Key information

Title: ORIENTATION TOOLS FOR TUBING HANGERS
Application number: 20260330
Case type: National
Status: 12.03.2026 Første realitetsuttalelse foreligger
Filed: 12.03.2026
Priority: 12.03.2025 US 63/770,567 and others
Effective date: 12.03.2026
Publicly available: 14.09.2026
Next annual fee due: 31.03.2028
Applicant: OneSubsea AS (NO)
Inventor: Robert Karl Johansson (NO) et al.
Agent: HÅMSØ PATENTBYRÅ AS (NO)

Abstract and drawing

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content.

An orientation tool and related landing assemblies and methods for adjusting an angular orientation of a tubing hanger in a wellhead system are disclosed. In some embodiments, a landing assembly includes a tubing hanger and an orientation tool coupled to and configured to adjust an angular orientation of the tubing hanger. The orientation tool includes an angular adjustment assembly comprising a piston. Actuation of the piston is configured to rotate the tubing hanger. The orientation tool further includes a control module comprising one or more sensors and a valve assembly. The control module is configured to determine the tubing hanger angular orientation using the one or more sensors and to rotate the tubing hanger via the valve assembly and piston based on the orientation.

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Date

Date	Doc. No.	Process	Case number	In/Out	Journal description	To/from
19.10.2026	04-02	Saksbehandling	20260330	UT	PT report 01:56:29
19.10.2026	04-01	Saksbehandling	20260330	UT	Substantive Examination	HÅMSØ PATENTBYRÅ AS
27.05.2026	03-03	Saksbehandling	20260330	INN	P32086NO00 Letter_NIPO	HÅMSØ PATENTBYRÅ AS
27.05.2026	03-02	Saksbehandling	20260330	INN	IS250328NO_POA_2551134	HÅMSØ PATENTBYRÅ AS
27.05.2026	03-01	Saksbehandling	20260330	INN	Korrespondanse (Hovedbrev inn)	HÅMSØ PATENTBYRÅ AS
13.03.2026	02-01	Saksbehandling	20260330	UT	Formal Examination 1	HÅMSØ PATENTBYRÅ AS
12.03.2026	01-03	Saksbehandling	20260330	INN	P32086NO00 - Specification - TO BE FILED - 2026 03 12	HÅMSØ PATENTBYRÅ AS
12.03.2026	01-02	Saksbehandling	20260330	INN	P32086NO00 - Drawings - TO BE FILED - 2026 03 12	HÅMSØ PATENTBYRÅ AS
12.03.2026	01-01	Saksbehandling	20260330	INN	Søknadsskjema Patent	HÅMSØ PATENTBYRÅ AS

Description, claims and drawings

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content.

Description

ORIENTATION TOOLS FOR TUBING HANGERS

CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] This application claims priority to and the benefit of United States provisional patent application number 63/770,567 filed on March 12, 2025, entitled “Active Orientation System for Tubing Hangers,” and United States provisional patent application number 63/771,421 filed on March 13, 2025, entitled “Active Orientation System for Tubing Hangers,” the contents of each are incorporated herein by reference.

BACKGROUND

[0002] A wellhead system includes a wellhead located at the upper end of a wellbore and a tubing hanger secured to the wellhead. The tubing hanger supports a tubing string that extends into the wellbore and provides a conduit for the flow of formation fluids to the surface. In some arrangements, the tubing hanger is supported directly by the wellhead.

[0003] For a subsea wellhead, during completion operations, a blowout preventer (BOP) may be installed on the wellhead (or on a tubing spool), and a riser extends upward from the BOP to a surface rig or vessel. The tubing hanger and its associated production tubing may be installed by attaching a tubing hanger running tool to the tubing hanger and lowering the assembly through the riser toward the wellhead using a landing string. Once positioned, the tubing hanger is landed at the desired location in the tubing spool or wellhead. The running tool can then be disconnected from the tubing hanger, and the landing string and running tool are retrieved to the surface.

[0004] The well is then prepared for completion by removing the riser and BOP. A valve tree (sometimes referred to as a “Christmas tree”) is subsequently mounted on the wellhead housing (or tubing spool) and connected, via a tie-in arrangement, to production flowlines that transport formation fluids from the wellbore.

SUMMARY

[0005] Some embodiments disclosed herein are directed to landing assemblies for installing a tubing hanger in a wellhead and for adjusting an angular orientation of the tubing hanger during installation. In some embodiments, a landing assembly includes a tubing hanger and an orientation tool coupled to the tubing hanger and configured to adjust an angular orientation of the tubing hanger. The orientation tool includes an angular adjustment assembly comprising a piston, where actuation of the piston is configured to rotate the tubing hanger. The orientation tool further includes a control module comprising one or more sensors and a valve assembly. The control module is configured to determine the angular orientation of the tubing hanger by use of the one or more sensors and to actuate the valve assembly to actuate the piston and rotate the tubing hanger based on the angular orientation.

[0006] Some embodiments disclosed herein are directed to orientation tools for adjusting an angular orientation of a component in a wellhead system. In some embodiments, an orientation tool includes an outer housing, an inner mandrel received in the outer housing and configured to be coupled to the component, an angular adjustment assembly coupled between the outer housing and the inner mandrel and comprising a piston, and a control module coupled to the inner mandrel and comprising one or more sensors and a valve assembly. The control module is configured to determine the angular orientation of the inner mandrel by use of the one or more sensors and to actuate the valve assembly to actuate the piston and rotate the inner mandrel based on the angular orientation.

[0007] Some embodiment disclosed herein are directed to methods of landing a tubing hanger in a wellhead. In some embodiments, a method includes lowering a landing assembly through a blowout preventer (BOP) to position the tubing hanger in the wellhead, positioning an orientation tool of the landing assembly in a bore of the BOP during the lowering, locking an outer housing of the orientation tool to the bore of the BOP, actuating a piston of the orientation tool to rotate an inner mandrel relative to the outer housing, and rotating the tubing hanger as a result of actuating the piston.

[0008] Some embodiments disclosed herein are directed to landing assemblies for installing a tubing hanger in a wellhead and for adjusting an angular orientation of the tubing hanger during installation. In some embodiments, a landing assembly includes a tubing hanger and an orientation tool coupled to the tubing hanger and configured to adjust an angular orientation of the tubing hanger. The orientation tool includes an outer housing and an inner mandrel coaxially positioned in the outer housing along a central axis, where the inner mandrel is coupled to the tubing hanger. The orientation tool further includes a piston positioned radially between the outer housing and the inner mandrel. Axial translation of the piston is configured to rotate the inner mandrel about the central axis.

[0009] Some embodiments disclosed herein are directed to orientation tools for adjusting an angular orientation of a component in a wellhead system. In some embodiments, an orientation tool includes an outer housing and an inner mandrel coaxially received in the outer housing along a central axis, where the inner mandrel is configured to be coupled to the component. The orientation tool further includes an angular adjustment assembly coupled between the outer housing and the inner mandrel, where the angular adjustment assembly comprises a piston. Axial actuation of the piston is configured to rotate the inner mandrel relative to the outer housing.

BRIEF DESCRIPTION OF THE DRAWINGS

[0010] For a detailed description of various exemplary embodiments, reference will now be made to the accompanying drawings in which:

[0011] FIG. 1 is a schematic cross-sectional view of a subsea wellhead system and a landing assembly for installing a tubing hanger in the wellhead system according to some embodiments disclosed herein;

[0012] FIGS. 2–5 are schematic cross-sectional views of an orientation tool of the landing assembly of FIG. 1 according to some embodiments disclosed herein; and

[0013] FIG. 6 is a flowchart illustrating a method for landing a tubing hanger in a wellhead according to some embodiments disclosed herein.

DETAILED DESCRIPTION

[0014] As previously described, a tubing hanger may be installed in a wellhead through a blowout preventer (BOP) using a tubing hanger running tool and running string. After installation, the BOP may be removed, and a valve tree may be secured to the wellhead to enable connection to production flowlines or other subsea infrastructure.

[0015] To facilitate proper make-up of tie-in connections between the valve tree and the production flowlines, it is generally desirable to land the valve tree in a predetermined angular orientation relative to the wellhead and any associated external structures, such as a permanent guide base or template. Even minor rotational deviations of the valve tree about the longitudinal axis of the wellhead can complicate proper engagement of the tie-in connectors and, in some cases, may prevent successful connection without repositioning.

[0016] Tubing hangers often provide conduits that enable communication between topside equipment and the region of the wellhead located below the tubing hanger. These conduits may support fluid flow or provide pathways for the transmission of electrical or optical signals to operate or monitor sensors and other wellbore equipment. Stab connectors or similar interfaces may be positioned at the upper end of the tubing hanger to facilitate connection to these conduits, and corresponding connectors on the valve tree engage the stab connectors when the valve tree is landed on the wellhead. Because the valve tree must properly mate with these tubing-hanger connections, the angular orientation of the valve tree is typically dictated by the orientation of the tubing hanger relative to the wellhead. Accordingly, it is important to ensure that the tubing hanger is correctly oriented about its axis when landed in the wellhead.

[0017] Accordingly, embodiments disclosed herein are directed to orientation tools that may be configured to adjust the angular orientation of a tubing hanger during installation of the tubing hanger into a subsea wellhead. In some embodiments, the orientation tool includes an outer housing that is selectively lockable to a bore of a BOP, an inner mandrel coupled to the tubing hanger, and an angular adjustment assembly disposed between the outer housing and the inner mandrel that is configured to rotate the inner mandrel relative to the outer housing about a central axis. In some embodiments, the orientation tool includes a control module that is configured to determine an angular orientation of the inner mandrel and to actuate the angular adjustment assembly to rotate the inner mandrel, thereby enabling closed-loop adjustment of tubing hanger orientation within the BOP to ensure tubing hanger angular alignment for successful valve tree tie-in connections.

[0018] FIG. 1 illustrates an example subsea wellhead system 10 and a landing assembly 50 for installing a tubing hanger 80 in the wellhead system 10. As shown, the wellhead system 10 is positioned at an upper end of a wellbore 12 that extends through the seafloor 5. In some embodiments, a liner 13 (such as casing or a primary conductor) is disposed in at least a portion of the wellbore 12 (e.g., cemented in place) and is coupled to, or otherwise supported by, a wellhead 14 positioned at the upper end of the wellbore 12. The wellhead 14 may include, or may be coupled to, a landing shoulder 17.

