Rotational Lock for Mating Wellhead Components

Abstract

A wellhead (10) with a casing head (20) has tubing (15) in its therethrough. A mating component, such as a pack-off (40), installs in the wellhead on the end of the tubing above a casing hanger (30). The bore (42) of the pack-off defines circumferential grooves—each having a canted spring (100A, 100B) disposed therein. The canted springs engaged between the groove and the tubing and restricting relative rotation between the pack-off and the tubing.

Description

BACKGROUND OF THE DISCLOSURE

Wellheads use casing hangers inside casing heads to support tubing strings in a well. One problem that has existed for some time is how to hold a tubing string and internal features (e.g., hanger, pack-off, etc.) of the wellhead stationary relative to one another during installation operations. Historically, rotational stops have been used to hold the tubing string and internal features in place. The rotational stops include mechanisms such as hardened pins, spring/pawl mechanisms, spring loaded pins, splines, keyways, and threaded connections. All of these mechanisms require the elements to be axially and/or rotationally aligned to function. Any need to make such alignments complicates installation steps in which large components must be lifted and placed to construct the wellhead.

The subject matter of the present disclosure is directed to overcoming, or at least reducing the effects of, one or more of the problems set forth above.

SUMMARY OF THE DISCLOSURE

A component of the present disclosure is used for a wellhead having a throughbore with a tubing component disposed therein. The component comprises a body and at least one canted spring. The body positions in the throughbore of the wellhead. The body defines a bore therethrough, and the bore defines at least one groove thereabout. The bore is disposed at least partially on the tubing component. The at least one canted spring is disposed in the at least one groove and is engaged between the at least one groove and the tubing component. The at least one canted spring restricts rotation of the body relative to the tubing in at least one direction.

The body can further comprise: an internal seal disposed in the bore and sealing against the tubing component; and an external seal disposed about the body and sealing against the throughbore of the wellhead. The bore can define a shoulder engaging a distal end of the tubing component. For example, the body can comprise a pack-off. Accordingly, the component can further include a slip hanger disposed in the throughbore of the wellhead on the tubing component below the pack-off.

The at least one groove can have a number of variations. For example, the groove can define a backwall divided at an angle and engaging coils of the at least one canted spring at two points. The groove can define a groove width configured relative to a coil width to at least partially define the engagement of the at least one canted spring between the at least one groove and the tubing component. The groove can define a groove depth that is configured relative to the internal and outer dimensions of the canted spring to at least partially define the engagement of the at least one canted spring between the at least one groove and the tubing component.

In one particular implementation, a component for a wellhead having a throughbore with a tubing component disposed therein comprises a body and first and second canted springs. As before, the body positions in the throughbore of the wellhead and defines a bore therethrough to at least partially position on the tubing component. The bore defines at first and second grooves thereabout in which first and second canted springs are disposed in the first groove. The springs are engaged between the grooves and the tubing component and preventing rotation of the body relative to the tubing component in opposing directions.

The coils of the first canted spring can define a first pitch; and the coils of the second canted spring can define a second pitch orientated opposite to the first pitch. The two pitches can be the same or different from one another.

According to the present disclosure, a wellhead for tubing comprises a wellhead component defining a throughbore with the tubing passing at partially therethrough. A body with at least one canted spring as details previously can position in the throughbore of the wellhead and can be disposed at least partially on the tubing.

According to the present disclosure, an apparatus comprises first and second components and at least one canted spring. The first component has an outer surface, while the second component defines a bore therethrough and positioning at least partially on the outer surface of the first component. Either the outer surface, the bore, or both define at least one groove thereabout for the at least one canted spring.

A method is disclosed of assembling a wellhead having tubing inside a throughbore. At least one canted spring is positioned in at least one groove defined in a bore of a wellhead component, and the bore of the wellhead component is positioned at least partially on the tubing inside the throughbore of the wellhead. The at least one canted spring is engaged between the at least one groove and the tubing, and rotation of the wellhead component and the tubing is restricted relative to one another in at least one direction with the engagement of the at least one canted spring. In positioning the bore of the wellhead component at least partially on the tubing, the wellhead component can be positioned regardless of axial and radial alignment relative to the tubing.

In positioning the bore of the body at least partially on the tubing, internal and external seals can seal the body against the throughbore of the wellhead. A shoulder defined in the bore can engage against a distal edge of the tubing.

