (e.g., a locked position or an engaged position).

[0027] FIG. 4 is an expanded cross-section of one of the tie down screws 40 within an opening 80 (e.g., annular bore) that extends into the body 44 of the tubing spool 24. As shown in the illustrated embodiment of FIG. 4, the first portion 46 of the tie down screw 40 is an annular shaped component that includes an opening 82 that receives the second portion 48 of the tie down screw 40. One or more seals 84 (e.g., annular seals) may be disposed in the opening 80 and/or the opening 82 to block a fluid (e.g., mud, oil, gas, water) from flowing into the tubing spool bore 34 (see, e.g., FIGS. 1 and 3) or from flowing out of the tubing spool bore 34. The seals 84 may be formed from nitrile, graphite, or any other suitable sealing material. While the illustrated embodiment of FIG. 4 shows the wellhead assembly 12 having two of the seals 84, in other embodiments, the wellhead assembly 14 may include 1 , 2, 3, 4, 5, or more than 5 of the seals 84.

[0028] As discussed above, the first portion 46 of the tie down screw 40 includes a first length 86 and the second portion 48 of the tie down screw 40 includes a second length 88. The first length 86 and the second length 88 may be reduced when compared to other types of tie down screws to enable the wellhead assembly 12 to pass through the opening 60 of the rotary table 29. For instance, the first length 86 may be reduced by between 5% and 75%, between 10% and 50%, or between 25% and 35% when compared to other types of tie down screws. Similarly, the second length 88 may be reduced by between 5% and 75%, between 10% and 50%, or between 25% and 35% when compared to other types of tie down screws. As such, the total length 62 of the tie down screw 40 may be reduced by between 5% and 75%, between 10% and 50%, or between 25% and 35% when compared to other types of tie down screws. In other embodiments, the total length 62 of the tie down screw 40 may be reduced by between 5% and 75%, between 10% and 50%, or between 25% and 35% when compared to the thickness 55 of the tubing spool 24 and/or another component of the wellhead assembly 12. In some embodiments, the thickness 55 of the tubing spool 24 may be at a first flange 56 of the tubing spool 24, at a body 57 of the tubing spool 24, and/or at a second flange 58 of the tubing spool 24. Despite the reduction of the lengths 62, 86, 88 of the tie down screw 40, the tie down screw 40 may still include a sufficient length to form a secure connection to a component of the wellhead system 12 and to enable the tie down screw 40 to withstand the pressures within the wellbore 20.

[0029] Further, the total length 62 of the tie down screw 40 may be defined by a length 83 of a portion 85 of the tie down screw 40 that engages a component of the wellhead assembly 12 when in an operating (e.g., engaged) position, the thickness 55 of the tubing spool 24 or other component of the wellhead assembly 12, and a length 87 of a portion 89 of the tie down screw 40 protruding from the surface 54 when the tie down screw is in the operating (e.g., engaged) position. In some embodiments, the length 83 of the portion 85 may be determined based on an amount of the tie down screw 40 that enables the tie down screw 40 to fully engage and/or activate the component of the wellhead assembly 12. Further, the length 87 of the portion 89 may be determined based on an amount of the tie down screw 40 that enables an operator to determine whether the tie down screw 40 is in the operating (e.g., engaged) position using the measurement device 70. [0030] In some embodiments, each of the tie down screws 40 may also include a test port 90 that enables pressure testing of the tie down screw 40, and/or the seals 84. For example, a hydraulic pump may be coupled to the test port 90. By applying pressure via the hydraulic pump, the integrity of the seals 84 may be verified. Further, by providing each tie down screw 40 with a test port 90, each tie down screw 40 may be individually tested to verify seal integrity.

[0031] As shown in the illustrated embodiment of FIG. 4, the second portion 48 of the tie down screws 40 includes a generally frustoconical distal portion 92 configured to compress against and maintain a position of a component within the tubing spool bore 34 (e.g., the tubing hanger 26). In other embodiments, the frustoconical distal portion 92 may engage a groove in the component within the tubing spool bore 34 and/or a tapered surface of the component within the tubing spool bore 34 to drive the component in an axial direction within the tubing spool bore 34. To engage the component, a gland 94 of the first portion 46 of the tie down screws 40 is rotated to drive the distal portion 92 radially inward into engagement with the tubing hanger 26. Specifically, to facilitate engagement with the wellhead assembly 12, the tie down screw 40 includes the gland 94 of the first portion 46 that may be configured to mate with recesses (e.g., threads) within the opening 80 of the tubing spool 24 or other component of the wellhead assembly 12, such as via external threads 96 or other suitable structures. In such an embodiment, the tie down screws 40 may be installed into the tubing spool 24 or other component of the wellhead assembly 12 by rotating the tie down screw 40 into engagement via threads 96. The opening 82 of the first portion 46 may include internal threads 98 configured to mate with threads 100 on the exterior of the second portion 48 of the tie down screw 40. As such, the first portion 46 and the second portion 48 may rotate about an axis 102 independent of one another until the threads 98 reach an end 104 of the threads 100, such that rotation of the first portion 46 drives rotation of the second portion 48 in a direction 106 along the axis 102. Further still, the second portion 48 may be rotated independently of the first portion 46 by rotating the second portion 48 at a gland 108 positioned proximate to the end 52 of the second portion 48. [0032] When the first portion 46 and/or the second portion 48 are rotated about the axis 102, the generally frustoconical distal portion 92 may contact a recess 110 of the component of the wellhead assembly 12 (e.g., the tubing hanger 26). While the illustrated embodiment of FIG. 4 shows the distal portion 92 of the tie down screw 40 having the frustoconical shape, in other embodiments, the distal portion 92 may be any suitable topography or shape configured to engage a similarly topographed recess 110 on the component of the wellhead assembly 12.

