WO2018132262A2

WO2018132262A2 - Overshot safety casing cutter system and method

Info

Publication number: WO2018132262A2
Application number: PCT/US2017/068592
Authority: WO
Inventors: Craig L. Cotton; Thomas G. Roesner
Original assignee: Cameron International Corporation
Priority date: 2016-12-30
Filing date: 2017-12-27
Publication date: 2018-07-19
Also published as: WO2018132262A3

Abstract

A method includes installing a blowout preventer onto a wellhead assembly, running a production casing into a wellbore through the blowout preventer and the wellhead assembly, lowering casing slips into the wellhead assembly through the blowout preventer, and setting the production casing in the casing slips. The method also includes lowering a casing cutter through the blowout preventer and the wellhead assembly, contacting the casing slips with the casing cutter, cutting and beveling the production casing with the casing cutter, and removing the casing cutter from the wellhead assembly and through the blowout preventer. The method further includes installing a sealing assembly in the wellhead assembly, and removing the blowout preventer from the wellhead assembly.

Description

OVERSHOT SAFETY CASING CUTTER SYSTEM AND METHOD

BACKGROUND

[0001] 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.

[0002] Oil and natural gas have a profound effect on modern economies and societies. In order to meet the demand for such natural resources, numerous companies invest significant amounts of time and money in searching for, accessing, and extracting oil, natural gas, and other subterranean resources. 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 can be located onshore or offshore depending on the location of a desired resource. Such systems generally include a wellhead assembly through which the resource is extracted. These wellhead assemblies generally include a wide variety of components and/or conduits, such as blowout preventers (BOPs), as well as various control lines, casings, valves, and the like, that control drilling and/or extraction operations.

[0003] In typical applications, casing is landed and set within the wellbore and wellhead assembly. Thereafter, the casing may be cut and beveled at an axial end of the casing within the wellhead assembly. It may be beneficial to cut and bevel the casing from the rig floor without removing the BOP. BRIEF DESCRIPTION OF THE DRAWINGS

[0004] 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:

[0005] FIG. 1 is a schematic of an embodiment of a mineral extraction system, in accordance with aspects of the present disclosure;

[0006] FIG. 2 is a cross-sectional side view of an embodiment of a wellhead assembly, illustrating installation of a blowout preventer, in accordance with aspects of the present disclosure;

[0007] FIG. 3 is a cross-sectional side view of an embodiment of a wellhead assembly, illustrating running of casing into a wellhead assembly, in accordance with aspects of the present disclosure;

[0008] FIG. 4 is a cross-sectional side view of an embodiment of a wellhead assembly, illustrating setting of a casing string within the wellhead assembly, in accordance with aspects of the present disclosure;

[0009] FIG. 5 is a cross-sectional side view of an embodiment of a wellhead assembly, illustrating a casing cutter landed against a casing hanger, in

accordance with aspects of the present disclosure;

[0010] FIG. 6 is a cross-sectional side view of an embodiment of a wellhead assembly, illustrating installation of a pack-off adapter, in accordance with aspects of the present disclosure;

[0011] FIG. 7 is a cross-sectional side view of an embodiment of a wellhead assembly, illustrating installation of a back pressure valve, in accordance with aspects of the present disclosure;

[0012] FIG. 8 is a flow chart of an embodiment of a method for cutting a casing element, in accordance with aspects of the present disclosure; and [0013] FIG. 9 is a schematic of an embodiment of a casing cutter, in

accordance with aspects of the present disclosure.

DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS

[0014] 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.

[0015] 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.

[0016] Embodiments of the presently disclosed techniques include systems and methods for cutting a casing element within or below a wellhead assembly without removing a blowout preventer (BOP) installed on the wellhead assembly. As explained in greater detail below, the disclosed embodiments include a cutter (e.g., overshot casing cutter, a fishing tool, etc.) that may be run through a BOP after a casing element (e.g., production casing) is run, cemented, and set within the wellhead assembly. The cutter may be landed against a casing hanger or casing slips, and the cutter may then be used cut and bevel the casing element. Thereafter, the cutter may be retrieved (e.g., with the casing "spoil" cut from the casing element) from the wellhead assembly through the BOP. A pack-off adapter, back pressure valve, and/or other sealing assembly may then be installed within the wellhead assembly. In this manner, the casing element (e.g., production casing) may be cut and beveled within the wellhead assembly without removal of the BOP, and the sealing assembly may be installed after landing the casing hanger (e.g., casing slips).

