Vessel with rotatably mounted guider body for hanging off intervention equipment in various positions

Abstract

A vessel in various examples has a hull, a moonpool, a handling tower for handling well intervention equipment above moonpool, a mount arranged outside, or on an outside of, the handling tower, and a guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment, wherein the first end is connected to the mount and the second end extends away from the mount, the guider body being rotatable relative to the mount about a vertical axis, so as thereby to move the hang-off portion of the guider body relative to the handling tower, in use, between a parking position in which the well intervention equipment is hung off outside the handling tower and at least one operational position in which the well intervention equipment is hung off above the moonpool Also described are examples of apparatus and methods using the apparatus including the guider body or an articulated guider body for preparing for the deployment of coiled tubing from the vessel.

Description

[0001] VESSEL WITH ROTATABLY MOUNTED GUIDER BODY FOR HANGING OFF INTERVENTION EQUIPMENT IN VARIOUS POSITIONS

[0002] Technical field

[0003] The present invention relates to the provision and arrangement of well intervention equipment on vessels for deployments into the sea through a moonpool.

[0004] Background

[0005] In connection with subsea wells, intervention operations in the well may be performed through a subsea wellhead using tools deployed on coiled tubing or on wirelines from a surface vessel. The subsea wellhead is provided with a subsea well entry assembly including typically a well control package and a lubricator provided on the well control package for containing the well pressure whilst tools are deployed. In this arrangement, the coiled tubing or wireline is submerged in the sea between the vessel and the well entry assembly on the wellhead. This is sometimes referred to as riserless subsea operations. That is, the subsea coiled tubing or wireline is not deployed inside a riser between the wellhead and the surface. The tools may be used for well intervention or workover.

[0006] The vessel is provided with a handling tower extending upward from deck. The coiled tubing is deployed using topsides coiled tubing deployment equipment including a topsides coiled tubing injector arranged inside the handling tower and above the moonpool. The coiled tubing extends through the injector head with a gooseneck guiding the coiled tubing from the reel into the coiled tubing injector head. The injector head acts on the coiled tubing to urge the tubing through sea toward or away from the wellhead.

[0007] The injector head may be suspended from the tower on a main hoist line. The coiled tubing injector head may also be arranged to be guided by the tower, for example the tower may have longitudinal guide rails, so that movement of the suspended equipment along the tower due to heave motions of the vessel is permitted whilst being retained in lateral position relative to the tower. The hoist line can for instance spool in or out to permit movement of the coiled tubing equipment along the tower, and in such way compensate for the heave motions of the vessel. By way of the heave compensation functionality, the coiled tubing injector can be supported from the vessel in constant height (i.e. relative to seabed), despite the vessel heaving up or down with waves, etc.

[0008] When wireline rather than coiled tubing is required, wireline equipment is employed. The wireline may then be deployed through the moonpool into the sea, and a tool string on the end of the wireline may be lowered to the wellbore to perform work, for example, light intervention work. The wireline equipment typically comprises a wireline winch which is operable to spool and unspool the wireline from the winch drum. A heave compensated support member is arranged on the tower over which the wireline from the winch drum is passed. The wireline with the tool string attached to the end thereof is thus suspended over the moonpool from the heave compensated support for deployment into the sea. The wireline and tool string may thus also be heave compensated. The wireline winch drum could also be operated to spool in or out to compensate for heave.

[0009] For coiled tubing operation, space above the moonpool is required for the topsides coiled tubing equipment such as the injector head, gooseneck, etc. The heave compensated support for the wireline may be moved to one side to make space over the moonpool. Transitioning between the wireline set up and coiled tubing set up can be time consuming, complex, and costly. The process must generally also comply with industry safety protocols, which can pose further challenges. For example, the coiled tubing and / or wireline may require load testing before the tool(s) are connected to the end of the coiled tubing. The coiled tubing also needs to be arranged to extend through the topsides injector head. In certain applications, the coiled tubing is arranged through another, subsea injector device and / or is provided with a subsea stripper. These are connected to the coiled tubing topsides and deployed along with the coiled tubing into the sea for connection to the subsea entry assembly on the subsea wellhead. Furthermore, the changeover from coiled tubing to wireline or vice versa may involve changing or reconfiguring the well control package and / or lubricator to be used on the subsea wellhead in the new operation. Thus, the existing well control package and / or lubricator may require to be retrieved back to the surface vessel before redeploying the same or another one.

[0010] At least one aim of the invention is to obviate or at least mitigate one or more drawbacks of prior art.

[0011] Summary

[0012] According to a first aspect of the invention, there is provided a vessel comprising: a hull; a moonpool; a handling tower for handling well interventioin equipment above the moonpool; a mount arranged outside, or on an outside of, the handling tower; and a guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment; the first end connected to the mount and the second end extending away from the mount, the guider body being rotatable, for example pivotably rotatable, relative to the mount about a vertical axis, so as thereby to move the hang-off portion of the guider body relative to the handling tower, in use, between a parking position in which the well intervention equipment is hung off outside the handling tower and at least one operational position in which the well intervention equipment is hung off above the moonpool.

[0013] The hang-off portion may be arranged at or near the second end. The hang-off portion may be arranged between the first and second ends.

[0014] Through the rotating of the guider body, at least one hang-off portion may be movable at least partially through a side opening or port of the handling tower between the parking position and the at least one operational position.