[0019] A blowout preventer (BOP) 16 is coupled to an upper end of the wellhead 14 (such as directly or indirectly through a tubing spool or other components or structures). The BOP 16 includes a bore 20 through which tubular strings and tools may be conveyed, and further includes one or more rams 22 (e.g., pipe rams, shear rams, blind rams, variable bore rams, casing rams, or combinations thereof) operable to control flow and/or to selectively seal within the bore 20 during operations. A riser 18 may extend upward from the BOP 16 toward the sea surface (not shown) to provide a passageway for running equipment into and out of the wellhead system 10 during completion or intervention operations.

[0020] The landing assembly 50 is configured to be conveyed through the riser 18 and the BOP 16 to land the tubing hanger 80 in the wellhead 14. The tubing hanger 80 may be configured to support production tubing 84 that extends downward into the wellbore 12. The tubing hanger 80 may include a landing shoulder 82 that is configured to land on, and be supported by, the landing shoulder 17 of the wellhead 14. In the illustrated embodiment, the landing assembly 50 includes a tubing hanger running tool 70 coupled to the tubing hanger 80 to facilitate running and landing the tubing hanger 80. The landing assembly 50 also includes an orientation tool 100 positioned uphole of the tubing hanger running tool 70. One or more connection subs 60 (e.g., slick joints, connectors, or other tubular subs) may be provided between the orientation tool 100 and the tubing hanger running tool 70, and/or between other components of the landing assembly 50, to provide a desired spacing, connection interface, and/or structural continuity along the landing assembly 50.

[0021] During an example installation sequence, the landing assembly 50 is lowered from the sea surface through the riser 18 and into the bore 20 of the BOP 16, thereby conveying the tubing hanger 80 and production tubing 84 toward the wellhead 14. As the landing assembly 50 is lowered, the tubing hanger 80 is positioned in the wellhead 14 such that the landing shoulder 82 of the tubing hanger 80 approaches and, in some embodiments, engages the landing shoulder 17 of the wellhead 14. In this position, the tubing hanger 80 may be generally landed (such as temporarily suspended) in the wellhead 14 while still permitting adjustment of angular orientation, as described herein.

[0022] In general, the orientation tool 100 is configured to adjust an angular orientation of the tubing hanger 80 relative to the wellhead system 10 (e.g., relative to the wellhead 14 and/or the BOP 16) to facilitate alignment of subsequently installed equipment, such as a valve tree and associated interface connectors and tie-in connections as previously described. For example, in some embodiments the orientation tool 100 may be selectively locked or secured to the bore 20 of the BOP 16 to provide a rotational reaction point, and may be actuated to rotate an inner portion of the orientation tool 100 (and thus the tubing hanger 80) about a central axis. As illustrated in FIG. 1, the orientation tool 100 may be positioned in a portion of the bore 20 such that the orientation tool 100 may engage with the inner surface of the bore 20 without interfering with (or potentially without occluding) the rams 22.

[0023] Further details of exemplary embodiments of the orientation tool 100, including example structures and actuation arrangements for adjusting angular orientation, are described later in the application with reference to subsequent figures. Once the tubing hanger 80 is fully landed and installed in the wellhead 14, the tubing hanger 80 may be considered a component of the wellhead system 10.

[0024] FIGS. 2–4 illustrate an example embodiment of an orientation tool 100 positioned within a bore 20 of a blowout preventer (BOP) for adjusting an angular orientation of a tubing hanger during installation. With particular reference to FIG. 2, the orientation tool 100 extends along a central or longitudinal axis 115 (or “central axis” or “axis”). The orientation tool 100 includes an outer housing 120 and an inner mandrel 110 coaxially positioned in the outer housing 120 along the axis 115.

[0025] The outer housing 120 is a generally cylindrical member defining an inner bore 122 that extends along the axis 115. The inner mandrel 110 is also a generally cylindrical member having an upper end 110a and a lower end 110b opposite the upper end 110a. The inner mandrel 110 defines a central bore 112 and includes a radially outer surface 113 extending axially between the upper end 110a and the lower end 110b.

[0026] In some embodiments, the inner mandrel 110 is configured to be coupled to a tubing hanger 80 (e.g., directly, or indirectly through the tubing hanger running tool 70 and one or more connection subs 60 shown in FIG. 1) such that rotation of the inner mandrel 110 about the axis 115 corresponds to rotation of the tubing hanger 80 about a longitudinal axis of the wellhead system. Specifically, in some embodiments, the lower end 110b of the inner mandrel 110 may be coupled to the tubing hanger 80 (FIG. 1), again either directly or indirectly as previously described.

[0027] The outer housing 120 includes a plurality of gripping assemblies 130 that are configured to selectively engage the bore 20 of the BOP 16 (FIG.1). Each gripping assembly 130 may be positioned in a corresponding pocket 124 (also referred to as a recess) defined in the outer housing 120. Each gripping assembly 130 includes a gripper 132 coupled to (or integrated with) a piston 134, and the piston 134 may sealingly engage inner walls of the corresponding pocket 124.

[0028] The gripper 132 is configured to frictionally engage with the bore 20 when extended radially outward of the pocket 124 relative to the axis 115. In some embodiments, the gripper 132 includes teeth, hardened coatings, inserts, and/or selected materials that are configured to enhance frictional contact with an inner surface of the bore 20. In some embodiments, the gripper 132 may comprise soft-alloy steel to prevent the gripper 132 from causing damage (such as indents, scratches, etc.) to the bore 20. During operation, pressurized fluid (such as pressurized fluid provided from the pressurized fluid source 182 as described in more detail herein) may be directed into the pocket 124 behind the piston 134. The hydraulic pressure provided by the pressurized fluid may then drive the piston 134 and gripper 132 radially outward and away from the axis 115 to engage the gripper 132 with the inner surface of the bore 20. Extending the grippers 132 may fix an axial position and an angular position of the outer housing 120 within the bore 20 during operations. FIG. 3 illustrates the grippers 132 in an expanded state in which the grippers 132 extend from the outer housing 120 and engage the inner wall of the bore 20.

[0029] It should be appreciated that, although the illustrated embodiment describes hydraulic actuation to radially expand the grippers 132, other actuation systems and methods may be used in other embodiments to move the grippers 132 between a retracted position and an expanded position for engagement with the bore 20. By way of example, the grippers 132 may be actuated by electromechanical actuators (e.g., electric motors driving lead screws, worm gears, or rackand-pinion mechanisms), by pneumatic actuation, by shape-memory or other electrically driven material actuators, and/or by mechanically driven arrangements that are energized by axial movement or rotation of a mandrel (e.g., camming surfaces, wedges, tapered sleeves, or colletstyle expanders). In some embodiments, the grippers 132 may additionally or alternatively be biased toward the retracted position by one or more springs and driven toward the expanded position by any of the foregoing actuation systems, thereby facilitating repeatable engagement and disengagement during installation operations.

[0030] The gripping assemblies 130 may be circumferentially spaced about the axis 115. In some embodiments, the gripping assemblies 130 are uniformly circumferentially spaced about the axis 115, although non-uniform circumferential spacing is also contemplated. Any suitable number of gripping assemblies 130 may be included. For example, in some embodiments, the orientation tool 100 includes six gripping assemblies 130, although more or fewer than six gripping assemblies 130 may be used.

[0031] In some embodiments, the gripping assemblies 130 are configured to run undersize while being conveyed through the BOP (including through a BOP flex joint). In some embodiments, the grippers 132 may comprise reaction dogs that are actuated by a plurality of pistons (e.g., six pistons) and may be configured to be self-retracting to provide fail-safe disengagement. In some embodiments, each gripping assembly 130 includes a seal pack, a piston body, a piston retainer, one or more fasteners, and a spring stack, and the gripping assemblies 130 may be configured to be accessible when assembled to the landing string to facilitate troubleshooting or repair.

[0032] Referring primarily again to FIG.2, the orientation tool 100 further includes an angular adjustment assembly 140 positioned between the outer housing 120 and the inner mandrel 110. In some embodiments, the angular adjustment assembly 140 includes a piston 160 and a sleeve 150 engaged between the outer housing 120 and the inner mandrel 110. The outer housing 120 defines an annular recess 142 (or more simply a “recess”) in the inner bore 122, and the annular recess 142 extends radially outward from the inner bore 122. The sleeve 150 and the piston 160 are at least partially positioned in the annular recess 142.

[0033] The sleeve 150 is a generally cylindrical member including a radially inner surface 152 and a radially outer surface 154, wherein the radially outer surface 154 is radially outward from the radially inner surface 152 relative to the axis 115. The radially inner surface 152 is engaged with the radially outer surface 113 of the inner mandrel 110 via a keyed connection (or “splined connection”). In the illustrated embodiment, the radially inner surface 152 includes a plurality of splines 156 (or “keys”). Each spline 156 extends axially relative to the axis 115 and includes an upper end 156a and a lower end 156b opposite the upper end 156a along the axis 115. The splines 156 may be circumferentially spaced about the radially inner surface 152, such as uniformly circumferentially spaced about the axis 115.

[0034] The splines 156 are inserted in a plurality of slots 114 defined on the radially outer surface 113 of the inner mandrel 110, although the keyed connection may be reversed such that the inner mandrel 110 includes splines and the sleeve 150 includes slots. Each slot 114 may define an upper shoulder 114a and a lower shoulder 114b that is opposite the upper shoulder 114a along the axis 115. In some embodiments, an axial length of each spline 156 (measured axially between the upper end 156a and the lower end 156b) is less than an axial length of each slot 114 (measured axially between the upper shoulder 114a and the lower shoulder 114b), such that the engaged splines 156 and slots 114 allow axial translation between the inner mandrel 110 and the sleeve 150 while maintaining rotational coupling therebetween. Accordingly, the keyed connection is configured to allow axial translation of the inner mandrel 110 relative to the sleeve 150 while causing the sleeve 150 and the inner mandrel 110 to rotate together about the axis 115 during operations. In some embodiments, axial travel of the inner mandrel 110 relative to the sleeve 150 is limited by engagement between the upper shoulders 114a and the spline upper ends 156a and by engagement between the lower shoulders 114b and the spline lower ends 156b.

[0035] The piston 160 is engaged radially between the sleeve 150 and an inner wall 146 of the annular recess 142 in the outer housing 120 relative to axis 115. The piston 160 is a cylindrical member having a radially inner surface 162 and a radially outer surface 164, wherein the radially outer surface 164 is radially outward from the radially inner surface 162 relative to the axis 115.

[0036] A plurality of first helical teeth 166 is defined on the radially inner surface 162 of the piston 160, and a plurality of second helical teeth 168 is defined on the radially outer surface 164 of the piston 160. The first helical teeth 166 extend in a first helical direction about the axis 115, and the second helical teeth 168 extend in a second helical direction about the axis 115, wherein the second helical direction is opposite the first helical direction.