[0017] FIG. 1 is a schematic of an exemplary mineral extraction system 10 configured to extract various natural resources, including hydrocarbons (e.g., oil and/or natural gas), from a mineral deposit 12. Depending upon where the natural resource is located, the mineral extraction system 10 may be land-based (e.g., a surface system) or subsea (e.g., a subsea system). The illustrated system 10 includes a wellhead assembly 14 coupled to the mineral deposit 12 or reservoir via a well 16. Specifically, a well bore 18 extends from the reservoir 12 to a wellhead hub 20 located at or near the surface.

[0018] The illustrated wellhead hub 20, which may be a large diameter hub, acts as an early junction between the well 16 and the equipment located above the well 16. The wellhead hub 20 may include a complementary connector, such as a collet connector, to facilitate connections with the surface equipment. The wellhead hub 20 may be configured to support various strings of casing or tubing that extend into the wellbore 18, and in some cases extending down to the mineral deposit 12.

[0019] The wellhead 14 generally includes a series of devices and components that control and regulate activities and conditions associated with the well 16. For example, the wellhead 14 may provide for routing the flow of produced minerals from the mineral deposit 12 and the well bore 18, provide for regulating pressure in the well 16, and provide for the injection of chemicals into the well bore 18 (down-hole). In the illustrated embodiment, the wellhead 14 includes a casing spool 22 (e.g., tubular or annular structure), a tubing spool 24 (e.g., tubular or annular structure), a hanger 26 (e.g., an annular casing hanger and/or casing slips), and a blowout preventer (BOP) 28.

[0020] In operation, the wellhead 14 enables completion and workover procedures, such as tool insertion into the well 16 and installation of various components (e.g., hangers, shoulders, etc.). Further, minerals extracted from the well 16 (e.g., oil and natural gas) may be regulated and routed via the wellhead 14. For example, the BOP 28 may include a variety of valves, fittings, and controls (e.g., pipe rams, shear rams, annular packers and associated fluid circuits and controls) to prevent oil, gas, or other fluid from exiting the well 16 in the event of an unintentional release of pressure or an overpressure condition.

[0021] As mentioned above, it may be desirable to cut and bevel a casing element (e.g., production casing) within the wellhead assembly 14 without removal of the BOP 28 from the wellhead assembly 14. To this end, the mineral extraction system 10 includes a cutter 30 (e.g., internal casing cutter, external casing cutter, overshot casing cutter, fishing tool, etc.) that may be run into the wellhead assembly 14 through the BOP 28. For example, the cutter 30 may be run into the wellhead assembly 14 with a tool 32 (e.g., a work string). As described in detail below, the cutter 30 is run through the BOP 28 into the wellhead assembly 14 and is landed against the casing hanger 26. The cutter 30 is then used to cut and bevel the casing element (e.g., production casing). After the casing element is cut, the cutter 30 is retrieved with the portion of casing cut from the casing element (e.g., the casing spoil) from the wellhead assembly 14 through the BOP 28. A sealing assembly (e.g., pack-off adapter and/or back pressure valve) may then be installed in the wellhead assembly 14. Thereafter, the BOP 28 may be removed from the wellhead assembly 14, if desired. As will be appreciated, cutting and beveling of the casing element and installation of the sealing assembly within the wellhead assembly 14 without removal of the BOP 28 may reduce exposure of the well bore 18 to an environment surrounding the wellhead assembly 14 (e.g., the BOP 28 may be actuated to block fluid flow across the BOP 28 and to isolate the wellhead assembly 14 from equipment on a rig floor).

[0022] FIGS. 2-7 are cross-sectional side views of the wellhead assembly 14, illustrating running, landing, and cutting of production casing within the wellhead assembly 14 without removal of the BOP 28 from the wellhead assembly 14. First, as shown in FIG. 2, the casing spool 22 of the wellhead assembly 14 is installed with a first casing 50 (e.g., a surface casing, annular casing) and a second casing 52 (e.g., an intermediate casing, annular casing). Additionally, a BOP flange 54 (e.g., annular flange) having lock screws 56 is coupled to the casing spool 22.

