SYSTEMS AND METHODS FOR CEMENTING CASING AND SEALING A HANGER IN A WELLHEAD HOUSING
A wellhead includes a wellhead housing, a passage formed in or along the wellhead housing, and a hanger configured to support a casing. The wellhead also includes a seal assembly configured to provide an annular seal across an annular space between the hanger and the wellhead housing. In operation, a movable seal component or the seal assembly is configured to move relative to the passage to selectively enable a flow of fluid across the seal assembly via the passage.
This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.
Natural resources, such as oil and gas, are used as fuel to power vehicles, heat homes, and generate electricity. Once a desired natural resource is discovered below a surface of the earth, mineral extraction systems are often employed to access and extract the desired natural resource. The mineral extraction systems may be located onshore or offshore depending on the location of the desired natural resource. The mineral extraction systems generally include a wellhead through which the desired natural resource is extracted. The wellhead may include or be coupled to a wide variety of components, such as a tubing hanger that supports a tubing, a casing hanger that supports a casing, valves, fluid conduits, and the like.
SUMMARYA summary of certain embodiments disclosed herein is set forth below. It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure. Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.
In certain embodiments, a wellhead includes a wellhead housing, a passage formed in or along the wellhead housing, and a hanger configured to support a casing. The wellhead also includes a seal assembly configured to provide an annular seal across an annular space between the hanger and the wellhead housing. A movable seal component or the seal assembly is configured to move relative to the passage to selectively enable a flow of fluid across the seal assembly via the passage.
In certain embodiments, a method of operating a wellhead includes running a hanger and a seal assembly into a wellhead housing. The method also includes routing a flow of fluid across the seal assembly via a passage formed in the wellhead housing during cementing operations with the hanger and the seal assembly in the wellhead housing. The method further includes, after the cementing operations, moving a movable component or the seal assembly relative to the wellhead housing to block the flow of fluid across the seal assembly and to seal an annular space between the hanger and the wellhead housing with the seal assembly
In certain embodiments, a wellhead includes a wellhead housing, a passage formed in the wellhead housing, and a hanger configured to support a casing. The wellhead also includes a seal assembly configured to move relative to the hanger between a first axial position and a second axial position within the wellhead housing. In the first axial position, the seal assembly enables a flow of fluid across the seal assembly via the passage. In the second axial position, the seal assembly blocks the flow of fluid across the seal assembly via the passage and provides an annular seal across an annular space between the hanger and the wellhead housing.
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:
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.
Certain embodiments of the present disclosure generally relate to systems and methods that support efficient casing installation operations. For example, certain embodiments of the present disclosure include a passage formed in or along a wellhead housing, and the passage is selectively sealed via a movable seal component, such as a piston, a valve, or a plug. In some cases, the movable seal component may be a seal assembly that seals an annular space between the wellhead housing and a hanger that supports the casing. During cementing operations, the movable seal component may be positioned to enable a flow of fluid through the passage formed in or along the wellhead housing. Then, after the cementing operations, the movable seal component may be positioned to block the flow of fluid through the passage formed in or along the wellhead housing (e.g., to seal the passage formed in or along the wellhead housing).
Advantageously, the systems and methods disclosed herein enable the seal assembly to run with the hanger into the wellhead housing (e.g., rather than running the hanger into the wellhead housing, then conducting cementing operations, and then running the seal assembly into the wellhead housing). Accordingly, the systems and methods disclosed herein may save time and associated costs during drilling operations.
With the foregoing in mind,
In the illustrated embodiment, the mineral extraction system 10 includes a tree 22, a tubing spool 24, a casing spool 26, and a blowout preventer (BOP) 38. The tree 22 generally includes a variety of flow paths (e.g., bores), valves, fittings, and controls for operating the well 16. Further, the tree 22 may provide fluid communication with the well 16. For example, the tree 22 includes a tree bore 28 that provides for completion and workover procedures, such as the insertion of tools (e.g., a tool 40) into the well 16, the injection of various chemicals into the well 16, and so forth. Further, the natural resources extracted from the well 16 may be regulated and routed via the tree 22. For example, the tree 22 may be coupled to a flowline that is tied back to other components, such as a manifold.
As shown, the tubing spool 24 may provide a base for the tree 22 and includes a tubing spool bore 30 that connects (e.g., enables fluid communication between) the tree bore 28 and the well 16. As shown, the casing spool 26 may be positioned between the tubing spool 24 and the wellhead hub 18 and includes a casing spool bore 32 that connects (e.g., enables fluid communication between) the tree bore 28 and the well 16. Thus, the tubing spool bore 30 and the casing spool bore 32 may provide access to the wellbore 20 for various completion and workover procedures. The BOP 38 may consist of a variety of valves, fittings, and controls to block oil, gas, or other fluid from exiting the well 16 in the event of an unintentional release of pressure or an overpressure condition.
As shown, a tubing hanger 34 is positioned within the tubing spool 24. The tubing hanger 34 may be configured to support tubing (e.g., a tubing string) that is suspended in the wellbore 20 and/or to provide a path for control lines, hydraulic control fluid, chemical injections, and so forth. Additionally, as shown, a casing hanger 36 is positioned within the casing spool 26. The casing hanger 36 may be configured to support casing (e.g., a casing string) that is suspended in the wellbore 20. The tool 40 may be utilized to lower the tubing hanger 34 into the tubing spool 24 and/or the casing hanger 36 into the casing spool 26.