[0015] In the parking position, the hang-off portion may be arranged outside the handling tower. In at least one operational position at least one hang-off portion may be arranged at least partially inside the handling tower.

[0016] The guider body may have a first hang-off portion for hanging off first well intervention equipment on one side of the guider body or section thereof and a second hang-off portion for hanging off second well intervention equipment on an opposite side of the guider body or the section thereof.

[0017] The guider body may be pivotable relative to the mount about a vertical axis.

[0018] The guider body may be a vertically arranged panel.

[0019] According to a second aspect of the invention, there is provided a vessel comprising: a hull; a moonpool; a handling tower for handling well intervention equipment above the moonpool; a mount arranged outside, or on an outside of, the handling tower; and an articulated guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment; the first end connected to the mount and the second end extending away from the mount, the articulated guider body being rotatable about a vertical axis, for example pivotably rotatable, relative to the mount and articulated sections of the guider body being individually rotatable relative to one another and the mount, one rotatable relative to the next about a vertical axis, for example pivotably rotatable, so as thereby to move the hang-off portion of the guider body relative to the handling tower between a parking position in which the well intervention equipment is hung off outside the handling tower and at least one operational position in which the well intervention equipment is hung off above the moonpool. The articulated sections may be pivotably rotatable each one relative to the next about a vertical axis. The articulated sections may be vertically arranged panels.

[0020] The articulated sections may include a first, proximal section and a second, distal section, and optionally at least one intermediate section. The at least one hang-off portion may be a portion of the distal section or an intermediate section.

[0021] The distal section may have a first hang-off portion for hanging off first well intervention equipment on one side of the distal section and a second hang-off portion for hanging off second well intervention equipment on an opposite side of the distal section.

[0022] In a first operational position, the first hang hang-off portion may be arranged for locating the first well intervention equipment either or both: inside the tower, e.g. at or near the centre of the tower; and / or over the moonpool, e.g. at or near the centre of the moonpool. In a second operational position, the second hang-off portion may be arranged for locating the second well intervention equipment either or both: inside the tower, e.g. at or near the centre of the tower; and / or over the moonpool e.g., at or near the centre of the moonpool. The distal section may be rotated relative to an adjacent intermediate or proximal portion to move between the first operational position and the second operational position.

[0023] In the parking position, the hang-off portion may be arranged outside the handling tower. In at least one operational position at least one hang-off portion is arranged at least partially inside the handling tower or at least partially above or over the moonpool.

[0024] Through so rotating the articulated guider body or sections thereof, at least one hang-off portion may be movable at least partially through an access side opening or port of the handling tower between the parking position and the at least one operational position.

[0025] In the parking position, the hang-off portion may be arranged away from and / or outside the width extent of the opening. The access opening may be an opening having a width transverse to a central longitudinal axis of the vessel, and in the parking position the hang-off portion may be arranged outside of the transverse extent of the opening and e.g. closer to the vessel side than to the central longitudinal axis. The access opening may be an opening having a width extending transverse to a longitudinal axis of the vessel, and in the parking position, the hang- off portion and / or second end of the guider body may be arranged away from the opening so as not to obstruct the opening and / or so as to allow access of other equipment through the opening into the interior of the tower. In the parking position, the guider body may extend from the mount away from an outside of the tower.

[0026] The hang-off portion may comprise one or more elements for coupling well intervention equipment to the guider body for hanging off well intervention equipment. The hang-off portion may comprise vertical guide rails and a part arranged to be mounted to the guide rails for permitting movement of the part up / down along the guide rails and retaining movement laterally. The part may be configured to have an injector head assembly connected thereto. The hang-off portion may comprise one or more elements for coupling passive heave compensator device on the guider.

[0027] The guider body may be disposed on the mount, extending toward the second end in suspended relationship above deck level.

[0028] The guider body may have a first hang-off portion for hanging off first well intervention equipment on one side of the guider body and a second hang-off portion for hanging off second well intervention equipment on the opposite side of the guider body.

[0029] The vessel may include the well intervention equipment, and the well intervention equipment may be coupled to the at least one hang-off portion. The well intervention equipment may be any of coiled tubing equipment; wireline equipment; well entry equipment.

[0030] The coiled tubing equipment may be coiled tubing deployment equipment configured to be disposed topsides during the deployment or operation of coiled tubing through the moonpool. The coiled tubing equipment may comprise any one or more of: a topsides coiled tubing injector head; a gooseneck; a length of coiled tubing; a tool string; an end connector on the coiled tubing for connecting the tool string to the coiled tubing; a subsea injector device; a subsea stripper; a passive heave compensator device; at least one connecting member for connecting the passive heave compensator to the topsides coiled tubing injector head; at least one connector for suspending the equipment from hoisting gear above the moonpool; either or both of a guide and a guide follower for guiding the coiled tubing injector head with respect to the tower column during subsea coiled tubing operations, permitting heave motions between the coiled tubing injector and the tower longitudinally along the tower, and restricting rotations or motions of the coiled tubing injector away relative to the tower column laterally. In the parking position, the coiled tubing equipment may be at least partially assembled for load testing a spooled-out length of coiled tubing from a coiled tubing reel, the spooled-out length of coiled tubing passed through the topsides coiled tubing injector head, and optionally the subsea coiled tubing injector, and optionally the subsea stripper, for load testing. In the parking position, the at least partially assembled coiled tubing equipment is preferably located outside the handling tower and near a side of the vessel for facilitating connection of external load testing means to the coiled tubing equipment for load testing, for example when the vessel is docked or moored alongside a dock or other facility. The load testing means may comprise at least one device arranged dockside or on another facility which applies a load to the end of the coiled tubing.