[0037] The first helical teeth 166 are meshed with a plurality of helical teeth 158 defined on the radially outer surface 154 of the sleeve 150. The second helical teeth 168 are meshed with a plurality of helical teeth 144 defined on the inner wall 146 of the annular recess 142. The helical teeth 158 on the sleeve 150 may extend in the same helical direction as the first helical teeth 166, and the helical teeth 144 on the inner wall 146 may extend in the same helical direction as the second helical teeth 168, thereby providing opposing helical directions at the two meshed interfaces.

[0038] The piston 160 includes one or more seals 169 that are configured to sealingly engage the inner wall 146 and the radially outer surface 154 of the sleeve 150. In some embodiments, the seals 169 may be positioned axially adjacent to (such as axially below) the first helical teeth 166 and the second helical teeth 168. The seals 169 may at least partially seal off an annular chamber 148 that is defined in the annular recess 142 by the piston 160, the inner wall 146, and the sleeve 150.

[0039] During operation, pressurized fluid may be selectively supplied to the annular chamber 148 to axially translate the piston 160 relative to the outer housing 120 and the sleeve 150. FIG.

4 illustrates an example actuation state of the orientation tool 100 in which the piston 160 has been displaced axially as a result of pressurization of the annular chamber 148.

[0040] As illustrated by the sequence from FIG.3 to FIG.4, pressurized fluid delivered to the annular chamber 148 urges the piston 160 axially (e.g., upward toward the upper end 110a in the illustrated orientation). With the outer housing 120 rotationally restrained by engagement of the grippers 132 with the bore 20 as shown in FIG. 3, meshing between the second helical teeth 168 and the helical teeth 144 on the inner wall 146 causes the piston 160 to rotate about the axis 115 as the piston 160 translates axially within the recess 142. Meshing between the first helical teeth 166 and the helical teeth 158 on the sleeve 150 transmits the piston rotation to the sleeve 150. Because the helical directions of the first and second helical teeth 166, 168 are opposite, the piston 160 and the sleeve 150 rotate in the same direction about the axis 115 in response to the axial actuation of the piston 160. The keyed connection between the sleeve 150 and the inner mandrel 110 then transmits torque to rotate the inner mandrel 110 about the axis 115 as a result of axial actuation of the piston 160, while optionally permitting the inner mandrel 110 to translate axially relative to the sleeve 150 within the limits established by the splines 156 and slots 114 as previously described. In some embodiments, the meshing of the helical teeth 144, 168, 166, 158 may be configured to double the degree of rotation of the inner mandrel 110 versus axial movement thereof, so that a high torque capacity and large angular stroke may be achieved in a relatively compact arrangement for the angular adjustment assembly 140.

[0041] In some embodiments, the helical teeth described herein (e.g., helical teeth 144, 158, 166, 168) may be formed with a selected helix angle to provide a desired relationship between axial stroke and angular rotation, as well as a desired torque capacity. By way of example, the helical teeth may have a helix angle of about 30° to about 80°, such as about 40° to about 70°, or such as about 60°, relative to axis 115.

[0042] In some embodiments, the piston 160 may additionally be actuated in an axially downward direction (e.g., toward the lower end 110b of inner mandrel 110) to rotate the inner mandrel 110 in an opposite rotational direction about the axis 115. For example, the piston 160 may be driven axially downward by bleeding, venting, or otherwise reducing pressure in the chamber 148 to allow a return force (e.g., gravity, a spring bias, or a differential pressure) to move the piston 160 downward, thereby producing opposite rotation through the meshed helical teeth interfaces. Additionally or alternatively, pressurized fluid may be selectively supplied to a region of the annular recess 142 above the piston 160 (e.g., an upper chamber defined at least in part by the piston 160, the inner wall 146, and the sleeve 150) to apply a downward hydraulic force on the piston 160. In such embodiments, downward axial translation of the piston 160 causes corresponding opposite rotation of the piston 160, sleeve 150, and inner mandrel 110 due to the helical tooth engagements, thereby enabling bi-directional angular adjustment of the inner mandrel 110 during operations. Accordingly, in some embodiments the piston 160 is configured to actuate in a first axial direction to rotate the inner mandrel 110 in a first rotational direction about the axis 115, and the piston 160 is configured to actuate in a second axial direction, opposite the first axial direction, to rotate the inner mandrel 110 in a second rotational direction about the axis 115, opposite the first rotational direction.

[0043] In some embodiments, angular adjustment assembly 140 is configured to provide more than about 60° of available orientation adjustment about the axis 115. In some embodiments, one or more components of the angular adjustment assembly 140 (such as the piston 160 and/or the sleeve 150) may comprise an aluminum-copper alloy or other low-friction material or coating to reduce friction and facilitate operation.

[0044] Referring again to FIG. 2, the orientation tool 100 includes a control module 170 coupled to the inner mandrel 110, such as at or near the upper end 110a. The control module 170 may enable closed-loop over the orientation tool 100 that may be particularly beneficial in deeperwater operations where riser stretch and related delays can affect response time and orientation accuracy.

[0045] The control module 170 may include a housing or other structural element configured to support, protect, and/or contain components used to control operation of the orientation tool 100 during deployment in a subsea environment. In some embodiments, the control module 170 includes a control assembly 172, one or more sensors 179, and a valve assembly 180.

[0046] In some embodiments, the control module 170 is additionally or alternatively coupled to one or more components of the landing assembly 50 (FIG.1) that are positioned uphole of the orientation tool 100, such as a landing string 52 or other tubular string segment. In such embodiments, the control module 170 may include, or may be coupled to, suitable structural elements (e.g., threaded connections, hubs, flanges, collet-type connectors, or other load-bearing interfaces) configured to facilitate mechanical connection to the uphole component while maintaining fluid and electrical continuity as appropriate. Accordingly, the control module 170 may be positioned and supported along the landing assembly 50 to enable communication, power delivery, and/or hydraulic supply interfaces with uphole systems while remaining operable to control the orientation tool 100.

[0047] In some embodiments, the control module 170 is mechanically coupled to the inner mandrel 110 such that rotation of the inner mandrel 110 about the axis 115 corresponds to rotation of the control module 170 about the axis 115. Accordingly, as will be described in more detail herein, measurements taken by one or more sensors 179 supported by the control module 170 may be used to determine an angular orientation of the inner mandrel 110, and thereby an angular orientation of a tubing hanger 80 (FIG. 1), which may be coupled to the inner mandrel 110 as previously described.

[0048] The control assembly 172 may comprise one or more controllers, control modules, or other computing devices that are positioned in, supported by, and/or communicatively coupled to the control module 170. In some embodiments, the control assembly 172 includes a processor 174 and a memory 176.

[0049] The processor 174 may comprise any suitable processing device, such as a microcontroller, a central processing unit (CPU), a graphics processing unit (GPU), a timing controller (TCON), a scaler unit, or combinations thereof. The memory 176 may store computerreadable instructions 178 that are executable by the processor 174 to perform operations described herein. In general, the processor 174 may fetch, decode, and execute the computer-readable instructions 178 and may also perform associated operations such as receiving sensor outputs, making determinations regarding angular orientation, generating control signals, and communicating control signals to other components. When the processor 174 assists another component in performing an operation, the processor 174 may be described as causing that component to perform the operation.

[0050] The memory 176 may comprise volatile storage (e.g., random access memory (RAM)), non-volatile storage (e.g., flash storage, read-only memory (ROM), or other non-volatile media), or combinations thereof. Data read or written by the processor 174 while executing the computerreadable instructions 178 may be stored on the memory 176. In some embodiments, the memory 176 comprises a non-transitory computer-readable medium, where the term “non-transitory” does not encompass transitory propagating signals.

[0051] As used herein, “a processor,” “at least one processor,” or “one or more processors” may refer to a single processor configured to perform one or multiple operations, or multiple processors configured to collectively perform one or more operations. Similarly, “a memory,” “at least one memory,” or “one or more memories” may refer to a single memory configured to store data and/or instructions, or multiple memories configured to collectively store data and/or instructions.

[0052] In some embodiments, the control assembly 172 is a dedicated controller for controlling certain aspects or functions of the orientation tool 100. Additionally or alternatively, the control assembly 172 may be included as part of a general or master controller for a landing assembly (e.g., landing assembly 50 of FIG.1). In some embodiments, the control assembly 172 may be embodied as a single unit or device. Additionally or alternatively, the control assembly 172 may be embodied as a plurality of devices that are communicatively coupled to one another and optionally remotely spaced from one another. In some embodiments, the control module 170, or one or more components thereof (e.g., the control assembly 172), is remotely located from the orientation tool 100, such as in another component or portion of the landing assembly 50 and/or at or proximate to the sea surface (e.g., on a topside rig or vessel), while remaining communicatively coupled to the valve assembly 180 and the one or more sensors 179.

[0053] The one or more sensors 179 may be communicatively coupled to the control assembly 172. The sensor(s) 179 may comprise any suitable sensors or sensor arrays configured to measure, detect, or provide data indicative of an orientation, such as an angular orientation about the axis 115, or one or more variables that are at least partially indicative of the angular orientation. In some embodiments, the sensors 179 include a gyrocompass that is configured to determine angular orientation relative to true North. Additionally or alternatively, the sensors 179 may include magnetic sensors (including Hall-effect sensors), radio frequency identification (RFID) devices, optical sensors, flow sensors, accelerometers, digital encoders, linear variable differential transformer (LVDT), and/or combinations thereof. In some embodiments, the one or more sensors 179 (and potentially other components of the control module 170) may be packaged in one or more atmospheric-pressure canisters.

[0054] In some embodiments, the control assembly 172 is configured to determine an angular orientation of at least a portion of the orientation tool 100 about the axis 115 within a BOP bore by processing output from the sensor(s) 179. Because the control module 170 is coupled to the inner mandrel 110, the control assembly 172 may determine the angular orientation of the inner mandrel 110 about the axis 115 based at least in part on the sensor output. In embodiments in which the inner mandrel 110 is coupled, directly or indirectly, to a tubing hanger (such as the tubing hanger 80 in FIG. 1), the determined angular orientation of the inner mandrel 110 may correspond to the angular orientation of the tubing hanger.

[0055] Thus, the control assembly 172 may provide live heading data and, in some embodiments, acceleration and velocity data via the sensor(s) 179 during installation of the tubing hanger 80 to facilitate monitoring of landing stages and orientation status. In some embodiments, a calibration process may be performed during assembly to align the one or more sensors 179 (which may comprise gyroscope(s) and accelerometer(s) as previously described) to a critical orientation control feature on a tubing hanger running tool 70 or other orientation reference feature, thereby enabling the measured heading to be correlated to a desired installed tubing hanger heading.