As discussed in more detail herein, a passage may be formed in or along a wellhead housing (e.g., a portion of the casing spool 26), and the passage is selectively sealed via a movable component (e.g., a piston, a valve, a plug, a seal assembly that may be integral to or separate from the hanger 34, 36, thus the movable component may include the hanger 34, 36). During cementing operations, the movable component may be positioned to enable a flow of fluid through the passage formed in or along the wellhead housing. Thus, the flow of fluid may pass from below the hanger to above the hanger (e.g., relative to the wellbore) via the passage. Then, after the cementing operations, the movable component may be positioned to block the flow of fluid through the passage formed in or along the wellhead housing (e.g., to seal the passage formed in or along the wellhead housing). Thus, the flow of fluid may not pass from below the hanger to above the hanger via the passage. To facilitate discussion, the mineral extraction system 10, and the components therein, may be described with reference to an axial axis or direction 44, a radial axis or direction 46, and a circumferential axis or direction 48.
A seal assembly 64 (e.g., annular seal assembly) is positioned about the hanger 56. As shown, the seal assembly 64 may include annular seals supported in annular seal grooves formed in the hanger 56 (e.g., a body of the hanger 56; a single, solid body that includes the annular seal grooves for the annular seals and that supports the casing 58). In operation, a running tool may lower the hanger 56 with the casing 58 and the seal assembly 64 into the wellhead housing 50. The running tool may lower the hanger 56 until the hanger 56 reaches a landed position in which the hanger 56 is landed on the wellhead housing 50 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 56 relative to the wellhead housing 50 toward the wellbore). In the landed position, the seal assembly 64 may contact and seal against the wellhead housing 50. Thus, the seal assembly 64 seals an annular space between a radially outer surface of the hanger 56 and a radially inner surface of the wellhead housing 50, and the seal assembly 64 blocks fluid flow through the annular space.
In particular, the seal assembly 64 forms an annular seal at a first axial location within the wellhead housing 50. However, the passage 52 provides a bypass pathway for fluid flow between a second axial location within the wellhead housing 50 (e.g., below the first axial location relative to the wellbore) to a third axial location within the wellhead housing 50 (e.g., above the first axial location relative to the wellbore). For example, the passage 52 includes a first opening 66 (e.g., inlet) exposed to the annular space at the second axial location and a second opening 68 (e.g., outlet) exposed to the annular space (or, more generally, a bore 70 of the wellhead housing 50) at the third axial location. Further, the piston 54 is configured to move within the passage 52 (e.g., along the axial axis 44) to selectively seal the passage 52.
Thus, once the hanger 56 is in the landed position with the seal assembly 64 against the wellhead housing 50, cementing operations may commence to cement the casing 58 within the wellbore. The piston 54 is positioned to enable the fluid flow from the first opening 66 to the second opening 68 via the passage 52. In particular, the fluid flow of fluid may travel into the first opening 66, through the passage 52, and out the second opening 68 to return to the annular space (or the bore 70). Once the cementing operations are complete, the piston 54 is driven/moved to block the fluid flow from the first opening 66 to the second opening 68 via the passage 52. For example, the piston 54 may be driven/moved from a first piston position 72 shown in solid lines in
The piston 54 may include seals 76 (e.g., annular seals) to seal against side walls of the passage 52. As shown, the passage 52 may include one or more additional openings 78, which may facilitate cementing operations for additional stages or levels of hangers and casings. In this way, the running tool may lower the hanger 56 with the casing 58 and the seal assembly 64 into the wellhead housing 50, and the seal assembly 64 may remain in the wellhead housing 50 (e.g., sealed against the wellhead housing 50) during the cementing operations. Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal between the hanger 56 and the wellhead housing 50 after the cementing operations.
It should be appreciated that the wellhead housing 50 may include multiple passages 52 distributed (e.g., spaced apart) about the circumferential axis 48 (e.g., at discrete locations about the circumferential axis 48). For example, the multiple passages 52 may include 2, 3, 4, or more passages 52 that each extend along the axial axis 44, that each include a respective piston 54, and that each include at least two respective openings (e.g., the openings 66, 68, 78). Advantageously, the multiple passages 52 may provide additional flow-by area (e.g., as compared to a signal passage 52) and/or dedicated passage(s) 52 for certain stages or levels of hangers and casings. For example, in some such cases, a first one of the multiple passages 52 may include two respective openings across a first axial range that corresponds to a first annulus (e.g., for a first stage or level of hanger and casing), while a second one of the multiple passages 52 may include two respective openings across a second axial range that corresponds to a second annulus (e.g., for a second stage or level of hanger and casing), wherein the first axial range is different from the second axial range (e.g., offset along the axial axis 44). Additionally, in some such cases, the first one of the multiple passages 52 may be at a first circumferential location, and the second one of the multiple passages 52 may be at a second circumferential location, wherein the first circumferential location is different from the second circumferential location (e.g., offset along the circumferential axis 48).
A seal assembly 94 (e.g., annular seal assembly) is positioned about the hanger 86. As shown, the seal assembly 94 may include annular seals supported in annular seal grooves formed in the hanger 86 (e.g., a body of the hanger 86; a single, solid body that includes the annular seal grooves for the annular seals and that supports the casing 88). In operation, a running tool may lower the hanger 86 with the casing 88 and the seal assembly 94 into the wellhead housing 80. The running tool may lower the hanger 86 until the hanger 86 reaches a landed position in which the hanger 86 is landed on the wellhead housing 80 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 86 relative to the wellhead housing 80 toward the wellbore). In the landed position, the seal assembly 94 may contact and seal against the wellhead housing 80. Thus, the seal assembly 94 seals an annular space between a radially outer surface of the hanger 86 and a radially inner surface of the wellhead housing 80, and the seal assembly 94 blocks fluid flow through the annular space.