[0031] According to a third aspect of the invention, there is provided apparatus for mounting to a vessel, the vessel comprising a hull, a moonpool, a handling tower for handling well intervention equipment above the moonpool, and a mount configured to be arranged outside, or on an outside of, the handling tower on the vessel, the apparatus comprising: a guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment; the first end configured to be connected to the mount and the second end to extend away from the mount, the guider body configured to be rotatable relative to the mount about a vertical axis, e.g. pivotably rotatable, for moving, in use, the hang-off portion of the guider body relative to the handling tower between a parking position in which, in use, the well intervention equipment is hung off outside the handling tower and at least one operational position in which, in use, the well intervention is hung off above the moonpool.

[0032] According to a fourth aspect of the invention, there is provided apparatus for mounting to a vessel, the vessel comprising a hull, a moonpool, and a handling tower for handling well intervention equipment above the moonpool, and a mount configured to be arranged outside, or on an outside of, the handling tower on the vessel, the apparatus comprising: an articulated guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment; the first end configured to be connected to the mount and the second end extending away from the mount, the articulated guider body configured to be rotatable about a vertical axis, e.g. pivotably rotatable, relative to the mount and articulated sections of the guider body configured to be individually rotatable relative to one another and the mount, one rotatable relative to the next about a vertical axis, e.g. pivotably rotatable, for moving, in use, the hang-off portion of the guider body relative to the handling tower between a parking position in which, in use, the well intervention equipment is hung off outside the handling tower and at least one operational position in which, in use, the well intervention is hung off above the moonpool. According to fifth aspect of the invention, there is provide a method of preparing for deployment of coiled tubing from the vessel in accordance with the first aspect of the invention, the method comprising the steps of: hanging off coiled tubing well intervention equipment from the hang- off portion of the guider body. The method may further comprise rotating the guider body about a vertical axis relative to the mount between the parking position and the at least one operational position.

[0033] According to a sixth aspect of the invention, there is provide a method of preparing for deployment of coiled tubing from the vessel in accordance with the second aspect of the invention, the method comprising the steps of: hanging off coiled tubing well intervention equipment from the hang-off portion of the articulated guider body. The method may further comprise rotating either or both of: the articulated guider body about a vertical axis relative to the mount, e.g. pivotably rotating; and articulated sections of the guider body individually relative to one another and the mount, one section rotating relative to the next about a vertical axis, e.g. pivotably rotating; thereby moving the hang-off portion between the parking position and the at least one operational position.

[0034] In various examples, the coiled tubing equipment may be at least partially assembled coiled tubing equipment including a spooled-out length of coiled tubing passed through the topsides coiled tubing injector head, and optionally the subsea coiled tubing injector, and optionally the subsea stripper, and in the parking position being located outside the handling tower, near a side of the vessel, wherein the method may further comprise in the parking position load testing the coiled tubing and / or coiled tubing equipment. The load testing of the coiled tubing and / or coiled tubing equipment may conveniently be performed using external load testing means which may be located quayside or on another external structure, e.g. when the vessel is docked or moored at or adjacent to the quayside or other external structure. The method may include connecting the external load testing means to the coiled tubing and / or coiled tubing equipment on the vessel to allow load testing.

[0035] The method may further comprise: moving at least part of the hang-off portion through a side port of the handling tower, locating coiled tubing deployment equipment inside the tower; suspending the coiled tubing deployment equipment from the handling tower; using the coiled tubing deployment equipment to deploy coiled tubing through the moonpool.

[0036] In certain examples, the tower may be provided with guide rails for guiding coiled tubing deployment equipment upward or downward along the tower to allow heave compensation in use, and an injector head deployment frame arranged on the tower guide rails, and either method may further comprise any one or more of: using the guider body to move the hang-off portion into an operational position whereby the coiled tubing injector head is arranged over the moon pool and / or within the handling tower; connecting the coiled tubing injector head to the injector head deployment frame; disconnecting the coiled tubing injector head from the guider body; moving the hang-off portion of the guider body away from the moonpool from a position over the moonpool to a position outside the moonpool; in examples where the tower has an interior, extracting the hang-off portion of the guider body through an opening, e.g. a side opening of the tower, toward the parked position.

[0037] In other examples, a coiled tubing injector head may be coupled with the hang-off portion and the hang-off portion may include guide rails, the coiled tubing injector head being arranged on a frame configured to run on the guide rails, and either method may further comprise: using the guider body to move the hang-off portion into the at least one operational position, thereby arranging the coiled tubing injector head and the guide rails in the deployment region within the handling tower; suspending coiled tubinq equipment including the coiled tubing injector head from the tower, allowing the coiled tubing injector head to move upward or downward on the guide rails of the hang-off portion for compensating for heave motions; deploying coiled tubing through the moonpool.

[0038] The vessel may further comprise at least one guide rail extension section, and either method may further comprise: aligning the guide rail of the extension section with the guide rails of the hang-off portion of the guider body; allowing the suspended coiled tubing injector head to move upward or downward along the handling tower guided by the aligned guide rails of the hang- off section and the guide rail extension section.