The foregoing summary is not intended to summarize each potential embodiment or every aspect of the present disclosure.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1A illustrates a cross-sectional view of a wellhead having a casing head, casing hangers, a tubing spool, pack-offs and the like, as well as a rotational lock according to the present disclosure.

FIG. 1B illustrates a cross-sectional view of simplified components for a wellhead having a rotational lock according to the present disclosure.

FIGS. 2A-2B illustrate elements of the disclosed rotational lock during stages of assembly.

FIGS. 2C-2E illustrate other arrangements of the disclosed rotational locks.

FIG. 3A illustrates a plan view of a first canted spring of the disclosed rotational lock.

FIG. 3B illustrates a plan view of a second canted spring of the disclosed rotational lock.

FIG. 3C illustrates an elevational view of portion of a coil for the canted springs.

FIG. 4 illustrates a schematic view of the elements of the disclosed rotational lock.

DETAILED DESCRIPTION OF THE DISCLOSURE

FIG. 1A illustrates a cross-sectional view of a wellhead 10 having various components mounted to surface casing 14. As is typical, a casing head 20 mounts with a landing ring 12 on the surface casing 14, and a slip hanger 30 landed in the bowl 25 of the casing head 20 supports an inner casing string 16 downhole. A slip pack-off 40 installs in the casing head 20 above the hanger 30 and mounts on the distal end of the inner casing string 16. The pack-off 40 provides a seal between the casing hanger 30 and the casing head 20.

A tubing spool 50 connects to the casing head 20 with an adapter 24. The tubing spool 50 includes a mandrel pack-off 60 engaged on the slip pack-off 40. Another casing slip hanger 70 mounted in the bowl created by the mandrel pack-off 60 in the tubing spool's bore 52 supports in an inner tubing string 18 on which another slip pack-off 80 installs. Additional components, such as additional tubing spools, blow-out preventer, a tubing head adapter, gate valves of a production tree, and the like, can then install above the tubing spool 50 depending on the current drilling or production stage of the well.

The wellhead 10 can have any variety of configurations, and the present example is only meant to be illustrative. Instead of slip hangers 30 and slip pack-off 40, mandrel hangers can be used with mandrel pack-offs.

The pack-off 40 that installs on the distal end of the inner casing string 16 forms a seal between the casing head's bore 22 and the inner casing 16. To do this, the pack-off 40 includes external seals 46 for sealing against the bore 22 of the casing head 20 and includes internal seals 44 in the bore 42 of the pack-off 40 for sealing against the casing 16.

To prevent rotation, the pack-off 40 further includes at least one rotational lock 100 according to the present disclosure. The rotational lock 100 is disposed in the bore 42 of the pack-off 40 and engages against the casing string 16. Although one rotational lock 100 is shown, additional rotational locks 100 can be used on the same pack-off 40. Additionally, the other pack-off 80 could also include a rotational lock for the inner tubing string 18.

As noted in the background section, there is a need for an engageable rotational locking feature for wellheads or other assemblies to hold the tubing string and installed components stationary during operations. Rather than requiring axial and rotational alignment to function, the rotation lock 100 of the present disclosure allows for components to snap-on/snap-off of tubing with minimal parts and without significant modifications to existing wellhead elements.

For simplified description, FIG. 1B illustrates a cross-sectional view of simplified components for a wellhead 10 having a rotational lock 100 according to the present disclosure. In this simplification, a casing head 20 mounts on surface casing 14, and a casing hanger 30 in the head 20 supports an inner tubing string 15. A pack-off component 40 mounts above the hanger 30 on the distal end of the tubing string 15. The pack-off component 40 includes internal seals 44 for sealing against the tubing 15 and includes external seals 46 for sealing against the throughbore 22 of the casing head 20. In general, the casing hanger 30 can be a slip hanger to which the pack-off component 40 may or may not be affixed.

Two rotational locks 100A-B are disposed in the bore 42 of the pack-off component 40 and are engaged with the tubing 15. Each rotational lock 100A-B prevents rotation of the pack-off component in opposite directions. In this way, during assembly of the wellhead 20, the rotational locks 100A-B prevent the pack-off component 40 from rotating on the distal end of the tubing 15 and likewise prevent the tubing 15 from rotation, as other components are assembled, removed, reassembled, and/or rearranged for the wellhead 10 during any of the various changes made during drilling, completion, and production operations.