In particular, the seal assembly 94 forms an annular seal at a first axial location within the wellhead housing 80. However, the passage 82 provides a bypass pathway for fluid flow between a second axial location within the wellhead housing 80 (e.g., below the first axial location relative to the wellbore) to a third axial location within the wellhead housing 80 (e.g., above the first axial location relative to the wellbore). For example, the passage 82 includes a first opening 96 (e.g., inlet) exposed to the annular space at the second axial location and a second opening 98 (e.g., outlet) exposed to the annular space (or, more generally, a bore 100 of the wellhead housing 80) at the third axial location. Further, the valve 84 is configured to move within the passage 82 (e.g., along the radial axis 46) to selectively seal the passage 82 to block the fluid flow through the passage 82.
Thus, once the hanger 86 is in the landed position with the seal assembly 94 against the wellhead housing 80, cementing operations may commence to cement the casing 88 within the wellbore. The valve 84 is positioned to enable the fluid flow from the first opening 96 to the second opening 98 via the passage 82. In particular, the flow of fluid may travel into the first opening 96, through the passage 82, and out the second opening 98 to return to the bore 100. Once the cementing operations are complete, the valve 84 is actuated to block the fluid flow between the first opening 96 and the second opening 98 via the passage 82. For example, the valve 84 may be driven/moved from a first valve position or configuration in which a valve member of the valve 84 is withdrawn from the passage 82 to enable the fluid flow through the passage 82 to a second valve position or configuration in which the valve member of the valve 84 extends across the passage 82 to block the fluid flow through the passage 82 after the cementing operations. The valve 84 may include seals 106 (e.g., annular seals) to seal against walls of the passage 82 and/or the openings 96, 98. In this way, the running tool may lower the hanger 86 with the casing 88 and the seal assembly 94 into the wellhead housing 80, and the seal assembly 94 may remain in the wellhead housing 80 (e.g., sealed against the wellhead housing 80) during the cementing operations. Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 86 to the wellhead housing 80 after the cementing operations.
The valve 84 may include a check valve that enables fluid flow in one direction (e.g., only one direction; through the first opening 96 into to the passage 82). Upon completion of the cementing operations, a lock 110 (e.g., a threaded lock) may be engaged with the valve 84 to block any fluid flow across the valve 84 (e.g., to transition the valve 84 into a plug that blocks fluid flow through the first opening 96 into the passage 82). The valve 84 may also include another type of valve, such as an integrated valve (e.g., gate valve, ball valve).
As shown, the passage 82 may include one or more additional openings 108, which may facilitate cementing operations for additional stages or levels of hangers and casings. Additionally, one or more additional valves 84 may be positioned in the second opening 98 and the one or more additional openings 108 to selectively block fluid flow through the openings 98, 108 and the passage 82 during cementing operations for other stages or levels of casing.
It should be appreciated that the wellhead housing 80 may include multiple passages 82 distributed (e.g., spaced apart) about the circumferential axis 48 (e.g., at discrete locations about the circumferential axis 48). For example, the multiple passages 82 may include 2, 3, 4, or more passages 82 that each extend along the axial axis 44 and that each include at least two respective openings (e.g., the openings 96, 98, 108). Each of the at least two respective openings also include a respective valve 84. Advantageously, the multiple passages 82 may provide additional flow-by area (e.g., as compared to a signal passage 82) and/or dedicated passage(s) 82 for certain stages or levels of hangers and casings. For example, in some such cases, a first one of the multiple passages 82 may include two respective openings across a first axial range that corresponds to a first annulus (e.g., for a first stage or level of hanger and casing), while a second one of the multiple passages 82 may include two respective openings across a second axial range that corresponds to a second annulus (e.g., for a second stage or level of hanger and casing), wherein the first axial range is different from the second axial range (e.g., offset along the axial axis 44). Additionally, in some such cases, the first one of the multiple passages 82 may be at a first circumferential location, and the second one of the multiple passages 82 may be at a second circumferential location, wherein the first circumferential location is different from the second circumferential location (e.g., offset along the circumferential axis 48).
In
A seal assembly 134 (e.g., annular seal assembly with annular seal elements) is positioned about the hanger 126. As shown, the seal assembly 134 may include annular seals supported in annular seal grooves formed in the hanger 126 (e.g., a body of the hanger 126; a single, solid body that includes the annular seal grooves for the annular seals and that supports the casing 128). In operation, a running tool 135 may lower the hanger 126 with the casing 128 and the seal assembly 134 into the wellhead housing 120. The running tool 135 may lower the hanger 126 until the hanger 126 reaches a landed position in which the hanger 126 is landed on the wellhead housing 120 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 126 relative to the wellhead housing 120 toward the wellbore). In the landed position, the seal assembly 134 may contact and seal against the wellhead housing 120. Thus, the seal assembly 134 seals an annular space between a radially outer surface of the hanger 126 and a radially inner surface of the wellhead housing 120, and the seal assembly 134 blocks fluid flow through the annular space.
In particular, the seal assembly 134 forms an annular seal at a first axial location within the wellhead housing 120. However, the passage 122 provides a bypass pathway for fluid flow between a second axial location within the wellhead housing 120 (e.g., below the first axial location relative to the wellbore) to a third axial location within the wellhead housing 120 (e.g., above the first axial location relative to the wellbore). For example, the passage 122 includes a first opening 136 (e.g., inlet) exposed to the annular space at the second axial location and a second opening 138 (e.g., outlet) exposed to the annular space (or, more generally, a bore 140 of the wellhead housing 120) at the third axial location. Further, the plug 124 is configured to be inserted into the passage 122 (e.g., along the radial axis 46) to selectively seal the passage 122 to block the fluid flow through the passage 122. The plug 124 may be inserted through an access port 125 at a radially outer surface of the wellhead housing 120.