[0039] Any of the various aspects of the invention may include any one or more further features or steps as described in relation to any other of the aspects of the invention whether described above or anywhere else herein.

[0040] Drawings and description

[0041] There will now be described, by way of example only, embodiments of the invention, with reference to the accompanying drawings, in which:

[0042] Figure 1 is a side representation of a subsea well intervention vessel;

[0043] Figure 2 is an overhead representation of the well intervention vessel of Figure 1 ; Figures 3A & 3B are overhead representations of a handling tower and hang-off system for the vessel of Figure 1 , showing the hang-off section in a first, parking position and a second, operational position respectively, according to one example;

[0044] Figures 4A & 4B are overhead and perspective representations respectively of a handling tower and hang-off system for the vessel of Figure 1 , in a first position, according to another example;

[0045] Figures 5A & 5B are overhead and perspective representations respectively of the handling tower and hang-off system of Figures 4A & 4B, in a second, intermediate position subsequent to the first, parking position;

[0046] Figures 6A & 6B are overhead and perspective representations respectively of the handling tower and hang-off system of Figures 4A & 4B, in a third, intermediate position subsequent to the second position;

[0047] Figures 7A & 7B are overhead and perspective representations respectively of the handling tower and hang-off system of Figures 4A & 4B, in a fourth, intermediate position subsequent to the third position;

[0048] Figures 8A to 8C are overhead and first and second perspective representations respectively of the handling tower and hang-off system of Figures 4A & 4B, in a fifth, operational position subsequent to the fourth position, with details of the handling tower cut away;

[0049] Figures 9A & 9B are overhead and perspective representations respectively of the handling tower and hang-off system of Figures 4A & 4B, in a sixth, operational position subsequent to the fifth position, with details of the handling tower cut away;

[0050] Figure 10 is a perspective representation of a handling tower and hang-off system for the vessel of Figure 1 , according to another example, at a first step of a process of inserting a coiled tubing injector head into the handling tower and suspending the coiled tubing injector head from the handling tower;

[0051] Figure 11 is a perspective representation of the handling tower and hang-off system of Figure 10 at a second step of the process subsequent to the first step;

[0052] Figure 12 is a perspective representation of the handling tower and hang-off system of Figure 10 at a third step of the process subsequent to the second step; Figure 13 is a perspective representation of the handling tower and hang-off system of Figure 10 at a fourth step of the process subsequent to the third step;

[0053] Figure 14 is a perspective representation of the handling tower and hang-off system of Figure 10 at a fifth step of the process subsequent to the fourth step;

[0054] Figure 15 is a perspective representation of the handling tower and hang-off system of Figure 10 at a sixth step of the process subsequent to the fifth step;

[0055] Figure 16 is a perspective representation of the handling tower and hang-off system of Figure 10 at a seventh step of the process subsequent to the sixth step;

[0056] Figure 17 is a perspective representation of a removable injector head transport device for use in the process of Figures 10 to 16;

[0057] Figure 18 is a schematic side view representation of coiled tubing equipment;

[0058] Figure 19 is a schematic side view representation of wireline equipment; and

[0059] Figure 20 is a schematic side view representation of well entry equipment.

[0060] With reference first to Figures 1 and 2, a vessel 1 is depicted at the sea surface 2. The vessel 1 is a well intervention vessel. The vessel has a hull 3, which is shown floating on the water of the sea 4, and a handling tower 6 on the hull 3, which extends vertically upward from the deck 7. The vessel 1 also includes a moonpool 9 within the hull. The moonpool 9 provides communication with the sea 4 so that equipment and / or coiled tubing suspended from the handling tower 6 can access and be lowered into or raised from sea 4 through the moonpool 9.

[0061] The moonpool 9 is accessible typically through an openable hatch 7h on the deck 7 within the handling tower 6. The handling tower 6 is for handling well equipment above the moonpool 9 and in this example has an interior deployment space 10 for the arrangement of equipment within the tower above the moonpool 9.

[0062] The hull 3 is a longitudinal structure comprising first and second hull sides 3a, 3b extending between rear and forward ends 11 , 12. A longitudinal axis 5 of the vessel extends longitudinally between the rear and forward ends 11 , 12. Furthermore, the axis 5 as depicted in Figure 2, is positioned centrally between the first and second hull sides 3a, 3b, thus can be regarded a longitudinal centreline. The handling tower 6 has an opening 16 through a rearward side section 14c of the handling tower 6. The opening 16 connects space outside the handling tower with the interior space 10 inside the handling tower 6. Furthermore, the vessel 1 is provided with a hang-off system 100. The hang-off system 100 includes a guider body in the form of a hang-off section 120 (constituting a hang-off portion) used for hanging off well intervention equipment 200 such as coiled tubing deployment / retrieval equipment 200. The hang-off system 100 allows the well intervention equipment 200 to be moved toward the moonpool 9, and in this example inserted into the deployment space 10, from a parking location outside the tower, through the opening 16 of the rearward side section 16c. To achieve this, the hang-off section 120 is rotatably connected to mount 102 fixedly disposed on the vessel outside the tower 6 or fixedly attached to the outside of the tower 6. The hang-off section 120 is thus rotatable so that at least part of the hang-off section 120 is moved through the opening 16 from a position outside the tower, such as seen in Figures 1 and 2, to a position above the moonpool 9, and inside the tower in this example, for arrangement of the well intervention equipment 200 (attached to the hang-off section 120) within the deployment space 10 and above the moonpool 9. From this position, the well intervention equipment 200 can for example be suspended from the tower for subsequent use in operations through the moonpool.