[0056] In some embodiments, the orientation tool 100 includes one or more visual indicators configured to indicate a rotational position of the inner mandrel 110 (and thus a tubing hanger coupled thereto) relative to the outer housing 120. For example, the visual indicators may comprise graduations, marks, or other indicia on an outer surface of the inner mandrel 110 and on the outer housing 120 that indicate (e.g., in degrees) a rotational position of the inner mandrel 110 relative to a datum on the outer housing 120. In some embodiments, such visual indicators may be used during assembly or pre-deployment to set or confirm an initial rotational position of the inner mandrel 110 relative to the outer housing 120. Additionally or alternatively, the visual indicators may be used to verify a rotational position of the inner mandrel 110 within the BOP 16, such as by evaluating output from a camera, an optical sensor, or other observation device.

[0057] The valve assembly 180 may include one or more valves, and each such valve may be fluidly coupled to a pressurized fluid source 182. In some embodiments, the valve assembly 180 may be at least partially located on or in the orientation tool 100 (such as part of the control module 170). In some embodiments, the valve assembly 180 is at least partially located outside of the orientation tool 100, and in some embodiments one or more valves of the valve assembly 180 are remotely located (e.g., in another portion of the landing assembly 50 or at a topside location) while remaining fluidly coupled to the pressurized fluid source 182 and to the hydraulic loads of the orientation tool 100.

[0058] The pressurized fluid source 182 may comprise a source of pressurized hydraulic fluid, although other pressurized fluids are contemplated. In some embodiments, the pressurized fluid source 182 is at least partially positioned in the control module 170. Additionally or alternatively, the pressurized fluid source 182 may at least partially comprise a pipe, hose, conduit, or other line that communicates pressurized fluid to the control module 170 and the valve assembly 180. In some embodiments, the pressurized fluid comprises hydraulic oil, although other suitable pressurized fluids may additionally or alternatively be used, including water-based hydraulic fluids, synthetic hydraulic fluids, glycol-based fluids, compressed gas (e.g., nitrogen or air), or combinations thereof.

[0059] The control assembly 172 is communicatively coupled to the valve assembly 180 such that the control assembly 172 may selectively actuate the one or more valves to communicate pressurized fluid from the pressurized fluid source 182 to one or more hydraulic loads of the orientation tool 100. For example, the control assembly 172 may actuate the valve assembly 180 to communicate pressurized fluid to the gripping assemblies 130 to radially expand the grippers 132 into engagement with the bore 20 and thereby lock the outer housing 120 to the bore 20 to establish a rotational reaction point as previously described. The control assembly 172 may additionally actuate the valve assembly 180 to communicate pressurized fluid to the annular chamber 148 of the angular adjustment assembly 140 to axially actuate the piston 160 and thereby rotate the inner mandrel 110 relative to the outer housing 120 about the axis 115, as previously described.

[0060] In some embodiments, pressurized fluid is communicated from the valve assembly 180 to one or more hydraulic loads of the orientation tool 100 through one or more tubes, ports, passages, manifolds, conduits, hoses, fittings, and/or other fluid communication structures or devices. For example, the valve assembly 180 may be fluidly coupled to the pockets 124 of the gripping assemblies 130 to selectively supply pressurized fluid for radially expanding the grippers 132, and the valve assembly 180 may additionally or alternatively be fluidly coupled to the annular chamber 148 to selectively supply pressurized fluid for axially actuating the piston 160. In the illustrated embodiments of FIGS. 2–5, such fluid communication structures are not shown, in order to simplify the drawings and to improve clarity.

[0061] In some embodiments, the orientation tool 100 defines one or more ports, passages, tubes, manifolds, and/or other internal or external flow paths that are configured to route pressurized fluid through the orientation tool 100. For example, one or more flow paths may be configured to communicate pressurized fluid from an uphole source, through the orientation tool 100, and downhole to one or more components of the landing assembly 50, such as the tubing hanger running tool 70 and/or other hydraulically actuated tools or functions associated with installing and securing the tubing hanger 80. In some embodiments, the orientation tool 100 provides one or more dedicated hydraulic circuits that pass through the inner mandrel 110 and/or along an annular region between the inner mandrel 110 and the outer housing 120, optionally with seals, connectors, and/or isolation features configured to maintain separation between circuits while allowing rotation of the inner mandrel 110 relative to the outer housing 120. In the illustrated embodiments of FIGS.2–5, such ports and flow paths are not shown in order to simplify the drawings and to improve clarity.

[0062] In some embodiments, the control assembly 172 is configured to control the degree of rotation of the inner mandrel 110 based on one or more feedback signals derived from the sensors 179. For example, the control assembly 172 may monitor output from a gyrocompass and actuate the valve assembly 180 to drive the piston 160 until the determined angular orientation satisfies a desired orientation specification, after which the control assembly 172 may stop or modify actuation.

[0063] In some embodiments, the control assembly 172 additionally or alternatively tracks or monitors an amount of rotation of the inner mandrel 110 based on a delivered volume of pressurized fluid supplied to (or vented from) the annular chamber 148. Without limitation, because the sizes of the annular recess 142, piston 160, sleeve 150, and associated volumes may be known, the control assembly 172 may correlate a volume of fluid delivered to the annular chamber 148 to an axial distance of travel of the piston 160. Further, because geometric parameters of the helical interfaces (e.g., pitch and profile of helical teeth 144, 158, 166, 168) may be known, the control assembly 172 may correlate the axial travel of the piston 160 to a degree of rotation of the sleeve 150 and the inner mandrel 110. In such embodiments, the sensors 179 may include one or more flow sensors (e.g., volumetric flow sensors and/or mass flow sensors) that are configured to provide flow rate and/or delivered volume information for use by the control assembly 172.

[0064] Other techniques for tracking angular rotation are also contemplated. For example, one or more RFID tags, optical targets, and/or magnetic features may be coupled to the inner mandrel 110, and corresponding readers or sensors may be included as part of the sensors 179, such that the control assembly 172 determines an angular position and/or a change in angular position from the resulting sensor output. In some embodiments, the control assembly 172 monitors the sensor output while pressurized fluid is being supplied to the annular chamber 148 and, when the sensor output indicates that the angular orientation of the inner mandrel 110 is within a desired range, the control assembly 172 actuates the valve assembly 180 to stop or reduce the flow of pressurized fluid to the annular chamber 148. In this manner, the control module 170 cooperates with the gripping assemblies 130 and the angular adjustment assembly 140 to provide controlled, and in some embodiments closed-loop, adjustment of tubing hanger angular orientation during installation.

[0065] FIG. 5 illustrates an example configuration of the orientation tool 100 during a stage of a tubing hanger installation in which the tubing hanger 80 (FIG.1) is (or has been) fully seated on the landing shoulder 17 of the wellhead 14. Referring briefly again to FIG.1, when the tubing hanger 80 is initially inserted into the wellhead 14, the tubing hanger 80 may be supported in an initial landed condition in which a landing shoulder 82 of the tubing hanger 80 is proximate to, and in some embodiments partially engages, the landing shoulder 17 of the wellhead 14. However, in this initial stage, an axial gap may remain between the shoulders 17, 82 to permit further controlled downward movement of the tubing hanger 80 into a final seated condition. In such embodiments, the landing assembly 50, including the tubing hanger running tool 70 and associated tubular components, maintains the tubing hanger 80 in the initial landed condition while the orientation tool 100 is used to adjust and/or confirm angular orientation within the bore 20 of the BOP 16 as previously described (FIGS. 2–4). Once the desired angular orientation of the tubing hanger is achieved, the landing assembly 50 may facilitate a controlled lowering of the tubing hanger 80 (such as by releasing hydraulic pressure) to fully seat or engage the shoulders 17, 82.

[0066] After the desired angular orientation is achieved in the initial landed condition via the orientation tool 100 as previously described, that the orientation tool 100 may accommodate subsequent downward movement of the tubing hanger 80 into full engagement with the landing shoulder 17 of the wellhead 14 (FIG. 1) while maintaining rotational coupling. In particular, as shown in FIG. 5, the sleeve 150 remains rotationally coupled to the inner mandrel 110 via the keyed connection defined by the splines 156 and slots 114. As previously described, the axial length of the slots 114 is greater than an axial length of the splines 156 such that the inner mandrel 110 is able to translate axially relative to the sleeve 150 within a limited range. Accordingly, when the tubing hanger 80 is subsequently lowered from the initial landed condition into full engagement with the landing shoulder 17, the inner mandrel 110 may move axially (e.g., downward) relative to the sleeve 150 while the sleeve 150 remains rotational coupled to the inner mandrel 110, thereby preserving the achieved angular orientation during the final seating of the tubing hanger 80 in the wellhead 14.

[0067] In some embodiments, axial travel during this final lowering is limited by interaction between the ends 156a, 156b of the splines 156 and the shoulders 114a, 114b of the slots 114. For example, axially downward movement of the inner mandrel 110 relative to the sleeve 150 may be limited by engagement between the lower shoulders 114b and the lower ends 156b, and axially upward relative movement may be limited by engagement between the upper shoulders 114a and the upper ends 156a. In this manner, the keyed connection provides a controlled axial compliance that facilitates final seating of the tubing hanger 80 while maintaining rotational coupling between the sleeve 150 and the inner mandrel 110. In some embodiments, the control assembly 172 is configured to monitor an axial position and/or an axial travel of the inner mandrel 110 relative to the outer housing 120 based on one or more outputs from the one or more sensors 179.

[0068] In some embodiments, the control module 170, or one or more components thereof, may be configured to facilitate controlled lowering of the tubing hanger 80 within the wellhead 14 after a desired angular orientation has been achieved. For example, the control module 170 may be configured to actuate a valve, sleeve, or other valving element (whether implemented as part of the valve assembly 180 or as a separate valving device) to selectively bleed, vent, or otherwise reduce hydraulic pressure in a downhole portion of the landing assembly 50, such as within the tubing hanger running tool 70 or an associated landing mechanism, thereby allowing the tubing hanger 80 to move downward into full engagement with the landing shoulder 17 as previously described. In some embodiments, the control module 170 initiates or controls this lowering operation at least in part, and in some embodiments the control module 170 coordinates with, or provides commands to, another controller or control module (e.g., a landing string control system) such that the lowering operation is performed in combination with other control equipment.

[0069] Additionally or alternatively, the control assembly 172 of the control module 170 (FIG.