[0023] The BOP 28 is coupled to the BOP flange 54, as shown in FIG. 3. With the BOP 28 coupled to the wellhead assembly 14, a drilling process may be completed. Once the well bore 18 is drilled, production casing 60 is run into the well bore 18 and is cemented in place, as shown in FIG. 3. Specifically, the production casing 60 is run through the wellhead assembly 14 into the well bore 18.

[0024] Once the production casing 60 running and cementing processes are completed, a casing hanger 70 (e.g., casing slips, annular hanger) is lowered into the wellhead assembly 14 (e.g., from a rig floor), as shown in FIG. 4. The casing hanger 70 is landed against a shoulder or landing surface of the casing spool 22 and is actuated to set the production casing 60 in place within the wellhead assembly 14 and the well bore 18. It should be noted that the casing hanger 70 is lowered into the wellhead assembly 14 through the BOP 28 with the BOP 28 still coupled to the wellhead assembly 14.

[0025] With the production casing 60 set by the casing hanger 70 (e.g., slips), the production casing 60 may be cut and beveled within the wellhead assembly 14. FIG. 5 is a cross-sectional side view of the wellhead assembly 14, illustrating the cutter 30 positioned within the wellhead assembly 14 (e.g., via a work string 74). More specifically, the cutter 30 is lowered from a rig floor of the mineral extraction system 10, through the BOP 28, and is set against the casing hanger 70. The cutter 30 may be a fishing tool, an overshot casing cutter, an external casing cutter, an internal casing cutter, or other suitable tubular cutting system. As will be appreciated, an external casing cutter cuts the production casing 60 from an outer diameter (e.g., outer annular surface) of the production casing 60, and an internal casing cutter cuts the production casing 60 from an inner diameter (e.g., inner annular surface) of the production casing 60. The cutter 30 may include additional features to enable a proper or desired cut (e.g., cutting location) in the production casing 60. Examples of such features are described below.

[0026] Once the cutter 30 is landed (e.g., "tagged") against the casing hanger 70, the cutter 30 may be actuated to cut and bevel the production casing 60 in a desired location (e.g., within or below the wellhead assembly 14). As will be appreciated, the cutting process may include applying weight to the cutter 30 and the production casing 60 and then rotating the cutter 30 or a component of the cutter 30 to cut the casing 60. For example, an appropriate amount of weight may be applied to the cutter 30 with a top drive 80 of the mineral extraction system 10. Rotation of the cutter 30 or cutter component may be achieved with the top drive 80, tongs, or other suitable system.

[0027] After the production casing 60 cutting process is complete, the cut of the production casing 60 (e.g., the bevel) may be washed or otherwise finished. The cutter 30 may be retrieved from the wellhead assembly 14 through the BOP 28. When the cutter 30 is removed from the wellhead assembly 14, the cutter 30 may also remove the portion of the production casing 60 that is cut away (e.g., the casing "spoil").

[0028] After the cutter 30 is removed, the tool 32 may be used to lower a pack-off adapter 90 into the wellhead assembly 14, as shown in FIG. 6. For example, the pack-off adapter 90 may be landed against the cut production casing 60 (e.g., a cut end of the production casing 60). The lock screws 56 of the BOP flange 54 may be actuated to hold the pack-off adapter 90 in place within the wellhead assembly 14. With the pack-off adapter 90 secured in place, a back pressure valve 100 may be installed as part of the wellhead assembly 14, and the BOP 28 may be removed (e.g., "nipple down"), as shown in FIG. 7.

[0029] FIG. 8 is a flow chart 1 10 of a method for cutting the production casing 60 without removing the BOP 28 of the wellhead assembly 14. First, as indicated by block 1 12, the BOP 28 is installed as part of the wellhead assembly 14. For example, the BOP 28 may be coupled to the BOP flange 54 of the wellhead assembly 14. In other embodiments, the BOP 28 may be coupled to another component of the wellhead assembly 14.