[0063] In this example, the hang-off system 100 comprises an articulated guider body including a proximal section 110 and the distal, hang-off section 120. The proximal and distal sections 110, 120 are rotationally connected at a rotational coupling therebetween, so that the distal, hang-off section 120 can be rotated with respect to the proximal section 110. The proximal section 110 in turn is rotationally connected to the mount 102 at another rotational coupling therebetween, so that the proximal section 110 can be rotated with respect to the mount 102. Servo motors may be utilised at the respective rotational couplings to drive the rotation of the sections as required.

[0064] In the parking position of Figures 1 and 2, the proximal section 110 extends between the mount 102 and the hang-off section 120 in a direction away from the longitudinal axis 5. The hang- off section 120 in turn extends away from the proximal portion 110 parallel to and offset from the longitudinal axis along the hull by offset O. This arrangement of the hang-off section 120 is facilitated by articulated structure and the wide angle of opening of the proximal section 110 away from the longitudinal axis 5. The hang-off section 120 is arranged far outside the width extent W of the opening 16. The opening 16 in the rear side section 14c of the tower 6 is thus kept free for insertion or access of other equipment, as may from time to time be desirable. In the example, the well intervention equipment 200 includes a coiled tubing injector head and gooseneck with a length of coiled tubing 240 from the coiled tubing reel 13 passed through the injector head. In this configuration, when in the stored configuration, the well intervention equipment 200 may be configured in preparation for operations, e.g., whilst other operations are ongoing within the tower, e.g. occupying the moonpool. For example, the well intervention equipment 200 can be subjected to load tests. In the example of the well intervention equipment being coiled tubing equipment, when at port, shoreside load testing devices can be applied to the coiled tubing to set up and test the load of the coiled tubing equipment. By carrying out such set up in advance and moving the already connected and load tested coiled tubing equipment with the hang-off section into the deployment region within the handling tower, the transition to coiled tubing operations can be achieved quicker. Since the well intervention equipment on the hang-off section is positioned near the side of the vessel in the parking position shoreside access can aid access to the equipment for setting up and loadtesting, etc.

[0065] In Figures 3A and 3B, the hang-off system 100’ has a hang-off section 120’ coupled rotationally to the mount 102’ via a rotational coupling 55, such that the hang-off section 120’ is rotatable with respect to the mount 102’ about the axis 55’ which is a vertical fixed axis. The rotation of the hang-off section 120’ in accordance with arrow R moves at least the distal end 120e of the hang-off section 120’, and the well intervention equipment 200’ coupled therewith, through the opening 16’ from a region outside the handling tower 6’ to a region above the moonpool 9, and in the example inside the handling tower 6’. The arrangement of Figure 3A is a parking position in which the hang-off section 120’ is substantially removed away from the opening 16’ and / or from an access corridor 76 along the vessel, the access corridor 76 having the same width or greater width than the width extent of the opening 16’ in the direction transverse to the longitudinal axis 5, so that the opening 16’ is free to access and / or access corridor 76 is free to be used by other equipment. The arrangement of Figure 3B is an operational position. The hang-off section 120 is moved from the parking position seen in Figure 3A to the operational position seen in Figure 3B through various intermediate positions.

[0066] Referring now particularly to Figures 4A and 4B, Figures 5A and 5B, Figures 6A and 6B, Figures 7A and 7B, Figures 8A, 8B, and 8C, and Figures 9A and 9B, another hang-off system 100” for well intervention equipment 200” is described along with its use and configuration in a series of different positions.

[0067] The hang-off system 100” in this example has an articulated guider body comprising three sections 110’, 120” and 130. The guider body is moved from the parking position seen in Figures 4A & 4B through various intermediate positions to the operational positions seen in Figures 8A to 8C and 9A to 9B. The section 110’ is the proximal section 110’ connected rotationally to the mount 102” at a rotational coupling 55” having an axis of rotation 55x”. The section 120” is the distal, hang-off section. The section 130 is an intermediate section arranged between the proximal section 110’ and the distal section 120”. The intermediate section 130 has a first coupling part which is connected rotationally to a coupling part of the proximal section 110’ at a rotational coupling 56 having an axis of rotation 56x. The intermediate section 130 further has a second coupling part which is connected rotationally to a coupling part of the distal, hang-off section 120” at a rotational coupling 57 having an axis of rotation 57x.

[0068] Each of the sections 110’, 120” and 130 is in the form of a rectangular panel which is arranged vertically. The panels are arranged in effect to hinge about vertical axes 55x, 56x, 57x at the rotationally couplings 55”, 56, 57.