5) may be utilized to monitor angular orientation of the inner mandrel 110, and thus the tubing hanger 80, during the final lowering into full engagement with the landing shoulder 17. For example, the control assembly 172 may receive output from one or more sensors 179 coupled to the inner mandrel 110 and determine whether the angular orientation remains within a desired range as the tubing hanger 80 transitions from the initial landed condition to the fully seated condition. If a deviation is detected, the control assembly 172 may be configured to initiate, inhibit, or modify actuation of the valve assembly 180 and/or to provide an indication to an operator or to other control equipment, thereby supporting controlled installation of the tubing hanger 80 in the desired angular orientation within the wellhead system 10. The foregoing arrangement may reduce the likelihood that the tubing hanger 80 changes angular orientation during final seating, and may improve alignment outcomes for subsequently installed components relative to the wellhead system 10, including the BOP 16, the wellhead 14, and associated external structures.

[0070] In some embodiments, the available axial travel between the inner mandrel 110 and the sleeve 150, as provided by the relative lengths of the splines 156 and the slots 114, is selected based on an expected axial travel of the tubing hanger 80 within the wellhead 14 during final set down. Accordingly, in some embodiments the axial travel permitted by the splined connection is sufficient to accommodate the final set down stroke such that, during normal operations, contact between the spline ends 156a, 156b and the slot shoulders 114a, 114b is generally avoided.

[0071] In some embodiments, and with reference to FIGS.2–5, the orientation tool 100 further includes a locking pin 192 that is selectively actuatable in a port 194 defined in the outer housing 120 to engage an annular groove 190 formed in the radially outer surface 113 of the inner mandrel 110. The annular groove 190 extends circumferentially about the axis 115 so that, when the locking pin 192 is received in the groove 190, the inner mandrel 110 remains free to rotate relative to the outer housing 120 while the locking pin 192 slides circumferentially within the groove 190 during such rotation. The locking pin 192 may be actuated by any suitable method or system, including by pressurized fluid delivered from the valve assembly 180 under control of the control module 170, by pressurized fluid from another source (e.g., a remotely operated vehicle), by threaded actuation, by an electric motor or other electromechanical actuator, or by combinations thereof. During operations such as those illustrated in FIGS. 2–4, the locking pin 192 may be driven radially inward into the annular groove 190 to inhibit or prevent axial translation of the inner mandrel 110 relative to the outer housing 120 while still allowing rotation of the inner mandrel 110 within the outer housing 120 via the angular adjustment assembly 140 as previously described. However, in a stage such as that illustrated in FIG.5, when the inner mandrel 110 is permitted to translate axially to facilitate final lowering and landing of the tubing hanger 80 in the wellhead 14 (FIG. 1), the locking pin 192 may be withdrawn radially outward from the annular groove 190, again by any suitable actuation method, device, or system, thereby allowing the axial translation of the inner mandrel 110 relative to the outer housing 120.

[0072] FIG. 6 is a flowchart illustrating an example method 200 for landing a tubing hanger in a wellhead and adjusting an angular orientation of the tubing hanger during installation. For purposes of explanation, blocks of method 200 are described with reference to example components and configurations shown in FIGS. 1–5. These references are provided to describe some embodiments. In other embodiments, method 200 may be performed using systems, tools, and assemblies that differ from those shown in FIGS. 1–5 in one or more respects, including differing structural arrangements, differing actuation sources, and/or differing sensing and control implementations, while still performing the functions described in connection with method 200.

[0073] At block 202, method 200 includes lowering a landing assembly through a blowout preventer (BOP) to position a tubing hanger in a wellhead. In some embodiments, and with reference to FIG.1, the landing assembly 50 includes a tubing hanger 80, a tubing hanger running tool 70 coupled to the tubing hanger 80, and an orientation tool 100 positioned uphole of the tubing hanger running tool 70, optionally with one or more connection subs 60 between components. The landing assembly 50 may be conveyed from the sea surface through a riser 18 and into a bore 20 of the BOP 16 coupled to the wellhead 14. As the landing assembly 50 is lowered, production tubing 84 supported by the tubing hanger 80 may be introduced into the wellbore 12 while the tubing hanger 80 approaches a landing shoulder 17 of the wellhead 14. In some embodiments, the tubing hanger 80 is positioned in an initial landed condition in which a landing shoulder 82 of the tubing hanger 80 is proximate to, and in some embodiments at least partially engages, the landing shoulder 17 while still permitting controlled angular adjustment and subsequent controlled lowering into full seating, as described with reference to FIG.5.

[0074] At block 204, method 200 includes positioning an orientation tool of the landing assembly in a bore of the BOP during the lowering of the landing assembly. In some embodiments, and with reference to FIGS. 1–2, the orientation tool 100 is positioned along the landing assembly 50 such that it enters and is disposed within the bore 20 of the BOP 16 while the tubing hanger 80 is being positioned in the wellhead 14. The orientation tool 100 may include an outer housing 120 and an inner mandrel 110 positioned within the outer housing 120 along a central axis 115, and the inner mandrel 110 may be coupled, directly or indirectly, to the tubing hanger 80 such that rotation of the inner mandrel 110 corresponds to rotation of the tubing hanger 80.

[0075] At block 206, method 200 includes locking an outer housing of the orientation tool to the bore of the BOP, wherein the orientation tool includes an inner mandrel positioned in the outer housing. In some embodiments, and with reference to FIGS.2–3, the outer housing 120 includes a plurality of gripping assemblies 130 circumferentially spaced about the axis 115. Each gripping assembly 130 may include a gripper 132 coupled to a piston 134 and positioned in a pocket 124 of the outer housing 120. The locking at block 206 may include expanding the plurality of gripping assemblies 130 out of the outer housing 120 to engage the bore 20, such as by communicating pressurized fluid to the pockets 124 to drive the pistons 134 radially outward and extend the grippers 132 into frictional engagement with the bore 20, as shown in FIG.3. In some embodiments, the locking at block 206 fixes both an angular position and an axial position of the outer housing 120 relative to the bore 20 during a subsequent rotation operation, thereby establishing a rotational reaction point for rotating the inner mandrel 110 relative to the outer housing 120. In some embodiments, the positioning at block 204 includes positioning the orientation tool 100 within the bore 20 such that, when the gripping assemblies 130 are actuated, the gripping assemblies 130 engage a portion of the bore 20 that is axially spaced from the rams 22 or the associated cavities. Accordingly, in some embodiments the orientation tool 100 is positioned so that engagement of the bore 20 by the gripping assemblies 130 does not interfere with, and does not occlude, operation of the rams 22 during installation operations.

[0076] At block 208, method 200 includes actuating a piston of the orientation tool to rotate the inner mandrel relative to the outer housing. In some embodiments, and with reference to FIGS.

2 and 4, the orientation tool 100 includes an angular adjustment assembly 140 disposed between the outer housing 120 and the inner mandrel 110. The angular adjustment assembly 140 includes a piston 160 positioned radially between the outer housing 120 and the inner mandrel 110, and in some embodiments the piston 160 is at least partially positioned in a recess 142 of the outer housing 120 that extends radially outward from an inner bore 122 of the outer housing 120. In some embodiments, actuating the piston 160 includes pressurizing a chamber 148 that is at least partially defined by the piston 160. For example, the piston 160 may include seals 169 that, together with an inner wall 146 of the recess 142 and a sleeve 150 disposed about the inner mandrel 110, define an annular chamber 148 in the recess 142. The piston 160 may be axially actuated by supplying pressurized fluid to the annular chamber 148 via a valve assembly 180 (FIG.2), thereby axially translating the piston 160 relative to the outer housing 120.

[0077] In some embodiments, block 208 further includes converting axial translation of the piston 160 into rotation through meshed helical interfaces. For example, and with reference to FIG. 2, the piston 160 may include a plurality of first helical teeth 166 and a plurality of second helical teeth 168. The first helical teeth 166 and the second helical teeth 168 may extend in opposite helical directions about the axis 115. The first helical teeth 166 may be meshed with helical teeth 158 on the sleeve 150, and the second helical teeth 168 may be meshed with helical teeth 144 defined in the outer housing 120 (e.g., on the inner wall 146 of the recess 142). With the outer housing 120 locked to the bore 20 at block 206, the meshed engagement between the piston 160 and the outer housing 120 causes the piston 160 to rotate about the axis 115 as the piston 160 translates axially. The meshed engagement between the piston 160 and the sleeve 150 transmits the rotation to the sleeve 150, and the sleeve 150 in turn transmits torque to the inner mandrel 110 to rotate the inner mandrel 110 relative to the outer housing 120.

[0078] In some embodiments, block 208 further includes maintaining rotational coupling between the sleeve 150 and the inner mandrel 110 by use of a keyed connection. For example, the sleeve 150 may be coupled to an outer surface 113 of the inner mandrel 110 with a keyed connection including splines 156 and corresponding slots 114. The keyed connection may be configured to transmit torque while permitting axial translation between the sleeve 150 and the inner mandrel 110 within a limited range, thereby facilitating subsequent landing operations while preserving the achieved angular orientation.

[0079] At block 210, method 200 includes rotating the tubing hanger as a result of actuating the piston. In some embodiments, and with reference to FIGS. 1–2 and 4, the inner mandrel 110 is coupled to the tubing hanger 80 such that rotation of the inner mandrel 110 produced at block 208 results in corresponding rotation of the tubing hanger 80 about the longitudinal axis of the wellhead system. In this manner, the tubing hanger 80 may be rotated to a desired angular orientation relative to the wellhead 14, the BOP 16, and/or associated external structures, thereby facilitating alignment of subsequently installed equipment such as a valve tree and associated interface connectors and tie-in connections.

[0080] In some embodiments, method 200 further includes axially translating the inner mandrel relative to the sleeve. For example, after rotating the tubing hanger 80 to a desired angular orientation, the tubing hanger 80 may be lowered from the initial landed condition into full engagement with the landing shoulder 17 of the wellhead 14. During such lowering, the keyed connection between the sleeve 150 and the inner mandrel 110 allows axial translation of the inner mandrel 110 relative to the sleeve 150 while maintaining rotational coupling, thereby tending to preserve the achieved angular orientation during final seating, as described with reference to FIG.

[0081] In some embodiments, method 200 further includes determining an angular orientation of the tubing hanger by use of one or more sensors that are coupled to the inner mandrel, and actuating the piston based on the determined angular orientation. For example, and with reference to FIG.2, the orientation tool 100 may include a control module 170 coupled to the inner mandrel 110, and the control module 170 may include one or more sensors 179 configured to provide an output indicative of angular orientation about the axis 115. In some embodiments, determining the angular orientation includes receiving an output from a gyrocompass with a control assembly 172 and determining the angular orientation by use of the control assembly 172 based on the output. In some embodiments, actuating the piston based on the determined angular orientation includes performing closed-loop adjustment by monitoring sensor output while supplying pressurized fluid to the annular chamber 148 and modifying, stopping, or reversing actuation when the angular orientation is within a desired range.