Thus, once the hanger 126 is in the landed position with the seal assembly 134 against the wellhead housing 120, cementing operations may commence to cement the casing 128 within the wellbore. The plug 124 is withdrawn or not positioned in the passage 122 to enable the fluid flow from the first opening 136 to the second opening 138 via the passage 122. In particular, the flow of fluid may travel into the first opening 136, through the passage 122, and out the second opening 138 to return to the bore 140. Once the cementing operations are complete, the plug 124 is inserted through the access port 125 to block the fluid flow between the first opening 136 and the second opening 138 via the passage 122. For example, the plug 124 may be driven/moved from a first plug position or configuration in which the plug 124 is withdrawn from the passage 122 to enable the fluid flow through the passage 122, to a second plug position or configuration in which the plug 124 extends across the passage 122 to block the fluid flow through the passage 122 after the cementing operations. The plug 124 may include seals 146 (e.g., annular seals) to seal against walls of the passage 122 and/or the second opening 138. In this way, the running tool 135 may lower the hanger 126 with the casing 128 and the seal assembly 134 into the wellhead housing 120, and the seal assembly 134 may remain in the wellhead housing 120 (e.g., sealed against the wellhead housing 120) during the cementing operations. Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 126 to the wellhead housing 120 after the cementing operations.
As shown in
As shown, a running tool 155 may lower the hanger 156 with the casing 158, the seal assembly 154, and a lock ring 157 (e.g., annular lock ring; c-ring) into the wellhead housing 150. The running tool 155 may lower the hanger 156 until the hanger 156 reaches a landed position in which the hanger 156 is landed on the wellhead housing 150 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 156 relative to the wellhead housing 150 toward the wellbore). In the landed position, the seal assembly 154 may contact and seal against both the wellhead housing 150 and the hanger 156. For example, the seal assembly 154 may include an annular ring 159 (e.g., ring body) that supports first annular seal elements on a radially inner surface that seal against a radially outer surface of the hanger 156 and second annular seal elements on a radially outer surface that seal against a radially inner surface of the housing 150. Thus, the seal assembly 154 seals an annular space between the radially outer surface of the hanger 156 and the radially inner surface of the wellhead housing 150, and the seal assembly 154 blocks fluid flow through the annular space. Additionally, in the landed position, the lock ring 157 may axially align with a corresponding recess 161 (e.g., annular recess or groove) in the radially inner surface of the wellhead housing 150.
Once the hanger 156 is in the landed position, the running tool 155 may be rotated (e.g., unthreaded) to cause the annular ring 159 with the seal assembly 154 to move axially (e.g., away from the wellbore) relative to the hanger 156 and the lock ring 157 supported by the hanger 156, as well as relative to the wellhead housing 150. The running tool 155 may be rotated until the annular ring 159 of the seal assembly 154 separates from the lock ring 157, which enables the lock ring 157 to expand radially outwardly to engage the corresponding recess 161 to lock the hanger 156 within the wellhead housing 150 (e.g., block axial movement of the hanger 156 relative to the wellhead housing 150).
However, to facilitate cementing operations, the running tool 155 is only partially rotated so that the seal assembly 154 remains positioned axially between a first opening 166 and a second opening 168 of the passage 152. Thus, the passage 152 provides a bypass pathway for fluid flow between a second axial location within the wellhead housing 150 (e.g., below the first axial location relative to the wellbore) to a third axial location within the wellhead housing 150 (e.g., above the first axial location relative to the wellbore via the first opening 166 (e.g., inlet) and the second opening 168 (e.g., outlet) that fluidly couple to the passage 152. The first opening 166 is exposed to the annular space at the second axial location and the second opening 168 (e.g., outlet) exposed to the annular space (or, more generally, a bore 170 of the wellhead housing 150) at the third axial location.
As shown in
As shown in
In this way, the running tool 155 may lower the hanger 156 with the casing 158, the seal assembly 154, and the lock ring 157 into the wellhead housing 150, and the seal assembly 154 may remain in the wellhead housing 150 during the cementing operations. However, the seal assembly 154 may move relative to the wellhead housing 150 after the cementing operations to seal the annular space between the hanger 156 and the wellhead housing 150, as well as the passage 152. In this way, the seal assembly 154 essentially operates as a movable component that selectively seals the passage 152. Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 156 to the wellhead housing 150 after the cementing operations.
The seal assembly 154, the running tool 155, and the hanger 156 may have any suitable interfaces that enable the operations and techniques described herein. For example, the running tool 155 may be threadably coupled to the hanger 156 and may also be coupled to the seal assembly 154 via an additional lock ring that engages an additional corresponding lock groove of the annular ring 159 of the seal assembly 154. The seal assembly 154 may be blocked from rotating with the running tool 155, such that the rotation of the running tool 155 (e.g., to unthread the running tool 155 from the hanger 156) drives axial movement of the seal assembly 154 (e.g., without rotation) relative to the wellhead housing and the hanger 156.