[0069] The hang-off section 120” is configured for hanging off well intervention equipment 200” as can be seen particularly for example in Figures 4A and 4B. In particular, the well intervention equipment 200” in this example is coiled tubing equipment which in this example includes an injector head assembly 201 and a heave compensator device 202 on opposite sides of the panel section 120”. These components 201 , 202 are provided on the hang-off section 120” separate from one another, not yet assembled together in their operational configuration (for moonpool deployments from the vessel). However, the coiled tubing 240 is typically already fed through the injector head assembly 201. The hang-off system 100” is operable to rotate the sections 110’, 120” and 130 through various positions including one position in which the one side 120a” of the hang-off section 120” faces the centre region of the tower interior (see Figures 8A to 8C) for arranging the heave compensator device 202 centrally. From this position, the heave compensator device 202 can conveniently be attached at one end to a connector on an end of the main hoist line passed over an upper end of the handling tower 6”, disconnected from the hang-off section 120”, and then suspended. The hang-off system 100” can also obtain a further position in which the opposite side 120b” of the hang-off section 120” faces the centre region of the tower (see Figures 9A and 9B) for arranging the coiled tubing injector head 201 centrally, whilst the heave compensator device 202 remains suspended. From this position, the injector head assembly 201 including the coiled tubing injector 251 can conveniently be attached through one or more coupling members to the other end of the heave compensator device 202 for suspending also the injector head assembly 201 from the handling tower 6” via the main hoist line. The hang-off section 120” in this example includes guide rails 123a, 123b to which the injector head assembly 201 is coupled. The guide rails 123a, 123b of the hang-off section 120” extend vertically. When in the position of Figures 9A and 9B, and the injector head assembly 201 is connected to the heave compensator device 202, the injector head assembly 201 is allowed to travel on the guide rails 123a, 123b of the hang-off section. In this way, the guide rails 123a, 123b may permit movement of the injector head assembly 201 up or down along the handling tower 6” in response to heave motions of the vessel 1 whilst retaining and / or hindering movement of the injector head assembly 201 laterally. The vessel 1 is provided with a guide rail extension section 320 which is deployed in preparation for operation. As can be seen in Figure 9B, the guide rails 123a, 123b of the hang-off section 120” are aligned with the guide rails 323a, 323b of the extension section 320. In practice therefore, the injector head assembly 201 can travel downward from the hang-off section 120” onto the extension section 320 and vice versa, e.g. during operations in response to heave motions, e.g. during moonpool deployments. The guide rails 123a, 123b, 323a, 323b can also be utilised to position appropriately the coiled tubing injector 201 for connection of further equipment or other preparatory tasks before the equipment is suspended. The extension section 320 allows movement over greater distance upward or downward within the tower 6”.

[0070] Operations, e.g. deployment / retrieval of coiled tubing through the moonpool 9, can then be performed with the hang-off section 120” remaining in place as shown in Figures 9A and 9B. The guide rails of the extension section 320 and the hang-off section 120” allow the necessary travel upward and downward whilst providing lateral retainment of the suspended equipment.

[0071] The handling tower 6” is also provided with a cursor frame 920 which is coupled to separate vertical guide rails of the handling tower. In other examples, the injector head assembly 201 is engaged by the cursor frame 920 once the injector head assembly 201 is located in the deployment region 10” within the handling tower 6”, e.g. when in the position of Figure 9A and 9B, and the injector head assembly 201 is then disconnected from the hang-off section 120” which then can be extracted from the tower 6” leaving the injector head assembly 201 coupled to the cursor frame 920 and suspended within the handling tower 6” on the main hoist line. The suspended injector head assembly 201 and cursor frame 920 together travel up or down along the tower rails 923a, 923b.

[0072] The coiled tubing equipment 200” includes the injector head assembly 201 , and the injector head assembly 201 comprises the injector head 251 , the gooseneck 252, and the bend restrictor 253. Typically, the coiled tubing 240 is passed through the injector head assembly 201 ready load tested, e.g., load tested to withstand at least the loads expected to be imparted during operations subsea when coiled tubing equipment suspended from the handling tower and with one or more tools on the end of the coiled tubing is deployed through the moonpool. The hang-off section 120” comprises in this example a frame body 122 with vertical guide rails 123a, 123b. The hang-off section 120” further includes an injector support assembly 124 including a first injector support portion 125 which is coupled to the guide rails 123a, 123b. The first injector support portion 125 is fitted with bogies or other rail engagers permitting movement of the injector support assembly 124 upward or downward along the guide rails 123a, 123b on the frame body 122. The first injector support portion 125 comprises a body which is lockable and unlockable for locking the first injector support portion 125 with respect to the frame body 122 and / or the rails 123a, 123b until movement along the guide rails is required such as when positioned inside the tower (e.g., Figures 9A and 9B). The injector support assembly 124 further includes a second injector support portion 126 which protrudes laterally outwardly from the first injector support portion 125 to define a platform for the injector head assembly 201. More specifically, the second injector support portion 126 comprises a seat for the injector head assembly 201 , the seat comprising a seat surface onto which the injector head is seated. The seat includes one or more locating formations which extend upward from the seat surface and engage with the structure of the injector head for keeping the injector head positioned and locked rotationally with respect to the seat. The second injector support portion 126 also includes a slew coupling 58 by which the injector head assembly 201 when seated is rotatable about a vertical axis 58x of slew coupling 58. To this end, the second injector support portion 126 comprises first and second parts which are coupled via the slew coupling 58. The seat for the injector head assembly 201 is provided on the one part with the other part being a part of the structure extending from the first injector support section 125. Thus, upon slewing of the part on which the injector head assembly 201 is seated, that is rotated together with the injector head assembly 201 relative to the other part about vertical axis 58x. The rotation is controllable for example using a servomotor for driving gears in engagement with a slew ring.