[0082] In some embodiments, method 200 further includes controlling angular adjustment based on delivered fluid volume and/or measured flow rate. For example, the control assembly 172 may correlate delivered fluid volume to piston axial travel based on known volume geometry of the annular chamber 148 and may correlate piston axial travel to angular rotation based on known helical geometry of the helical teeth 144, 158, 166, 168. In such embodiments, one or more flow sensors may provide flow rate and/or delivered volume information used to estimate rotation and/or to supplement sensor-based orientation determination. Thus, in some embodiments, method 200 includes determining a degree of rotation of the inner mandrel (or tubing hanger) by determining a volume of pressurized fluid directed to the chamber 148 and determining the degree of rotation based on the determined volume.

[0083] In some embodiments, method 200 further includes, at block 206, expanding a plurality of gripper assemblies out of the outer housing to engage the bore of the BOP. For example, the control assembly 172 may actuate a valve assembly 180 to communicate pressurized fluid to the gripping assemblies 130 to extend the grippers 132 into engagement with the bore 20 before, during, or after actuation of the piston 160 at block 208. In this manner, method 200 provides a controlled technique for adjusting tubing hanger orientation within the BOP bore during installation, including by using helical tooth interfaces to translate axial piston actuation into rotation, and including by using sensors and control logic to determine angular orientation and to actuate the piston based on the determined orientation.

[0084] In some embodiments, method 200 further includes securing the tubing hanger 80 in the wellhead 14 after achieving the desired angular orientation and seating the tubing hanger 80 on the landing shoulder 17 (FIG. 1). In such embodiments, method 200 may further include disconnecting the tubing hanger 80 from the landing assembly 50, such as by releasing or disconnecting the tubing hanger running tool 70 from the tubing hanger 80, and then retrieving the landing assembly 50 (including the orientation tool 100, the tubing hanger running tool 70, and any associated connection subs 60) to the sea surface via the riser 18 and the BOP 16.

[0085] As explained above and reiterated below, the present disclosure includes, without limitation, the following example Examples.

[0086] Example 1: A landing assembly comprising: a tubing hanger; and an orientation tool coupled to the tubing hanger and configured to adjust an angular orientation of the tubing hanger, where the orientation tool comprises: an angular adjustment assembly comprising a piston, where actuation of the piston is configured to rotate the tubing hanger; and a control module comprising one or more sensors and a valve assembly, where the control module is configured to: determine the angular orientation of the tubing hanger by use of the one or more sensors; and actuate the valve assembly to actuate the piston and rotate the tubing hanger based on the angular orientation.

[0087] Example 2: The apparatus of any of the Examples, where the orientation tool comprises an outer housing and an inner mandrel positioned within the outer housing, where the inner mandrel is coupled to the tubing hanger, and where the piston is positioned between the outer housing and the inner mandrel.

[0088] Example 3: The apparatus of any of the Examples, where the orientation tool comprises a sleeve coupled to an outer surface of the inner mandrel, where the piston comprises a plurality of first helical teeth and a plurality of second helical teeth, where the plurality of first helical teeth are meshed with a plurality of helical teeth on the sleeve, and where the plurality of second helical teeth are meshed with a plurality of helical teeth defined in the outer housing.

[0089] Example 4: The apparatus of any of the Examples, where the plurality of first helical teeth extend in a first helical direction about a central axis of the orientation tool, where the plurality of second helical teeth extend in a second helical direction about the central axis, and where the second helical direction is opposite the first helical direction.

[0090] Example 5: The apparatus of any of the Examples, where the piston is configured to actuate in a first axial direction to rotate the tubing hanger in a first rotational direction and is configured to actuate in a second axial direction to rotate the tubing hanger in a second rotational direction, where the second axial direction is opposite the first axial direction along the central axis, and where the second rotational direction is opposite the first rotational direction.

[0091] Example 6: The apparatus of any of the Examples, where the piston is a cylindrical member comprising a radially inner surface and a radially outer surface, where the radially outer surface is radially outward from the radially inner surface relative to the central axis, where the plurality of first helical teeth are defined on the radially inner surface, and where the plurality of second helical teeth are defined on the radially outer surface.

[0092] Example 7: The apparatus of any of the Examples, where the outer housing comprises an inner bore, where the inner mandrel is coaxially received in the inner bore along the central axis, where the outer housing comprises a recess extending radially outward from the inner bore, and where the piston is at least partially positioned in the recess.

[0093] Example 8: The apparatus of any of the Examples, where the plurality of helical teeth defined in the outer housing are defined on an inner wall of the recess.

[0094] Example 9: The apparatus of any of the Examples, where the piston comprises a plurality of seals engaged with the inner wall of the recess and the sleeve such that a chamber is defined in the recess by the piston, the inner wall, and the sleeve.

[0095] Example 10: The apparatus of any of the Examples, where the control module is configured to actuate the valve assembly to supply pressurized fluid to the chamber to actuate the piston and rotate the tubing hanger.

[0096] Example 11: The apparatus of any of the Examples, where the sleeve is coupled to the outer surface of the inner mandrel by a keyed connection.

[0097] Example 12: The apparatus of any of the Examples, where the keyed connection is configured to allow axial translation of the inner mandrel relative to the sleeve.

[0098] Example 13: The apparatus of any of the Examples, where the one or more sensors comprise a gyrocompass.

[0099] Example 14: The apparatus of any of the Examples, where the outer housing comprises a plurality of gripper assemblies, and where the control module is configured to radially expand the plurality of gripper assemblies from the outer housing.

[00100] Example 15: An orientation tool for adjusting an angular orientation of a component in a wellhead system, the orientation tool comprising: an outer housing; an inner mandrel received in the outer housing, where the inner mandrel is configured to be coupled to the component; an angular adjustment assembly coupled between the outer housing and the inner mandrel, where the angular adjustment assembly comprises a piston, and where actuation of the piston is configured to rotate the inner mandrel; and a control module coupled to the inner mandrel, where the control module comprises one or more sensors and a valve assembly, and where the control module is configured to: determine the angular orientation of the inner mandrel by use of the one or more sensors; and actuate the valve assembly to actuate the piston and rotate the inner mandrel based on the angular orientation.

[00101] Example 16: The apparatus of any of the Examples, where the angular adjustment assembly comprises a sleeve coupled to an outer surface of the inner mandrel, where the piston comprises a plurality of first helical teeth and a plurality of second helical teeth, where the plurality of first helical teeth are meshed with a plurality of helical teeth on the sleeve, and where the plurality of second helical teeth are meshed with a plurality of helical teeth defined in the outer housing.

[00102] Example 17: The apparatus of any of the Examples, where the plurality of first helical teeth extend in a first helical direction about a central axis of the orientation tool, where the plurality of second helical teeth extend in a second helical direction about the central axis, and where the second helical direction is opposite the first helical direction.

[00103] Example 18: The apparatus of any of the Examples, where the piston is configured to actuate in a first axial direction to rotate the inner mandrel in a first rotational direction and is configured to actuate in a second axial direction to rotate the inner mandrel in a second rotational direction, where the second axial direction is opposite the first axial direction along the central axis, and where the second rotational direction is opposite the first rotational direction about the central axis.

[00104] Example 19: The apparatus of any of the Examples, where the piston is a cylindrical member comprising a radially inner surface and a radially outer surface, where the radially outer surface is radially outward from the radially inner surface relative to the central axis, where the plurality of first helical teeth are defined on the radially inner surface, and where the plurality of second helical teeth are defined on the radially outer surface.

[00105] Example 20: The apparatus of any of the Examples, where the outer housing comprises an inner bore, where the inner mandrel is coaxially received in the inner bore along the central axis, where the outer housing comprises a recess extending radially outward from the inner bore, and where the piston is at least partially positioned in the recess.

[00106] Example 21: The apparatus of any of the Examples, where the plurality of helical teeth defined in the outer housing are defined on an inner wall of the recess.

[00107] Example 22: The apparatus of any of the Examples, where the piston comprises a plurality of seals engaged with the inner wall of the recess and the sleeve such that a chamber is defined in the recess by the piston, the inner wall, and the sleeve.

[00108] Example 23: The apparatus of any of the Examples, where the control module is configured to actuate the valve assembly to supply pressurized fluid to the chamber to actuate the piston and rotate the inner mandrel.

[00109] Example 24: The apparatus of any of the Examples, where the control module is configured to determine a degree of rotation of the inner mandrel based on a volume of pressurized fluid flowed to the chamber.

[00110] Example 25: The apparatus of any of the Examples, where the sleeve is coupled to the outer surface of the inner mandrel by a keyed connection.

[00111] Example 26: The apparatus of any of the Examples, where the keyed connection is configured to allow axial translation of the inner mandrel relative to the sleeve.

[00112] Example 27: The apparatus of any of the Examples, where the one or more sensors comprise a gyrocompass.

[00113] Example 28: The apparatus of any of the Examples, where the outer housing comprises a plurality of gripper assemblies, and where the control module is configured to radially expand the plurality of gripper assemblies from the outer housing.

[00114] Example 29: A method of landing a tubing hanger in a wellhead, the method comprising: (a) lowering a landing assembly through a blowout preventer (BOP) to position the tubing hanger in the wellhead; (b) positioning an orientation tool of the landing assembly in a bore of the BOP during (a); (c) locking an outer housing of the orientation tool to the bore of the BOP, where the orientation tool comprises an inner mandrel positioned in the outer housing; (d) actuating a piston of the orientation tool to rotate the inner mandrel relative to the outer housing; and (e) rotating the tubing hanger as a result of (d).

[00115] Example 30: The method of any of the Examples, where (d) further comprises meshing a plurality of first helical teeth on the piston with helical teeth defined in the outer housing.

[00116] Example 31: The method of any of the Examples, where (d) further comprises meshing a plurality of second helical teeth on the piston with helical teeth on a sleeve coupled to an outer surface of the inner mandrel, where the plurality of first helical teeth extend in an opposite helical direction to the plurality of second helical teeth about a central axis of the orientation tool.

[00117] Example 32: The method of any of the Examples, where (d) further comprises pressurizing a chamber at least partially defined by the piston.

[00118] Example 33: The method of any of the Examples, further comprising: (f) axially translating the inner mandrel relative to the sleeve.

[00119] Example 34: The method of any of the Examples, where (f) comprises axially translating the inner mandrel relative to the sleeve by use of a keyed connection between the sleeve and the inner mandrel.

[00120] Example 35: The method of any of the Examples, further comprising: (g) determining an angular orientation of the tubing hanger by use of one or more sensors coupled to the inner mandrel; and (h) actuating the piston based on (g).