FIGS. 2A-2B illustrate elements of the disclosed rotational locks 100A-B during stages of assembly. The elements include a mating component 200 for fitting on the distal end 214 of a tubing component 210, which has an internal bore 212. In general, the mating component 210 can be any internal component of a wellhead or other assembly that mates to tubing. Therefore, the tubing component 210 may be part of or installed on casing or tubing, such as used in a wellhead. Although described in the context of a wellhead, however, the disclosed rotational locks 100A-B can be used for any suitable mating components in a wellbore environment.

As best shown in FIG. 2A, the mating component 200 includes an inner bore 202 having circumferential grooves 206A-B defined thereabout. The bore 202 may also include a stop shoulder 204 and may include seals (not shown). The rotational locks 100A-B include canted springs 110A-B disposed in opposite orientations in the circumferential grooves 206A-B.

When the mating component 200 installs on the distal end 214 of the tubing component 210 as shown in FIG. 2B, the stop shoulder 204 can engage the tubing's edge. To facilitate passage of the springs 110A-B past the edge of the tubing component 210, the distal end 214 may define an outer bevel feature. The canted springs 110A-B of the rotational locks 100A-B engage between the grooves 206A-B and the outer surface of the tubing component 210 to prevent rotation of the mating component 200 in opposite directions. In addition to preventing rotation in one or both directions, the canted springs 110A-B allow free travel axially between the tubing components 200, 210. This means that the rotational lock 200 does not depend on a need for any particular axial or rotational alignment between the components 200, 210.

Although shown in the context of using two canted springs 110A-B oriented in opposite directions, one or more additional canted springs 110 can be used in one or more additional grooves 206. For example, FIG. 2C illustrates four canted springs 110A-D used between the components 200, 210. The various canted springs 110A-D can prevent rotation in either one or both of the directions. In this way, two or more canted springs e.g., 110A-B can work in tandem in one direction to support additional loading. Additionally or alternatively, two or more other canted springs e.g., 110C-D can work in tandem in the opposite direction. Overall, the tandem support can increase the rotational resistance of the lock depending on the application.

Although shown in the context of the mating component 200 having a bore 202 (with the grooves 206A-B and the canted springs 110A-B) that fits on the cylindrical outer surface of the tubing component 210, a reverse arrangement could be used. For example, FIG. 2D illustrates a tubing component 210, provided it has a sidewall of significant thickness, that has external grooves 216 in which the canted springs 110C-D are positioned. The tubing component 210 can then fit at least partially in the mating component's bore 202 so the canted springs 110C-D engage against the inner cylindrical surface of the bore 202 to prevent rotation.

Moreover, an assembly may use one or more internal canted springs 110A-B in the bore 202 of the mating component 200 combined with one or more external canted springs 100C-D on the tubing component 210. For example, FIG. 2E illustrates first canted springs 110A-B for preventing rotation in a first direction can be used in internal grooves 206 of the mating component 200, while second canted springs 110C-D for preventing rotation in an opposite direction can be used on external grooves 216 of the tubing component 210. Each pair can alternatively prevent rotation in both directions.

These and other tandem, reverse, and combined arrangements of FIGS. 2A-2E can be used on any of the various arrangements disclosed herein.

FIG. 3A illustrates a plan view of a first canted spring 110A of the disclosed rotational lock 100, and FIG. 3B illustrates a plan view of a second canted spring 110B of the disclosed rotational lock 100. The canted springs 110A-B can be composed of a suitable material for wellhead applications, including metallic material, plastic, glass, composite, etc.

These two canted springs 110A-B each have coils 112 angled at opposite pitches P relative to one another. The amount of pitch P for both may be the same or different from one another. In fact, the two springs 110A-B may be identical to one another, but flipped relative to one another when installed in the component.

In general, the springs 110A-B have inner diameters ID and outer diameters OD configured for the implementation at hand, such as the outer diameter of the tubing component (210) and the inner dimension of the circumferential groove (206) between which the spring 110 engages. Additionally, the coils 112 have a general coil width (CW) as shown in FIG. 3C. Each of these various dimensions ID, OD, CW, P, and the like are configured for the implementation at hand.