[0030] With the BOP 28 installed as part of the wellhead assembly 14 (e.g., "nipple up"), the well bore 18 may be drilled, as indicated by block 1 14. Once the drilling process is complete, casing (e.g., the production casing 60) may be run into the well bore 18 and cemented into place, as indicated by block 1 16.

Thereafter, the casing hanger 70 (e.g., casing slips) is lowered into the wellhead assembly 14 from the rig floor. The casing hanger 70 may be landed against a shoulder or other landing surface of the casing spool 22, as indicated by block 1 18. It should be noted that the steps of blocks 1 14, 1 16, and 1 18 are all completed with the BOP 28 coupled to the wellhead assembly 14.

[0031] Once the casing hanger 70 is landed within the wellhead assembly 14, the casing hanger 70 is actuated to set and secure the production casing 60 in place within the wellhead assembly 14, as indicated by block 120. The casing cutter 30 is then lowered through the BOP 28 to complete the cutting and beveling process, as indicated by block 122. First, as indicated by block 124, the cutter 30 is landed (e.g., "tagged") against the casing hanger 70. Once the cutter 30 is in proper position within the wellhead assembly 14, the production casing 60 cutting process is completed, as indicated by block 126. In certain

embodiments, the cutter 30 includes one or more features (e.g., a guide, positioning system, or other feature) to enable proper positioning of the cutter 30 within the wellhead assembly 14. The one or more features may also enable cutting of the production casing 60 at a desired or proper location. [0032] After the cutting process is completed, the casing spoil (e.g., cut portion of the production casing 60) and the cutter 30 may be removed from the wellhead assembly 14, as indicated by block 128. In particular, the casing cutter 30 and casing spoil are removed from the wellhead assembly 14 through the BOP 28, which is still coupled to the wellhead assembly 14. The cut production casing 60 may then be washed or otherwise finished.

[0033] As indicated by block 130, the pack-off adapter 90 may be run and landed against the production casing 60 within the wellhead assembly 14 after the cutter 30 is removed. Then the back pressure valve 100 may be installed within the wellhead assembly 14, as indicated by block 132, and the BOP 28 may then be removed (e.g., "nipple down"), as indicated by block 134. Thus, the BOP 28 remains coupled to the wellhead assembly 14 during the drilling, casing 60 running, cementing, casing 60 cutting and beveling, and seal assembly (e.g., pack-off adapter 90 and back pressure valve 100) installation processes. In this manner, the well bore 18 may be blocked and/or protected from exposure to the environment surrounding the wellhead assembly 14 during these processes.

[0034] As mentioned above, the cutter 30 may include one or more features to enable proper positioning of the cutter 30 within the wellhead assembly 14 and proper operation of the cutter 30 within the wellhead assembly 14. FIG. 9 is a schematic of an embodiment of the cutter 30, which may be used to complete the casing 60 cutting and beveling process described above. The cutter 30 may be a fishing tool, overshot casing cutter, internal casing cutter, external casing cutter, other suitable cutting tool, or any combination thereof.

[0035] In the illustrated embodiment, the cutter 30 includes a cutting system 140 and an actuation system 142. The cutting system 140 may include cutters, such as knives, blades, or other mechanical cutters. As will be appreciated, in an internal cutting system (e.g., where the cutter 30 is an internal casing cutter), the cutters or knives initialize a cut of the production casing 60 from an inner diameter of the production casing 60, as indicated by arrows 144. Alternatively, in an external cutting system (e.g., where the cutter 30 is an external casing cutter), the cutters or knives initialize a cut of the production casing from an outer diameter of the production casing, as indicated by arrows 146. In other embodiments, the cutting system 140 may include a chemical cutting system, water cutting system, or other type of cutting system.

[0036] The actuation system 142 is configured to actuate the cutting system 140 to initiate and/or complete the cutting process. For example, the actuation system 142 may be a mechanical (e.g., spring), hydraulic, or other suitable actuation system configured to actuate the cutting system 140. When or after the actuation system 142 actuates the cutting system 140, the cutter 30 may be rotated (e.g., via the top drive 80), as discussed above, to complete the

production casing 60 cutting process. As will be appreciated, the cutting system 140 may have cutters configured to retain or secure a portion of the production casing 60 (e.g., spoil) that is cut from the production casing 60, such that the cutter 30 removes the spoil when the cutter 30 is removed from the wellhead assembly 14.