[00121] Example 36: The method of any of the Examples, further comprising: (i) determining a volume of pressurized fluid directed to the chamber; and (j) determining a degree of rotation based on (i).

[00122] Example 37: The method of any of the Examples, where (g) comprises receiving an output from a gyrocompass with a control assembly, and determining the angular orientation by use of the control assembly based on the output.

[00123] Example 38: The method of any of the Examples, where (c) comprises expanding a plurality of gripper assemblies out of the outer housing to engage the bore of the BOP.

[00124] Example 39: A landing assembly comprising: a tubing hanger; and an orientation tool coupled to the tubing hanger and configured to adjust an angular orientation of the tubing hanger, where the orientation tool comprises: an outer housing; an inner mandrel coaxially positioned in the outer housing along a central axis, where the inner mandrel is coupled to the tubing hanger; and a piston positioned radially between the outer housing and the inner mandrel, where axial translation of the piston is configured to rotate the inner mandrel about the central axis.

[00125] Example 40: The apparatus of any of the Examples, where the orientation tool comprises a sleeve coupled to an outer surface of the inner mandrel, where the piston comprises a plurality of first helical teeth and a plurality of second helical teeth, where the plurality of first helical teeth are meshed with a plurality of helical teeth on the sleeve, and where the plurality of second helical teeth are meshed with a plurality of helical teeth defined in the outer housing.

[00126] Example 41: The apparatus of any of the Examples, where the plurality of first helical teeth extend in a first helical direction about the central axis, where the plurality of second helical teeth extend in a second helical direction about the central axis, and where the second helical direction is opposite the first helical direction.

[00127] Example 42: The apparatus of any of the Examples, where the piston is a cylindrical member comprising a radially inner surface and a radially outer surface, where the radially outer surface is radially outward from the radially inner surface relative to the central axis, where the plurality of first helical teeth are defined on the radially inner surface, and where the plurality of second helical teeth are defined on the radially outer surface.

[00128] Example 43: The apparatus of any of the Examples, where the outer housing comprises an inner bore, where the inner mandrel is coaxially received in the inner bore along the central axis, where the outer housing comprises a recess extending radially outward from the inner bore, and where the piston is at least partially positioned in the recess.

[00129] Example 44: The apparatus of any of the Examples, where the plurality of helical teeth defined in the outer housing are defined on an inner wall of the recess.

[00130] Example 45: The apparatus of any of the Examples, where the piston comprises a plurality of seals engaged with the inner wall of the recess and the sleeve such that a chamber is defined in the recess by the piston, the inner wall, and the sleeve.

[00131] Example 46: The apparatus of any of the Examples, where the sleeve is coupled to the outer surface of the inner mandrel by a keyed connection.

[00132] Example 47: The apparatus of any of the Examples, where the keyed connection is configured to allow axial translation of the inner mandrel relative to the sleeve.

[00133] Example 48: The apparatus of any of the Examples, where the outer housing comprises a plurality of gripper assemblies configured to be radially expanded from the outer housing.

[00134] Example 49: An orientation tool for adjusting an angular orientation of a component in a wellhead system, the orientation tool comprising: an outer housing; an inner mandrel coaxially received in the outer housing along a central axis, where the inner mandrel is configured to be coupled to the component; and an angular adjustment assembly coupled between the outer housing and the inner mandrel, where the angular adjustment assembly comprises a piston, and where axial actuation of the piston is configured to rotate the inner mandrel relative to the outer housing.

[00135] Example 50: The apparatus of any of the Examples, where the angular adjustment assembly comprises a sleeve coupled to an outer surface of the inner mandrel, where the piston comprises a plurality of first helical teeth and a plurality of second helical teeth, where the plurality of first helical teeth are meshed with a plurality of helical teeth on the sleeve, and where the plurality of second helical teeth are meshed with a plurality of helical teeth defined in the outer housing.

[00136] Example 51: The apparatus of any of the Examples, where the plurality of first helical teeth extend in a first helical direction about the central axis, where the plurality of second helical teeth extend in a second helical direction about the central axis, and where the second helical direction is opposite the first helical direction.

[00137] Example 52: The apparatus of any of the Examples, where the piston is a cylindrical member comprising a radially inner surface and a radially outer surface, where the radially outer surface is radially outward from the radially inner surface relative to the central axis, where the plurality of first helical teeth are defined on the radially inner surface, and where the plurality of second helical teeth are defined on the radially outer surface.

[00138] Example 53: The apparatus of any of the Examples, where the outer housing comprises an inner bore, where the inner mandrel is coaxially received in the inner bore along the central axis, where the outer housing comprises a recess extending radially outward from the inner bore, and where the piston is at least partially positioned in the recess.

[00139] Example 54: The apparatus of any of the Examples, where the plurality of helical teeth defined in the outer housing are defined on an inner wall of the recess.

[00140] Example 55: The apparatus of any of the Examples, where the piston comprises a plurality of seals engaged with the inner wall of the recess and the sleeve such that a chamber is defined in the recess by the piston, the inner wall, and the sleeve.

[00141] Example 56: The apparatus of any of the Examples, further comprising a valve assembly, where actuation of the valve assembly is configured to selectively flow pressurized fluid into the chamber to actuate the piston and rotate the inner mandrel.

[00142] Example 57: The apparatus of any of the Examples, where the sleeve is coupled to the outer surface of the inner mandrel by a keyed connection.

[00143] Example 58: The apparatus of any of the Examples, where the keyed connection is configured to allow axial translation of the inner mandrel relative to the sleeve.

[00144] Example 59: The apparatus of any of the Examples, where the outer housing comprises a plurality of gripper assemblies configured to be radially expanded from the outer housing. The disclosure comprises the subject matter described in the following clauses which may form the basis for claim amendments or future divisional applications:

Clause 1. A landing assembly comprising:

a tubing hanger; and

an orientation tool coupled to the tubing hanger and configured to adjust an angular orientation of the tubing hanger, where the orientation tool comprises:

an angular adjustment assembly comprising a piston, where actuation of the piston is configured to rotate the tubing hanger, and

a control module comprising one or more sensors and a valve assembly, where the control module is configured to:

determine the angular orientation of the tubing hanger by use of the one or more sensors; and

actuate the valve assembly to actuate the piston and rotate the tubing hanger based on the angular orientation.

Clause 2. The landing assembly of clause 1, where:

the orientation tool comprises an outer housing and an inner mandrel positioned within the outer housing,

the inner mandrel is coupled to the tubing hanger,

the piston is positioned between the outer housing and the inner mandrel,

the outer housing comprises a plurality of gripper assemblies, and

the control module is configured to radially expand the plurality of gripper assemblies from the outer housing.

Clause 3. The landing assembly of clause 2, where:

the orientation tool comprises a sleeve coupled to an outer surface of the inner mandrel, the piston comprises a plurality of first helical teeth and a plurality of second helical teeth, the plurality of first helical teeth are meshed with a plurality of helical teeth on the sleeve, and the plurality of second helical teeth are meshed with a plurality of helical teeth defined in the outer housing, and

the plurality of first helical teeth extend in a first helical direction about a central axis of the orientation tool, and the plurality of second helical teeth extend in a second helical direction about the central axis that is opposite the first helical direction.

Clause 4. The landing assembly of clause 3, where:

the piston is a cylindrical member comprising a radially inner surface and a radially outer surface, the radially outer surface being radially outward from the radially inner surface relative to the central axis,

the plurality of first helical teeth are defined on the radially inner surface and the plurality of second helical teeth are defined on the radially outer surface,

the inner mandrel is coaxially received in an inner bore of the outer housing along the central axis,

the outer housing comprises a recess extending radially outward from the inner bore and the piston is at least partially positioned in the recess such that a chamber is defined in the recess by at least the piston, the recess, and the sleeve,

the plurality of helical teeth defined in the outer housing are defined on an inner wall of the recess, and

the control module is configured to actuate the valve assembly to supply pressurized fluid to the chamber to actuate the piston and rotate the tubing hanger.

Clause 5. The landing assembly of clause 4, where the sleeve is coupled to the outer surface of the inner mandrel by a keyed connection that is configured to allow axial translation of the inner mandrel relative to the sleeve.

Clause 6. The landing assembly of clause 5, where the one or more sensors comprise a gyrocompass.

Clause 7. The landing assembly of clause 3, where:

the piston is configured to actuate in a first axial direction to rotate the tubing hanger in a first rotational direction and is configured to actuate in a second axial direction to rotate the tubing hanger in a second rotational direction,

the second axial direction is opposite the first axial direction along the central axis, and the second rotational direction is opposite the first rotational direction.

Clause 8. An orientation tool for adjusting an angular orientation of a component in a wellhead system, the orientation tool comprising:

an outer housing;

an inner mandrel received in the outer housing, where the inner mandrel is configured to be coupled to the component;

an angular adjustment assembly coupled between the outer housing and the inner mandrel, where the angular adjustment assembly comprises a piston, and where actuation of the piston is configured to rotate the inner mandrel; and

a control module coupled to the inner mandrel, where the control module comprises one or more sensors and a valve assembly, and where the control module is configured to:

determine the angular orientation of the inner mandrel by use of the one or more sensors; and

actuate the valve assembly to actuate the piston and rotate the inner mandrel based on the angular orientation.

Clause 9. The orientation tool of clause 8, where:

the angular adjustment assembly comprises a sleeve coupled to an outer surface of the inner mandrel,

the piston comprises a plurality of first helical teeth that are meshed with a plurality of helical teeth on the sleeve and a plurality of second helical teeth that are meshed with a plurality of helical teeth defined in the outer housing, and

the plurality of first helical teeth extend in a first helical direction about a central axis of the orientation tool and the plurality of second helical teeth extend in a second helical direction about the central axis that is opposite the first helical direction.

Clause 10. The orientation tool of clause 9, where:

the plurality of first helical teeth are defined on the radially inner surface and the plurality of second helical teeth are defined on the radially outer surface, the inner mandrel is coaxially received in an inner bore of the outer housing along the central axis,

the piston is at least partially positioned in a recess defined in the inner bore, and the plurality of helical teeth defined in the outer housing are defined on an inner wall of the recess.

Clause 11. The orientation tool of clause 10, where:

the piston comprises a plurality of seals engaged with the inner wall of the recess and the sleeve such that a chamber is defined in the recess by the piston, the inner wall, and the sleeve, and

the control module is configured to actuate the valve assembly to supply pressurized fluid to the chamber to actuate the piston and rotate the inner mandrel.

Clause 12. The orientation tool of clause 11, where the control module is configured to determine a degree of rotation of the inner mandrel based on a volume of pressurized fluid flowed to the chamber.