Each of the canted springs 110A-B may have the same OD and ID, but assemblies may use other combinations. For example, the canted springs 110A-B may have different IDs, different ODs, or both different IDs and ODs. Additionally, each of the canted springs 110A-B do not have to be disposed in similar grooves 206 in the mating component 200 and do not need to engage the same surface of the tubing component 210 to function as lock. Accordingly, one spring 110A may have one or more different dimensions compared to the other spring 110B, one of the grooves 206A may have one or more different dimensions compared to the other grooves 206B, and the surface against which the springs 110A-B engage do not need to be the same surface (i.e., they can have different surfaces with different diameters).

For example, FIG. 4 illustrates a schematic view of the elements of the disclosed rotational lock 100 during engagement. The circumferential groove 206 in the mating component 200 includes a divided backwall defining an angle θ. The divided backwall allows for two points of engagement against the coils 112 of the spring 110. The groove 206 is defined at a groove depth SD and has a groove width SW. The tubing component 210 fits at a clearance C relative to the component 200 having the exposed canted spring 110.

Each of these dimensions SW, SD, θ, and C combined with the dimensions ID, OD, CW, P of the canted spring 110 operate together for the canted spring 110 to engage between the tubing component 210 and the groove 206 and prevent relative rotation between the tubing component 210 and the mating component 200. For example, the groove width SW combined with the coil width CW and the groove depth SD combined with the difference between the inner and outer dimensions ID, OD of the canted spring 110 as well as the clearance C define the amount of engagement.

As noted in the background of the present disclosure, historical solutions require predefined axial positions to engage features such as pins, pawls, splines, etc. to prevent rotation. Traditional solutions also require predefined rotational alignment to engage these types of features. This rotational lock 100 of the present disclosure is not dependent on rotational alignment and can engage at any rotational angle. This allows for axial movement for positioning the tubular elements and can remove the need to rotate the tubular elements at any axial position even during up and down tubing movement.

As disclosed herein, the rotation lock 100 includes one or more canted springs 110 in corresponding grooves 206. Each canted spring 110 prevent rotation in one direction so rotation can be prevented in opposing directions by the opposing canted springs 110A-B. Utilizing two opposing springs 110A-B with grooves 206A-B allows the tubing component 210 to be engaged and disengaged repeatedly without wear or damage during installation.

As will be appreciated during assembly of a wellhead during stages of drilling, completion, and eventual preparation for production, various wellhead components are installed one on top of the other on and inside the wellhead, can be installed by passing through other components, such as a blow-out preventer, or can be installed while other components are lifted out of the way. The challenges involved in completing these various assembly steps can be simplified by the disclosed rotational locks 100.

The foregoing description of preferred and other embodiments is not intended to limit or restrict the scope or applicability of the inventive concepts conceived of by the Applicants. It will be appreciated with the benefit of the present disclosure that features described above in accordance with any embodiment or aspect of the disclosed subject matter can be utilized, either alone or in combination, with any other described feature, in any other embodiment or aspect of the disclosed subject matter.

In exchange for disclosing the inventive concepts contained herein, the Applicants desire all patent rights afforded by the appended claims. Therefore, it is intended that the appended claims include all modifications and alterations to the full extent that they come within the scope of the following claims or the equivalents thereof.

Claims

1. A component for a wellhead having a throughbore with a tubing component disposed therein, the component comprising: a body positioning in the throughbore of the wellhead, the body defining a bore therethrough, the bore defining at least one groove thereabout, the bore disposed at least partially on the tubing component; andat least one canted spring disposed in the at least one groove and engaged between the at least one groove and the tubing component, the at least one canted spring restricting rotation of the body relative to the tubing in at least one direction.

2. The component of claim 1, wherein the body further comprises: an internal seal disposed in the bore and sealing against the tubing component; andan external seal disposed about the body and sealing against the throughbore of the wellhead.

3. The component of claim 1, wherein the bore defines a shoulder engaging a distal end of the tubing component.

4. The component of claim 1, wherein the body comprises a pack-off.

5. The component of claim 4, further comprising a slip hanger disposed in the throughbore of the wellhead on the tubing component below the pack-off.

6. The component of claim 1, wherein the at least one groove defines a backwall divided at an angle and engaging coils of the at least one canted spring at two points.

7. The component of claim 1, wherein the at least one groove defines a groove width; and wherein the at least one canted spring defines a coil width, the groove width and the coil width being configured to at least partially define the engagement of the at least one canted spring between the at least one groove and the tubing component.

8. The component of claim 1, the at least one groove defines a groove depth; and wherein the at least one canted spring defines a difference between an inner dimension and an outer dimension, the groove depth and the difference being configured to at least partially define the engagement of the at least one canted spring between the at least one groove and the tubing component.