[0037] In the illustrated embodiment, the cutter 30 also includes a positioning system 150. The positioning system 150 may be a guide or other system configured to enable proper positioning of the cutter 30 within the wellhead assembly 14 before the cutting process begins. For example, in the illustrated embodiment, the positioning system 150 includes a guide 152 positioned (e.g., threaded) at a lower axial end 154 of the cutter 30 when the cutter 30 is run into the wellhead assembly 14. The guide 152 may be a collar (e.g., annular collar) or other structure having a preselected dimension (e.g., axial length 156) that enables a desired positioning of the cutter 30 relative to the production casing 60. The guide 152 may also include other features (e.g., surfaces, geometries, configurations, etc.) to enable desired positioning of the cutter 30 relative to the production casing 60. As will be appreciated, proper or desired positioning of the cutter 30 relative to the production casing 60 enables cutting of the production casing 60 at a desired location along the production casing 60 to ensure that an appropriate or desired amount of the production casing 60 is cut and removed. [0038] The guide 152 may also have other features, such as an axial end feature 153, (e.g., surface feature, bearing surface, surface treatment, ball bearings, etc.) to enable rotation of the cutter 30 relative to the casing hanger 70 (e.g., slips) and/or enable application of weight to the casing hanger 70 by the cutter 30. As described above, the cutter 30 is landed against the casing hanger 70 or slips during the cutting process. Thus, the axial end feature 153 may enable completion of the production casing 60 cutting process without causing degradation to the casing hanger 70 (e.g., slips).

[0039] In other embodiments, the positioning system 150 may include other components, such as sensors 158 (e.g., optical sensors, magnetic sensors, etc.). In another embodiment, such as an embodiment where the cutter 30 is an internal casing cutter, the positioning system 150 may include a stop shoulder feature 160. The stop shoulder feature 160 may be configured to land against an axial end of the production casing 60, an internal surface of the production casing 60, or other surface within the wellhead assembly 14 to enable desired and/or precise positioning of the cutter 30 relative to the production casing 60. In this manner, a cut of the production casing 60 may occur at a desired location along the production casing 60.

[0040] The cutter 30 may further include other features to enable proper positioning and operation of the cutter 30 within the wellhead assembly 14 during the cutting and beveling process. For example, in an embodiment where the cutter 30 is an external casing cutter, the cutter 30 may include a thrust bearing 162 (e.g., adjustable thrust bearing). For example, the thrust bearing 162 may be positioned at the axial end 154 of the cutter 30. In certain embodiments, the thrust bearing 162 maybe positioned at the axial end 154 of the cutter 30 instead of, or in addition to, the guide 152. The thrust bearing 162 may provide a shoulder for a precise location of a cut to be made by the cutter 30. The thrust bearing 162 may also help avoid undesired contact between internal components of the wellhead assembly 14 and the cutter 30 when the cutter 30 is lowered into the wellhead assembly 14. [0041] As described above, embodiments of the presently disclosed techniques include systems and methods for cutting a casing element, such as production casing 60, within the wellhead assembly 14 without removing the BOP 28 coupled to the wellhead assembly 14. Specifically, the cutter 30 (e.g., overshot casing cutter, a fishing tool, etc.) discussed above may be run through the BOP 28 coupled to the wellhead assembly 14 after the production casing 60 is run, cemented, and set within the wellhead assembly 14. The cutter 30 is landed against a casing hanger or casing slips 70, and the cutter 30 is then used cut and bevel the production casing 60. During the cutting process, the cutter 30 is landed against, applies weight, and rotates relative to the casing hanger 70. As described in detail above, the cutter 30 may include one or more features to enable proper positioning and/or operation of the cutter 30 within the wellhead assembly 14 during the cutting process.

[0042] Once the producing casing 60 is cut and beveled, the cutter 30 may be retrieved (e.g., with the casing "spoil" cut from the casing 60) from the wellhead assembly 14 through the BOP 28. Then the pack-off adapter 90, back pressure valve 100, and/or other sealing assembly may then be installed within the wellhead assembly 14. In this manner, the production casing 60 may be cut and beveled within the wellhead assembly 14 without removal of the BOP 28, and the sealing assembly (e.g., pack-off adapter 90 and/or back pressure valve 100) may be installed after landing the casing hanger 70. In other words, the BOP 28 may be installed (e.g., "nipple up") during the entire drilling, casing running, casing cutting, etc. processes to block exposure of the well bore 18 to the environment surrounding the wellhead assembly 14.