In
Various features of the wellhead housing 200 and the hanger 208 may facilitate efficient running, cementing, and sealing operations. For example, a running tool 212 may run the hanger 208 with the seal assembly 204 into the wellhead housing 200 until the hanger 208 reaches a landed position in which the hanger 208 is landed on the wellhead housing 200 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 208 relative to the wellhead housing 200 toward the wellbore). In the embodiment shown in
In response to detection of the hanger 208 being in the landed position (e.g., slack off weight), the running tool 212 moves the hanger 208 axially (e.g., away from the wellbore; raises the hanger 208) to align a first lock ring 218 with a lock ring groove 220 in the wellhead housing 200. An actuation sleeve 222 (e.g., a hydraulic actuation sleeve) of the running tool 212 may be driven axially (e.g., toward the wellbore) to insert radially between the hanger 208 and the first lock ring 218, which drives the first lock ring 218 radially outwardly away from the hanger 208 toward the lock ring groove 220 in the wellhead housing 200. Then, the running tool 212 again moves the hanger 208 axially (e.g., toward the wellbore; lowers the hanger 208) until the first lock ring 218 contacts a lower shoulder 224 of the lock ring groove 220. In this position or configuration, which is illustrated in
Once the cementing operations are complete, the running tool 212 may raise the hanger 208 until the first lock ring 218 contacts an upper shoulder 228 of the lock ring groove 220. In this position or configuration, which is illustrated in
Further, as shown in
In this way, the running tool 212 may lower the hanger 208 with the casing 226, the seal assembly 204, and the lock rings 218, 230 into the wellhead housing 200, and the seal assembly 204 may remain in the wellhead housing 200 (e.g., aligned with the groove 202; not sealed against the wellhead housing 200) during the cementing operations. However, the hanger 208 with the casing 226, the seal assembly 204, and the lock rings 218, 230 may move relative to the wellhead housing 200 after the cementing operations to seal the annular space between the hanger 208 and the wellhead housing 200. In this way, the hanger 208 with the seal assembly 204 may essentially operate as a movable component that selectively seals the annular space (e.g., selectively exposes the groove 202 to the hanger passage 206 or seals the groove 202 from the hanger passage 206; the groove 202 operates as a bypass passage). Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 208 to the wellhead housing 200 after the cementing operations.
As shown in an inset provided in
In
Various features of the wellhead housing 250 and the hanger 258 may facilitate efficient running, cementing, and sealing operations. For example, a running tool 272 may run the hanger 258 with the seal assembly 264 into the wellhead housing 250 until the hanger 258 reaches a landed position in which the hanger 258 is landed on the wellhead housing 250 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 258 relative to the wellhead housing 250 toward the wellbore). In the embodiment shown in
In response to detection of the hanger 258 being in the landed position (e.g., slack off weight), a retainer 280 (e.g., one or more temporary locks, such as one or more hold down screws) may be driven (e.g., via an actuator; via manual operation by an operator) radially inwardly through the wellhead housing 250 (or through a blowout preventer adapter that is coupled to the wellhead housing 250). It should be appreciated that the retainer 280 may have any suitable form, such as one or more retainer screws that are inserted into respective openings 282 (e.g., threaded openings) that are spaced apart or distributed circumferentially about the wellhead housing 250. In certain embodiments, the retainer 280 may contact and engage a tool surface 284 of the running tool 272 to block axial movement of the running tool 272 (and the hanger 258 coupled thereto) relative to the wellhead housing 250. Further, as described herein, the retainer 280 may block withdrawal of the hanger 258 from the wellhead housing 250 (e.g., at least a portion of the hanger 258 with the seal assembly 264 is maintained between the housing surface 276 of the wellhead housing 250 and the retainer 280 along the axial axis 44).
With the hanger 258 in the landed position as illustrated in
Once the cementing operations are complete, the running tool 272 may raise the hanger 258 until the retainer 280 contacts an upper shoulder 286 of the hanger 258. In this position or configuration, which is illustrated in
Further, as shown in
In this way, the running tool 272 may lower the hanger 258 with the casing 260 and the seal assembly 264 into the wellhead housing 250, and the seal assembly 264 may remain in the wellhead housing 250 (e.g., aligned with the passage 252 to open the passage 252 to fluid flow) during the cementing operations. However, the hanger 258 with the casing 260 and the seal assembly 264 may move relative to the wellhead housing 250 after the cementing operations to seal the annular space between the hanger 258 and the wellhead housing 250. In this way, the hanger 258 with the seal assembly 264 may essentially operate as a movable component that selectively seals the annular space (e.g., selectively exposes the passage 252 to the hanger passage 256 or seals the passage 252 from the hanger passage 256; the passage 252 operates as a bypass passage). Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 258 to the wellhead housing 250 after the cementing operations.
Advantageously, with reference to the inset provided in
As shown in an inset provided in
Various features of the wellhead housing 300 and the hanger 308 may facilitate efficient running, cementing, and sealing operations. For example, a running tool 322 may run the hanger 308 with the seal assembly 304 into the wellhead housing 300 until the hanger 308 reaches a landed position in which the hanger 308 is landed on the wellhead housing 300 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 308 relative to the wellhead housing 300 toward the wellbore). In the embodiment shown in
In response to detection of the hanger 308 being in the landed position (e.g., slack off weight), a retainer 330 (e.g., one or more temporary locks, such as one or more hold down screws) may be driven (e.g., via an actuator; via manual operation by an operator) radially inwardly through the wellhead housing 300 (or through a blowout preventer adapter that is coupled to the wellhead housing 300). It should be appreciated that the retainer 330 may have any suitable form, such as one or more retainer screws that are inserted into respective openings 332 (e.g., threaded openings) that are spaced apart or distributed circumferentially about the wellhead housing 300. Further, as described herein, the retainer 330 may block withdrawal of the hanger 308 from the wellhead housing 300 (e.g., at least a portion of the hanger 308 with the seal assembly 304 is maintained between the housing surface 326 of the wellhead housing 300 and the retainer 330 along the axial axis 44).