9. The component of claim 1, wherein the at least one groove comprises first and second grooves; andwherein the at one canted spring comprises: a first canted spring disposed in the first groove and engaged between the first groove and the tubing component, the first canted spring preventing rotation of the body relative to the tubing component in a first direction; anda second canted spring disposed in the second groove and engaged between the second groove and the tubing component, the second canted spring preventing rotation of the body relative to the tubing component in a second direction opposite to the first direction.

10. The component of claim 9, wherein coils of the first canted spring define a first pitch; and wherein coils of the second canted spring define a second pitch orientated opposite to the first pitch.

11. The component of claim 10, wherein the first pitch is the same as the second pitch.

12. A wellhead for tubing, comprising: a first wellhead component defining a throughbore with the tubing passing at partially therethrough; anda second wellhead component according to claim 1 comprising the body and the at least one canted spring.

13. An apparatus, comprising: a first component having an outer surface;a second component defining a bore therethrough and positioning at least partially on the outer surface of the first component, wherein at least one of the outer surface of the first component and the bore of the second component defines at least one groove thereabout; andat least one canted spring disposed in the at least one groove and engaged between the at least one groove and the other of outer surface and the bore, the at least one canted spring restricting rotation of the first and second components relative to one another in at least one direction.

14. The apparatus of claim 13, wherein the outer surface of the first component defines a first of the at least one groove thereabout; and wherein a first of the at least one canted spring is disposed in the first groove and is engaged between the first groove and the bore of the second component, the first canted spring restricting rotation of the first and second components relative to one another in a first of the at least one direction.

15. The apparatus of claim 14, wherein the outer surface of the first component defines a second of the at least one groove thereabout; and wherein a second of the at least one canted spring is disposed in the second groove and is engaged between the second groove and the bore of the second component, the second canted spring restricting rotation of the first and second components relative to one another in a second of the at least one direction opposite to the first direction.

16. The apparatus of claim 13, wherein the bore of the second component defines a first of the at least one groove thereabout; and wherein a first of the at least one canted spring is disposed in the first groove and is engaged between the first groove and the outer surface of the first component, the first canted spring restricting rotation of the first and second components relative to one another in a first of the at least one direction.

17. The apparatus of claim 16, wherein the outer surface of the first component defines a second of the at least one groove thereabout; and wherein a second of the at least one canted spring is disposed in the second groove and is engaged between the second groove and the bore of the first component, the second canted spring restricting rotation of the first and second components relative to one another in a second of the at least one direction opposite to the first direction.

18. The apparatus of claim 17, wherein the first and second grooves have one or more groove dimensions that are the same or different, and wherein the first and second canted springs have one or more spring dimensions that are the same or different.

19. The apparatus of claim 16, wherein the bore of the second component defines a second of the at least one groove thereabout; and wherein a second of the at least one canted spring is disposed in the second groove and is engaged between the second groove and the outer surface of the first component, the second canted spring restricting rotation of the first and second components relative to one another in a second of the at least one direction opposite to the first direction.

20. A method of assembling a wellhead having tubing inside a throughbore, the method comprising: positioning at least one canted spring in at least one groove defined in a bore of a wellhead component;positioning the bore of the wellhead component at least partially on the tubing inside the throughbore of the wellhead;engaging the at least one canted spring between the at least one groove and the tubing; andrestricting rotation of the wellhead component and the tubing relative to one another in at least one direction with the engagement of the at least one canted spring.

21-24. (canceled)

25. The method of claim 20, wherein positioning the at least one canted spring in the at least one groove defined in the bore of the body comprises: positioning a first of the at least one canted springs in a first of the at least one groove; andpositioning a second of the at least one canted springs disposed in a second of the at least one groove.

26. The method of claim 25, wherein engaging the at least one canted spring and preventing the rotation comprises: engaging the first canted spring between the first groove and the tubing and preventing the rotation of the body relative to the tubing in a first of the at least one direction; andengaging the second canted spring between the first groove and the tubing and preventing the rotation of the body relative to the tubing in a second of the at least one direction opposite to the first direction.

27. The method of claim 25, wherein coils of the first canted spring define a first pitch; and wherein coils of the second canted spring define a second pitch orientated opposite to the first pitch.

28. The method of claim 27, wherein the first pitch is the same as the second pitch.

29-31. (canceled)