[0073] The rotational orientation of the injector head assembly 201 around the axis 58x whilst coupled to the hang-off section 120” can thus be varied. For example, as can be appreciated, the orientation of the injector head assembly 201 about the axis 58x can be varied as the hang off system 100” is moved between the parking / stored position (see Figures 4A and 4B) and one or more positions in which the hang-off section 120” at least partially is located above the moonpool 9 and / or within the handling tower 6”. Thus, the orientation can be usefully varied in examples when coiled tubing 240 extends from the reel 13 to the gooseneck 252 and through the injector head assembly 201 , for aligning or maintaining alignment of the gooseneck 252 with respect to the coiled tubing 240 and / or the reel 13, as the position of the coiled tubing 240 with respect to the reel 13 changes when operating the hang-off system 100” to move from one position to the next. In the example of the hang-off system 100”, various positions are obtained through the movement and rotation of sections 110’, 120”, 130. In Figures 4A and 4B, the hang-off system 100” is a first, parking position. The proximal section 110’ extends laterally at a steep angle (approximately 70 degrees) away from and transverse to the longitudinal axis 5 toward the rotational coupling 56. The rotational coupling 56 is thus positioned wide of the mount 102 and wide of the width extent W of the opening 16” transverse to the longitudinal axis 5 toward the vessel side. The sections 110’, 120”, 130 are arranged so that the hang-off section 120 is positioned also far outside the width extent W of the access corridor 76, which extends along the vessel through the opening 16, and which is of the same width extent W to the opening 16, transverse to the vessel axis 5. This corridor 76, extending centrally and longitudinally along the vessel, allows access to the space inside the handling tower 6” without obstruction from the well intervention equipment 200, whilst the well intervention equipment 200 is stored out of the way, on standby. The vessel deck 7 is provided with skidding rails 77a, 77b extending longitudinally along the vessel and through the opening 16” and through the inside of the tower. These skidding rails 77a, 77b are positioned within the access corridor 76. Whilst the hang- off system is in the parking position, other equipment can be skidded along the rails 77a, 77b into the interior of the handling tower 6” and used in the interior space 10” therein. For example, other equipment can for example be arranged on a skiddable frame which is then skidded along the rails into and / or through the interior of the handling tower 6. In certain examples, the hang-off section 120 can be inserted whilst such a skiddable frame is located within the tower, noting that the bottom of the hang-off section 120” is arranged with some clearance above deck level so that the hang-off section can pass above part of the already inserted skiddable frame within the tower, in such an example. A lateral angle of rotation (approximately 110 degrees) is defined between the proximal section 110’ and the intermediate section 130. As such the proximal section 110’ extends along the vessel from the coupling 56 toward the coupling 57. More specifically, the proximal section 110’ extends along the vessel between coupling 56 and 57 parallel to the longitudinal axis 5 and is spaced away from the centre by a lateral offset distance O transverse to the axis 5. The distal, hang-off section 120” extends away from the coupling 57 toward a distal end parallel and aligned with the intermediate section 130. Like the intermediate section 130, the distal section 120 extends along the vessel between the coupling 56 and 57 parallel to the longitudinal axis and is spaced away from the centre by a lateral offset distance O transverse to the axis 5. (The injector head assembly 201 is arranged on an outside of the hang-off section 120” facing laterally outward from the vessel and the heave compensator device 202 is arranged on an inside of the section 120” facing inward toward vessel centre.) In Figures 5A and 5B, viewed from the proximal end 100p toward the distal end 100d of the hang-off system 100”, the distal, hang-off section 120” is rotated left toward the centre from the position of Figures 4A and 4B thus forming a lateral angle 90 degrees at the rotational coupling 57 between the distal section 120” and the intermediate section 130. (At this position, the injector head assembly 201 is facing rearward and the heave compensator device 202 is facing forward.)

[0074] In Figures 6A and 6B, still viewed from proximal end 100p toward the distal end 100d of the hang-off system 100”, the angle of 90 degrees between the distal section 120” and the intermediate section 130 is maintained, the intermediate section 130 is rotated left relative to the proximal section 110’ by 90 degrees and the proximal section 110’ is rotated left relative to the mount 120 by 70 degrees from the position of Figures 5A and 5B.

[0075] In Figures 7A and 7B, still viewed from proximal end 100p toward the distal end 100d of the hang-off system 100”, the angle of 90 degrees between the distal section 120” and the intermediate section 130 is maintained, the angle of 90 degrees between the intermediate section 130 and the proximal section 110’ is maintained, and the proximal section 110’ is rotated left by 35 degrees relative to the mount from the position of Figures 6A and 6B. At this position, the hang-off section 120” is located above the moonpool and inside the tower. Thus, between the position of Figures 6A and 6B and the position of Figures 7A and 7B the hang-off section is moved from outside the tower 6” through the opening 16” into the region 10” above the moonpool, inside of the tower.

[0076] In Figures 8A, 8B, and 8C, still viewed from proximal end 100p toward the distal end 100d of the hang-off system 100”, the angle of 90 degrees between the intermediate section 130 and the proximal section 110’ is maintained, the proximal section 110’ is rotated left by 55 degrees relative to the mount and the distal section is rotated right by 180 degrees from the position of Figures 6A and 6B. The heave compensator device 202 coupled to the hang-off section 120” is arranged over the moonpool centre. From this position, the heave compensator device 202 can be connected to the tower hoisting line, then decoupled from the hang-off section 120”, and then suspended within the tower 6” from the tower hoisting line ready for coupling of the injector head assembly 201 to the heave compensator device 202 which can take place once in the position of Figures 9A and 9B.