With the hanger 308 in the landed position as illustrated in
Once the cementing operations are complete, the running tool 322 may raise the hanger 308 until the retainer 330 contacts an upper shoulder 336 of the hanger 258 (or a portion of the running tool 322 that is coupled to the hanger 258). In this position or configuration, which is illustrated in
While a lock ring is not illustrated in
In this way, the running tool 322 may lower the hanger 308 with the casing 310 and the seal assembly 304 into the wellhead housing 300, and the seal assembly 304 may remain in the wellhead housing 300 (e.g., aligned with the passage 302 to open the passage 302 to fluid flow) during the cementing operations. However, the hanger 308 with the casing 310 and the seal assembly 304 may move relative to the wellhead housing 300 after the cementing operations to seal the annular space between the hanger 308 and the wellhead housing 300. In this way, the hanger 308 with the seal assembly 304 may essentially operate as a movable component that selectively seals the annular space (e.g., selectively exposes the passage 302 or seals the passage 302; the passage 302 operates as a bypass passage). Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 308 to the wellhead housing 300 after the cementing operations.
Advantageously, with reference to the inset provided in
As shown in an inset provided in
Various features of the wellhead housing 350 and the hanger 358 may facilitate efficient running, cementing, and sealing operations. For example, a running tool 372 may run the hanger 358 with the seal assembly 354 into the wellhead housing 350 until the hanger 358 reaches a landed position in which the hanger 358 is landed on the wellhead housing 350 (e.g., axially facing or radially overlapping surfaces contact one another to block further movement of the hanger 358 relative to the wellhead housing 350 toward the wellbore). In the embodiment shown in
In response to detection of the hanger 358 being in the landed position (e.g., slack off weight), a retainer 380 (e.g., one or more temporary locks, such as one or more hold down screws) may be driven (e.g., via an actuator; via manual operation by an operator) radially inwardly through the wellhead housing 350 (or through a blowout preventer adapter that is coupled to the wellhead housing 350). It should be appreciated that the retainer 380 may have any suitable form, such as one or more retainer screws that are inserted into respective openings 382 (e.g., threaded openings) that are spaced apart or distributed circumferentially about the wellhead housing 350. Further, as described herein, the retainer 380 may block withdrawal of the hanger 358 from the wellhead housing 350 (e.g., at least a portion of the hanger 358 with the seal assembly 354 is maintained between the housing surface 376 of the wellhead housing 350 and the retainer 380 along the axial axis 44).
With the hanger 358 in the landed position as illustrated in
Once the cementing operations are complete, the running tool 372 may raise the hanger 358 until the retainer 380 contacts an upper shoulder 386 of the hanger 358 (or a portion of the running tool 372 that is coupled to the hanger 358). In this position or configuration, which is illustrated in
Further, as shown in
Additional features that may be included in the lock ring 388 are described herein with reference to
Thus, as shown in
In this way, the running tool 372 may lower the hanger 358 with the casing 360 and the seal assembly 354 into the wellhead housing 350, and the seal assembly 354 may remain in the wellhead housing 350 (e.g., aligned with the passage 352 to open the passage 352 to fluid flow) during the cementing operations. However, the hanger 358 with the casing 360 and the seal assembly 354 may move relative to the wellhead housing 350 after the cementing operations to seal the annular space between the hanger 358 and the wellhead housing 350. In this way, the hanger 358 with the seal assembly 354 may essentially operate as a movable component that selectively seals the annular space (e.g., selectively exposes the passage 352 or seals the passage 352; the passage 352 operates as a bypass passage). Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 358 to the wellhead housing 350 after the cementing operations.
Advantageously, with reference to the inset provided in
Further, with reference to the inset provided in
In certain embodiments, the wellhead housing 600 also includes housing protrusions 612 (e.g., teeth). The housing protrusions 612 extend radially inwardly from a radially inner surface of the wellhead housing 600. The housing protrusions 612 may include one or more protrusions stacked axially relative to one another and arranged in a slotted or segmented design, as shown in an inset provided in
In certain embodiments, the hanger 608 also includes hanger protrusions 614 (e.g., teeth). The hanger protrusions 614 extend radially outwardly from a radially outer surface of the hanger 608. The hanger protrusions 614 may include one or more protrusions stacked axially relative to one another and arranged in a slotted or segmented design, as shown in an inset provided in
As shown in
Various features of the wellhead housing 600 and the hanger 608 may facilitate efficient running, cementing, and sealing operations. For example, as shown in
The hanger 608 may be lowered until the hanger 608 contacts or engages one or more surfaces, such as the housing protrusions 612, that blocks further movement of the hanger 608 toward the wellbore. For example, if the hanger protrusions 614 and the housing protrusions 612 are aligned along the circumferential axis 48, the hanger protrusions 614 may land on the housing protrusions 612, which may block the further movement of the hanger 608 toward the wellbore. In such cases, the running tool 616 may be rotated to rotate the hanger 608 until the hanger protrusions 614 and the housing protrusions 612 are offset along the circumferential axis 48. Then, with reference to
As shown in
Further, with the hanger 608 in the landed position, the seal assembly 604 is axially aligned with the one or more grooves 602 formed in the wellhead housing 600, and the one or more grooves 602 are able to provide a bypass for fluid flow across the seal assembly 604. Thus, the fluid flow may travel axially through the radial gaps 626, circumferentially into the one or more grooves 602, and then axially through the one or more grooves 602. In this way, the fluid flow may travel through the unsealed flow paths and the one or more grooves 602 to travel axially across the seal assembly 604 from the first axial position to the second axial position, such as shown by arrows 628. Accordingly, in the landed position, cementing operations may be carried out to cement the casing 610 supported by the hanger 608 in the wellbore.