Clause 13. The orientation tool of clause 12, where the sleeve is coupled to the outer surface of the inner mandrel by a keyed connection that is configured to allow axial translation of the inner mandrel relative to the sleeve.

Clause 14. The orientation tool of clause 8, where the outer housing comprises a plurality of gripper assemblies, and the control module is configured to radially expand the plurality of gripper assemblies from the outer housing.

Clause 15. A method of landing a tubing hanger in a wellhead, the method comprising:

(a) lowering a landing assembly through a blowout preventer (BOP) to position the tubing hanger in the wellhead;

(b) positioning an orientation tool of the landing assembly in a bore of the BOP during (a);

(c) locking an outer housing of the orientation tool to the bore of the BOP, where the orientation tool comprises an inner mandrel positioned in the outer housing; (d) actuating a piston of the orientation tool to rotate the inner mandrel relative to the outer housing; and

(e) rotating the tubing hanger as a result of (d).

Clause 16. The method of clause 15, where (d) further comprises

meshing a plurality of first helical teeth on the piston with helical teeth defined in the outer housing, and

meshing a plurality of second helical teeth on the piston with helical teeth on a sleeve coupled to an outer surface of the inner mandrel,

where the plurality of first helical teeth extend in an opposite helical direction to the plurality of second helical teeth about a central axis of the orientation tool.

Clause 17. The method of clause 16, where (d) further comprises pressurizing a chamber at least partially defined by the piston, and further comprising:

(f) determining a volume of pressurized fluid directed to the chamber; and

(g) determining a degree of rotation of the inner mandrel based on (f).

Clause 18. The method of clause 16, further comprising:

(h) axially translating the inner mandrel relative to the sleeve via a keyed connection between the sleeve and the inner mandrel.

Clause 19. The method of clause 15, further comprising:

(i) determining an angular orientation of the tubing hanger using one or more sensors coupled to the inner mandrel; and

(j) actuating the piston based on (i).

Clause 20. The method of clause 15, where (c) comprises expanding a plurality of gripper assemblies out of the outer housing to engage the bore of the BOP.

[00145] Embodiments disclosed herein are directed to orientation tools that may be configured to adjust the angular orientation of a tubing hanger during installation of the tubing hanger into a subsea wellhead. In some embodiments, the orientation tool includes an outer housing that is selectively lockable to a bore of a BOP, an inner mandrel coupled to the tubing hanger, and an angular adjustment assembly disposed between the outer housing and the inner mandrel that is configured to rotate the inner mandrel relative to the outer housing about a central axis. In some embodiments, the orientation tool includes a control module that is configured to determine an angular orientation of the inner mandrel and to actuate the angular adjustment assembly to rotate the inner mandrel, thereby enabling closed-loop adjustment of tubing hanger orientation within the BOP and improving the likelihood of achieving alignment for valve tree tie-in connections and tubing hanger-to-tree interface connectors. In some embodiments, the disclosed approach may reduce or eliminate reliance on a pin-and-groove alignment system for orienting the tubing hanger, including reducing or eliminating the use of a BOP pin and a tubing hanger orientation joint (THOJ) with an external helix profile, which may reduce BOP modification requirements, may reduce landing string length penalties, and may reduce reliance on specialized calibration equipment or operations.

[00146] In some embodiments, the orientation tool 100 includes additional subsystems and interfaces, such as electrical connectors, a valve pack implementing at least a portion of the valve assembly 180, and one or more bumpers, bearings, center bodies, and/or inner sleeve structures that cooperate to support rotation, sealing, and load transfer in the subsea environment. In some embodiments, the landing assembly 50 incorporating the orientation tool 100 further includes an emergency disconnect package (EDP) sub or saver hub and a shear joint positioned uphole of the orientation tool 100, and the orientation tool 100 may include a secondary unlock or secondary unlatch (SUL) system that uses one or more hydraulic shuttle valves, a dedicated secondary reference line, an isolation shuttle, and a pressure-actuated element (e.g., a burst disk) such that, after a selected loss of pressure condition, increasing BOP annulus pressure below a pipe ram permits pressure communication to a tubing hanger running tool unlatch function to facilitate release.

[00147] It should be appreciated that, although the illustrated embodiments describe the angular adjustment assembly 140 as a helical actuation arrangement configured to convert axial translation of the piston 160 into rotation of the sleeve 150 and inner mandrel 110, other embodiments may utilize different actuation devices, systems, and/or control strategies to rotate the inner mandrel 110 relative to the outer housing 120. For example, in some embodiments one or more motors (e.g., electric motors or hydraulic motors) may be coupled to the inner mandrel 110 and/or to an intermediate drive member to generate rotation, such as through a gear train, belt drive, chain drive, worm gear, or other rotary transmission. Additionally or alternatively, rotation may be produced by other actuator types, including vane-style rotary actuators, rack-and-pinion mechanisms, radial piston/yoke arrangements, harmonic drives, stepper-driven gearboxes, magnetically coupled drives, and/or other electromechanical or fluid-powered actuation systems, whether used alone or in combination, without departing from the scope of the present disclosure.

[00148] The preceding discussion is directed to various embodiments. However, one of ordinary skill in the art will understand that the examples disclosed herein have broad application, and that the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.

[00149] The drawing figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in interest of clarity and conciseness.

[00150] In the preceding discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to .. ..” Also, the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection of the two devices, or through an indirect connection that is established via other devices, components, nodes, and connections. In addition, as used herein, the terms “axial” and “axially” generally mean along or parallel to a given axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the given axis. For instance, an axial distance refers to a distance measured along or parallel to the axis, and a radial distance means a distance measured perpendicular to the axis. Further, when used herein (including in the claims), the words “about,” “generally,” “substantially,” “approximately,” and the like, when used to refer to a stated value, mean within a range of plus or minus 10% of the stated value. As used herein, (including in the claims), the phrase “based on” means “based at least on.”

[00151] While exemplary embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary only and are not limiting. Many variations and modifications of the systems, apparatus, and processes described herein are possible and are within the scope of the disclosure. Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the operations in a method claim may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (1), (2), (3) before operations in a method claim are not intended to and do not specify a particular order to the operations, but rather are used to simplify subsequent reference to such operations.

Claims

CLAIMS

What is claimed is:

1. A landing assembly comprising:

a tubing hanger; and

an orientation tool coupled to the tubing hanger and configured to adjust an angular orientation of the tubing hanger, where the orientation tool comprises:

an angular adjustment assembly comprising a piston, where actuation of the piston is configured to rotate the tubing hanger, and

a control module comprising one or more sensors and a valve assembly, where the control module is configured to:

determine the angular orientation of the tubing hanger by use of the one or more sensors; and

actuate the valve assembly to actuate the piston and rotate the tubing hanger based on the angular orientation.

2. The landing assembly of claim 1, where:

the orientation tool comprises an outer housing and an inner mandrel positioned within the outer housing,

the inner mandrel is coupled to the tubing hanger,

the piston is positioned between the outer housing and the inner mandrel,

the outer housing comprises a plurality of gripper assemblies, and

the control module is configured to radially expand the plurality of gripper assemblies from the outer housing.

3. The landing assembly of claim 2, where:

4. The landing assembly of claim 3, where:

the plurality of first helical teeth are defined on the radially inner surface and the plurality of second helical teeth are defined on the radially outer surface,

the inner mandrel is coaxially received in an inner bore of the outer housing along the central axis,

the plurality of helical teeth defined in the outer housing are defined on an inner wall of the recess, and

the control module is configured to actuate the valve assembly to supply pressurized fluid to the chamber to actuate the piston and rotate the tubing hanger.

5. The landing assembly of claim 3 or 4, where the sleeve is coupled to the outer surface of the inner mandrel by a keyed connection that is configured to allow axial translation of the inner mandrel relative to the sleeve, and where the one or more sensors comprise a gyrocompass.

6. The landing assembly of claim 3 or 4, where:

the second axial direction is opposite the first axial direction along the central axis, and the second rotational direction is opposite the first rotational direction.

7. A method of landing a tubing hanger in a wellhead, the method comprising:

(a) lowering a landing assembly through a blowout preventer (BOP) to position the tubing hanger in the wellhead;

(b) positioning an orientation tool of the landing assembly in a bore of the BOP during (a);

(e) rotating the tubing hanger as a result of (d).

8. The method of claim 7,

where (d) further comprises

meshing a plurality of first helical teeth on the piston with helical teeth defined in the outer housing,

meshing a plurality of second helical teeth on the piston with helical teeth on a sleeve coupled to an outer surface of the inner mandrel, where the plurality of first helical teeth extend in an opposite helical direction to the plurality of second helical teeth about a central axis of the orientation tool; and

further comprising:

(f) pressurizing a chamber at least partially defined by the piston;

(f) determining a volume of pressurized fluid directed to the chamber; and (g) determining a degree of rotation of the inner mandrel based on (f).

9. The method of claim 7 or 8, where (c) comprises expanding a plurality of gripper assemblies out of the outer housing to engage the bore of the BOP, and further comprising:

(h) axially translating the inner mandrel relative to the sleeve via a keyed connection between the sleeve and the inner mandrel.

10. The method of claim 7 or 8, further comprising:

(i) determining an angular orientation of the tubing hanger using one or more sensors coupled to the inner mandrel; and

(j) actuating the piston based on (i).

Drawings

Priority

12.03.2025 US 63/770,567

13.03.2025 US 63/771,421

Patent classes

IPC classes

E21B 33/04

CPC classes

E21B 33/04

Citations

US 2018163500 A1 (A1)

US 4386656 A (A)

US 20240426187 A1 (A1)

Applicants, owners and inventors

Applicants

OneSubsea AS

Strandveien 4

1366 LYSAKER

NO (BÆRUM Municipality, Akershus county)

Org. number: 929765001

Inventors

Robert Karl Johansson

Maskinveien 13

4033 STAVANGER

NO (STAVANGER Municipality, Rogaland county)

Stuart Spitz

Unit 46 - Howe Moss Ave, Kirkhill Industrial Estate

AB210GP WORKINGHAM

Lee Hall

Unit 46 - Howe Moss Ave, Kirkhill Industrial Estate

AB210GP WORKINGHAM

Agent

HÅMSØ PATENTBYRÅ AS

Postboks 9

4068 STAVANGER

NO (STAVANGER Municipality, Rogaland county)

Org. number: 918752900

Reference: P32086NO00

Status history

Payment history

Oppositions and appeals

No oppositions or appeals

Administrative limitation

No administrative limitation

Liens and licences

No liens or licenses registered

Gazette entries

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Only events from 2024.03.04 and onwards are shown.