[0033] The tie down screw 40 includes the one or more seals 84, which may include a first seal 114 (e.g., annular seal) generally disposed around the circumference of the tie down screw 40 in a first location along the length 62 of the tie down screw 40. The tie down screw 40 may also include a second seal 116 (e.g., annular seal) disposed around the circumference of the tie down screw 40 at a second location along the length 62 of the tie down screw 40. As illustrated in FIG. 4, the first seal 114 is directly about the first portion 46 of the tie down screw 40 within the opening 80 of the tubing spool 24. The second seal 116 includes a ring seal within the opening 82 and between the first portion 46 and the second portion 48 of the tie down screw 40.

[0034] FIG. 5 depicts a flowchart of an embodiment of a process 100 for operating a mineral extraction system 10 having the tie down screws 40. At block 102, the tie down screws 40 may be disposed in the openings 80 of the wellhead assembly 12 in a disengaged position (e.g., retracted position), such that the tie down screws 40 extend from the surfaces 54 of the body 44 of the tubing spool 24. Further, at block 104, the wellhead assembly 12 may be directed into the wellbore 20 (or toward the wellbore 20). As discussed above, the wellhead assembly 12 may pass through the opening 60 of the rotary table 29, as shown at block 106. In some embodiments, operation of the well may include fracturing rock formations in the well, as shown at block 108. After the fracturing process and any post-fracturing production flow, the well may be plugged and production tubing and a production tree may be installed, as shown at block 110. In some cases, installing the production tubing and/or production tree may require removal and/or reinsertion of the wellhead assembly 12 into the well. As a result of the tie down screws 40, the wellhead assembly 12 may be removed and/or reinstalled into the well without removing the rotary table 29. As such, forming the well 10 in order to begin extracting minerals from the mineral deposit 14 may be facilitated by eliminating removal of the rotary table 29.

[0035] While the disclosed subject matter may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed. Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims.

Claims

1. A mineral extraction system, comprising:

a wellhead assembly configured to be disposed into a wellbore; and a tie down screw configured to be disposed at least partially into a component of the wellhead assembly, wherein the tie down screw is configured to extend radially outward from the component of the wellhead assembly, and wherein the wellhead assembly is configured to pass through an opening of a rotary table when the tie down screw is disposed at least partially into the component of the wellhead assembly.

2. The system of claim 1 , wherein the tie down screw comprises a first annular portion and a second portion, wherein the second portion is configured to be disposed into an opening of the first annular portion.

3. The system of claim 1 , wherein the second portion comprises a frustoconical end configured to mate with a recess of an additional component of the wellhead assembly.

4. The system of claim 1 , wherein the first annular portion comprises internal threads configured to mate with external threads of the second portion.

5. The system of claim 1 , comprising a measurement device configured to determine a distance between an end of the tie down screw extending radially outward from the component of the wellhead assembly and a surface of the component of the wellhead assembly.

6. The system of claim 5, wherein the measurement device is communicatively coupled to a control system, and wherein the control system is configured to determine whether the tie down screw is in a predetermined position based on the distance.

7. The system of claim 5, wherein the measurement device comprises a camera.

8. The system of claim 1 , wherein the wellhead assembly is configured to pass through the opening of the rotary table when the tie down screw is at least partially disposed in the component of the wellhead assembly in a fully retracted position.

9. The system of claim 1 , wherein the tie down screw is configured to secure an additional component of the wellhead assembly to the component of the wellhead assembly, engage seals of the component of the wellhead assembly, engage seals of the additional component of the wellhead assembly, or a combination thereof.

10. A system, comprising:

a wellhead assembly configured to be disposed into a wellbore;

a tie down screw configured to be disposed at least partially into a component of the wellhead assembly, wherein the tie down screw is configured to extend radially outward from the component of the wellhead assembly, and wherein the wellhead assembly is configured to pass through an opening of a rotary table when the tie down screw is disposed at least partially into the component of the wellhead assembly; and

a control system configured to determine a distance between an end of the tie down screw extending radially outward from the component of the wellhead assembly and an external surface of the component of the wellhead assembly.

11. The system of claim 10, wherein the tie down screw comprises a first annular portion and a second portion, wherein the second portion is configured to be disposed into an opening of the first annular portion.

12. The system of claim 11 , wherein the tie down screw comprises one or more seals disposed between the first annular portion and an additional opening extending through the component of the wellhead assembly, between the first annular portion and the second portion, or both.

13. The system of claim 12, wherein the second portion of the tie down screw comprises a passage extending axially through the second portion of the tie down screw.

14. The system of claim 13, wherein the passage is configured to test the one or more seals of the tie down screw.

15. The system of claim 11 , wherein the second portion of the tie down screw comprises a frustoconical end configured to mate with a recess in an additional component of the wellhead assembly.

16. The system of claim 10, comprising a measurement device communicatively coupled to the control system, wherein the measurement device is configured to provide feedback to the control system indicative of the distance between the end of the tie down screw and the external surface of the component.

17. A method, comprising:

disposing a tie down screw at least partially into a component of a wellhead assembly in a retracted position;

directing the wellhead assembly into a wellbore; and

passing the wellhead assembly and the tie down screw in the retracted position through an opening of a rotary table.

18. The method of claim 17, comprising performing a fracturing process when the wellhead assembly is disposed in the wellbore.

19. The method of claim 18, comprising installing production equipment into the wellbore without removing the rotary table.

20. The method of claim 19, wherein installing the production equipment into the wellbore comprises removing of the wellhead assembly from the wellbore, redirecting the wellhead assembly into the wellbore, and repassing the wellhead assembly through the rotary table.