With reference to
In this position or configuration, which is illustrated in
In certain embodiments, the retractable pin 620 may move into a slot 632 (e.g., recess) formed in the radially outer surface of the hanger 608, which may block back spinning or reverse rotation of the hanger 608 within the wellhead housing 600. Additionally, in certain embodiments, a stop surface 634 may be provided along one side of at least one of the hanger protrusions 614 to contact and block further rotation of the hanger 608 within the wellhead housing 600. In this way, the slot 632 and the stop surface 634 may facilitate reaching and maintaining alignment of the hanger protrusions 614 and the housing protrusions 612 along the circumferential axis 48 after the cementing operations.
Further, the running tool 616 may then be separated from the hanger 608 via any suitable techniques. For example, once the hanger 608 is locked within the wellhead housing 600 (e.g., via engagement between the hanger protrusions 614 and the housing protrusions 612, and with support from the slot 632 and/or the stop surface 634), further rotation of the running tool 616 may break shear pins 636 that couple the annular sleeve 618 to the running tool 616. Accordingly, the running tool 616 may then rotate relative to the annular sleeve 618 and the hanger 608 to unthread from the hanger 608.
In certain embodiments, the annular sleeve 618 is coupled to the running tool 616, such as via pins 638 (e.g., fasteners or screws) that engage an annular grooved formed in the running tool 616. Accordingly, the running tool 616 and the annular sleeve 618 may be driven axially (e.g., away from the wellbore) together to withdraw from the wellhead housing 600. In this way, the running tool 616 may lower the hanger 608 with the casing 610, as well as the seal assembly 604, into the wellhead housing 600. Further, the seal assembly 604 may remain in the wellhead housing 600 (e.g., aligned with the one or more grooves 602; not sealed against the wellhead housing 600) during the cementing operations. However, the hanger 608 with the casing 610, as well as the seal assembly 604, may move relative to the wellhead housing 600 after the cementing operations to seal the annular space between the hanger 608 and the wellhead housing 600. In this way, the hanger 608 with the seal assembly 604 may essentially operate as a movable component that selectively seals the annular space (e.g., selectively opens or seals the groove 602; the one or more grooves 602 operate as a bypass passage). Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 608 to the wellhead housing 600 after the cementing operations.
It should be appreciated that the wellhead housing 600 and the hanger 608 shown in
As shown in
With reference to
As shown in
As shown in
Once the seal assembly 654 and the hanger 658 are locked within the wellhead housing 650, the running tool 662 may be rotated (e.g., in a second rotational direction) to unthread from the hanger 658 and until the running tool 662 separates from the hanger 658. Accordingly, the running tool 662 may lower the hanger 658 with the casing 660, the seal assembly 654, and the lock ring 664 into the wellhead housing 650, and the seal assembly 654 may remain in the wellhead housing 650 during the cementing operations. However, the seal assembly 654 may move relative to the wellhead housing 650 after the cementing operations to seal the annular space between the hanger 658 and the wellhead housing 650, as well as the passage 656. In this way, the seal assembly 654 essentially operates as a movable component that selectively seals the passage 656. Further, in some embodiments, no additional seal packoff elements or steps are utilized to provide the seal the hanger 658 to the wellhead housing 650 after the cementing operations. The seal assembly 654, the running tool 662 (including the support ring 682), and the hanger 658 may have any suitable interfaces that enable the operations and techniques described herein.
In block 702, the method 700 may begin with running a hanger and a seal assembly into a wellhead housing. Other components, such as one or more lock rings, may also be run with the hanger and the seal assembly into the wellhead housing. The seal assembly may include one or more annular seals (e.g., elastomer or metal seals; o-rings) that are configured to seal an annular space between the hanger and the wellhead housing. The seal assembly may include the one or more annular seals supported directly on the hanger (e.g., in grooves formed in a body of the hanger; the seal assembly is integrated into the hanger or is part of hanger), or the seal assembly may include the one or more annular seals supported on an annular ring (e.g., grooves formed in the annular ring) that is coupled to and/or circumferentially surrounds a portion of the hanger.
In block 704, cementing operations may commence once the hanger and the seal assembly are positioned in the wellhead housing. During the cementing operations, the seal assembly and/or another movable seal component (e.g., a piston, a valve, a plug) may be positioned to enable a flow of fluid axially across the seal assembly via a passage formed in or along the wellhead housing.
For example, the passage may include a first opening that is exposed to cement returns between the hanger and the wellhead housing below the seal assembly, as well as a second opening that is exposed to a channel or other path within the wellhead housing above the seal assembly (e.g., the channel or other path may be formed in the hanger, the running tool, and/or the annular space above the seal assembly). The passage may be open (e.g., not sealed, blocked, and/or obstructed by the seal assembly and/or the another movable seal component) to enable the flow of fluid axially across the seal assembly via the passage. As another example, the passage may include a groove (e.g., radially expanded portion; relatively large inner diameter) of the wellhead housing. The groove may be open (e.g., with a radial gap between the hanger and the groove) to enable the flow of fluid axially across the seal assembly via the groove.