[0043] While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed. Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims.

Claims

1 . A method, comprising:

installing a blowout preventer onto a wellhead assembly;

running a production casing into a wellbore through the blowout preventer and the wellhead assembly;

lowering casing slips into the wellhead assembly through the blowout preventer;

setting the production casing in the casing slips;

lowering a casing cutter through the blowout preventer and the wellhead assembly;

contacting the casing slips with the casing cutter;

cutting and beveling the production casing with the casing cutter;

removing the casing cutter from the wellhead assembly and through the blowout preventer;

installing a sealing assembly in the wellhead assembly; and

removing the blowout preventer from the wellhead assembly.

2. The method of claim 1 , comprising rotating the casing cutter to enable the casing cutter to cut and bevel the production casing.

3. The method of claim 1 , comprising applying a weight to the casing cutter to facilitate cutting and beveling the production casing using the casing cutter.

4. The method of claim 1 , comprising removing a spoil of the production casing from the wellhead assembly and through the blowout preventer with the casing cutter.

5. The method of claim 1 , comprising initiating the cutting of the production casing along an inner annular surface of the production casing using the casing cutter.

6. The method of claim 1 , comprising initiating the cutting of the production casing along an outer annular surface of the production casing using the casing cutter.

7. The method of claim 1 , comprising cementing the production casing within the wellhead assembly prior to cutting and beveling the production casing using the casing cutter.

8. A system, comprising:

a casing cutter assembly configured to be lowered through a blowout preventer and into a wellhead assembly, wherein the casing cutter assembly comprises a cutter configured to cut a production casing at a location within or below the wellhead assembly while the blowout preventer is coupled to the wellhead assembly; and

a sealing assembly configured to be installed at a cut end of the

production casing.

9. The system of claim 8, wherein the sealing assembly comprises a pack-off adapter and a back pressure valve.

10. The system of claim 8, wherein the casing cutter assembly comprises a positioning system.

1 1 . The system of claim 8, wherein the casing cutter assembly comprises a thrust bearing.

12. The system of claim 8, wherein the cutter is configured to initiate the cut of the production casing along an inner annular surface of the production casing.

13. The system of claim 8, wherein the cutter is configured to initiate the cut of the production casing along an outer annular surface of the production casing.

14. The system of claim 8, comprising a top drive coupled to the cutter casing assembly and configured to drive rotation of the cutter to cut the production casing.

15. The system of claim 8, wherein the casing cutter assembly is configured to retain a spoil of the production casing to facilitate removal of the spoil from the wellhead assembly.

16. A method, comprising:

lowering a casing cutter through a blowout preventer and a wellhead assembly;

cutting and beveling a production casing at a location within or below the wellhead assembly using the casing cutter while the blowout preventer is coupled to the wellhead assembly;

removing a spoil of the production casing from the wellhead assembly and through the blowout preventer using the casing cutter;

installing a sealing assembly against a cut end of the production casing; and

removing the blowout preventer from the wellhead assembly.

17. The method of claim 16, comprising contacting a casing hanger with the casing cutter prior to cutting and beveling the production casing using the casing cutter.

18. The method of claim 16, wherein installing the sealing assembly comprises landing a pack-off adapter on the cut end of the production casing, actuating lock screws of a flange of the blowout preventer to hold the pack-off adapter against the cut end of the production casing, and installing a back pressure valve to control fluid flow through the wellhead assembly.

19. The method of claim 16, comprising, prior to lowering the casing cutter through the blowout preventer and the wellhead assembly:

installing the blowout preventer onto the wellhead assembly;

running the production casing into a wellbore through the blowout preventer and the wellhead assembly;

lowering casing slips into the wellhead assembly through the blowout preventer; and

setting the production casing in the casing slip.

20. The method of claim 16, comprising rotating the casing cutter to enable the casing cutter to cut and bevel the production casing.