In block 706, after the cementing operations, the seal assembly and/or the another movable seal component may be positioned to block the flow of fluid axially across the seal assembly via the passage formed in or along the wellhead housing. For example, the seal assembly may be moved axially relative to the passage to seal against the wellhead housing at a seal location that is axially above (e.g., relative to the wellbore) the passage (e.g., the second opening or outlet of the passage). As another example, the movable component may be a piston that is moved within the passage to fluidly disconnect the first opening from the second opening. As another example, the movable component may be a lock that is inserted to engage a valve (e.g., a check valve) within the passage to fluidly disconnect the first opening from the second opening, or a plug that is inserted into the passage to fluidly disconnect the first opening from the second opening.
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 invention as defined by the following appended claims. For example, while the illustrated embodiments show a hanger and a housing of a wellhead, it should be understood that the systems and methods may be adapted to for use with any of a variety of other annular structures.
Additionally, any features shown or described with reference to
The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical. Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ” or “step for [perform]ing [a function] . . . ”, it is intended that such elements are to be interpreted under 35 U.S.C. 112(f). However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. 112(f).
Claims
1. A wellhead, comprising:
- a wellhead housing;
- a passage formed in or along the wellhead housing;
- a hanger configured to support a casing; and
- a seal assembly configured to provide an annular seal across an annular space between the hanger and the wellhead housing;
- wherein a movable seal component or the seal assembly is configured to move relative to the passage to selectively enable a flow of fluid across the seal assembly via the passage.
2. The wellhead of claim 1, wherein the movable seal component or the seal assembly is configured to move relative to the hanger to selectively enable the flow of fluid across the seal assembly via the passage.
3. The wellhead of claim 1, wherein the movable seal component of the seal assembly is configured to move axially relative to the passage to selectively enable the flow of fluid across the seal assembly via the passage.
4. The wellhead of claim 1, wherein the movable seal component of the seal assembly is configured to move radially relative to the passage to selectively enable the flow of fluid across the seal assembly via the passage.
5. The wellhead of claim 1, comprising an additional passage formed in or along the wellhead housing, wherein an additional movable seal component or the seal assembly is configured to move relative to the additional passage to selectively enable the flow of fluid across the seal assembly via the additional passage.
6. The wellhead of claim 1, comprising the movable seal component, wherein the movable seal component comprises a piston, a valve, or a plug, and the movable seal component is configured to move relative to the passage to selectively enable the flow of fluid across the seal assembly via the passage.
7. The wellhead of claim 6, wherein the seal assembly is integrated into the hanger, and the movable seal component is configured to move relative to the seal assembly and the hanger to selectively enable the flow of fluid across the seal assembly via the passage.
8. The wellhead of claim 1, wherein the seal assembly is configured to move between a first axial position and a second axial position relative to the passage and relative to the hanger to selectively enable the flow of fluid across the seal assembly via the passage.
9. The wellhead of claim 1, wherein the seal assembly is configured to move relative to the passage to axially align the seal assembly with the passage to enable the flow of fluid across the seal assembly via the passage.
10. The wellhead of claim 9, wherein the seal assembly is configured to move relative to the passage to axially offset the seal assembly from the passage to provide the annular seal across the annular space between the hanger and the wellhead housing to block the flow of fluid across the seal assembly via the passage.
11. The wellhead of claim 9, wherein the seal assembly is positioned axially between an inlet of the passage and an outlet of the passage while the seal assembly is axially aligned with the passage.
12. The wellhead of claim 1, wherein the passage extends through a wall of the wellhead housing.
13. The wellhead of claim 1, wherein the flow of fluid comprises cement returns.
14. A method of operating a wellhead, the method comprising:
- running a hanger and a seal assembly into a wellhead housing;
- routing a flow of fluid across the seal assembly via a passage formed in the wellhead housing during cementing operations with the hanger and the seal assembly in the wellhead housing; and
- after the cementing operations, moving a movable component or the seal assembly relative to the wellhead housing to block the flow of fluid across the seal assembly and to seal an annular space between the hanger and the wellhead housing with the seal assembly.
15. The method of claim 14, wherein the seal assembly is axially aligned with the passage while the seal assembly during the cementing operations.
16. The method of claim 14, comprising, after the cementing operations, moving the seal assembly axially relative to the wellhead housing and relative to the hanger to block the flow of fluid across the seal assembly and to seal the annular space between the hanger and the wellhead housing with the seal assembly.
17. The method of claim 14, comprising, after the cementing operations, moving the movable seal component relative to the wellhead housing and relative to the hanger to block the flow of fluid across the seal assembly and to seal the annular space between the hanger and the wellhead housing with the seal assembly, wherein the movable seal component comprises a piston, a valve, or a plug.
18. The method of claim 16, wherein the flow of fluid comprises cement returns.
19. A wellhead, comprising:
- a wellhead housing;
- a passage formed in the wellhead housing;
- a hanger configured to support a casing; and
- a seal assembly configured to move relative to the hanger between a first axial position and a second axial position within the wellhead housing;
- wherein, in the first axial position, the seal assembly enables a flow of fluid across the seal assembly via the passage;
- wherein, in the second axial position, the seal assembly blocks the flow of fluid across the seal assembly via the passage and provides an annular seal across an annular space between the hanger and the wellhead housing.
20. The wellhead of claim 19, wherein, in the first axial position, the seal assembly is axially aligned with the passage.
Type: Application
Filed: Dec 22, 2023
Publication Date: Jul 16, 2026
Inventors: Andrew SANDERS (Houston, TX), Kyle SOMMERFELD (Houston, TX), Leonard VOGEL (Houston, TX), Nicholas RUFF (Houston, TX), Dennis NGUYEN (Pearland, TX)
Application Number: 19/137,319