[0077] In Figures 9A and 9B, still viewed from proximal end 100p toward the distal end 100d of the hang-off system 100”, the angle of 90 degrees between the intermediate section 130 and the proximal section 110’ is maintained, the distal section 120” is rotated left by 90 degrees from the position of Figures 8A, 8B, and 8C. This unfolds the distal and intermediate sections 120”, 130 so that the injector head assembly 201 is now positioned over the moonpool centre. As described above, in this position, the heave compensator device 202 can be connected to the injector head assembly 201 , and the injector head assembly 201 is unlocked such that the suspended injector head assembly is allowed to travel up and down the guide rails 123a, 123b. The extension section 320 is aligned with the guide rails 123a, 123b.

[0078] The sequence can be performed in reverse.

[0079] With reference now to Figures 10 to 17, a hang-off system 100”’ is used in various steps of a process. The hang-off system 100”’ in this example comprises an articulated body comprising four articulated sections one rotationally coupled to the next, the sections including a proximal section 110”, a distal, hang-off section 120’”, a first intermediate section 130’, and a second intermediate section 140. The proximal section 110” is coupled rotationally to the mount 102’”. In this example, also the hang-off section 120’” has an alternative configuration. In this example the hang-off section 120” comprises a vertical rectangular panel frame 522 and an injector head support portion 525 extending laterally outward from the vertical panel frame 522. The injector head support portion 525 comprises an openable clamping ring 582 into which an injector head assembly transport device 590 is receivable. The injector head transport device 590 is depicted in further detail in Figure 17. The injector head assembly transport device 590 provides a seat 592 for seating the injector head 252 on the transport device 590. The transport device 590 has a central bore 591 allowing the bend restrictor 253 to extend through the bore 591 , whilst the injector 252 rests on a seat surface 593. The seat 590 has locating formations 594a-594d for further engaging a structure of the injector head 252. In Figure 10, the hang- off system 100’” is shown without well intervention equipment coupled to the hang-off section. In Figure 11 , the injector head transport device 590 is inserted into the clamping ring 582 of the hang-off section 120’” and the injector head assembly 20T in turn is arranged on the seat 592 of the transport device 590. The hang-off system 100’” is in the parking position outside the handling tower 6’” ready to be moved into the inside of the handling tower 6’” to a position above the moonpool through the tower side opening 16’”. The handling tower 6’” has tower guide rails 423a, 423b running vertically along the inside of the handling tower 6’” and an injector head tower support assembly 420 arranged to run upward and downward on the tower rails 423a, 423b. The injector head tower support assembly 420 includes an injector head support frame 422 comprising a cantilever frame portion 422c extending from the guide rail structure laterally toward the centre region of the tower interior, so as to be arranged above the moonpool centre. The cantilever portion 422c of the injector head tower support frame 422 includes a receptacle 425 for receiving the injector head transport device 590. In Figure 12 the injector head tower support frame 422 is positioned appropriately along the guide rails 423a, 423b in the tower 6”’ in anticipation of moving the hang-off section 120”’ along with the injector head assembly 201’ into the inside of the tower. In Figure 13, the hang-off system 100’” has been operated to move the hang-off section 120’” into the tower. The injector head assembly 20T is arranged with the bend restrictor 253 above the receptacle 425 of the injector head tower support frame 422 which then in Figure 14 is moved upward to engage with a part of the injector head transport device 590 which is received in the receptacle 425. The clamping ring 582 of the hang-off section 120’” is opened and decoupled from the transport device 590, and the hang-off section 120” is retracted out of the tower 6’” back into the parking positions as seen in Figure 15, leaving the injector head assembly 20T now supported on the injector head tower support frame 422. The injector head assembly 20T can then be connected to the passive heave compensator device 202 suspended from the main hoist line of the tower 6’” and suspended on the hoist line, as seen in Figure 16. The suspended injector head tower support frame 422 is configured so as to be freely movable up or down on the tower along the rails 423a, 423b in response to heave motions of the vessel whilst being retained laterally with respect to the tower 6’”. Thus, operations, e.g. the deployment / retrieval of coiled tubing, through the moonpool 9 can be carried out using the suspended injector head assembly 20T.

[0080] The sequence can of course also be performed in reverse.

[0081] Various modifications and improvements may be made without departing from the scope of the invention described herein. As can be appreciated, the well intervention equipment in any of the examples above can take different forms. Examples of well intervention equipment are provided with reference to Figures 18 to 20. In Figure 18, the well intervention equipment is coiled tubing equipment 700. In Figure 19, the well intervention equipment is wireline equipment 800. In Figure 20 the well intervention equipment is well entry equipment 900.

[0082] Although the coiled tubing equipment 700 and wireline equipment 800 of Figures 18 and 19 are depicted in assembled form, the well intervention equipment can alternatively be distributed form, for example in the form of unassembled or separate components or merely partially assembled. The well intervention equipment can be any one or more of the components described with reference to Figures 18 to 20 and they can be hung-off separately or with any one or more other components of the equipment of Figures 18 to 20 connected thereto, as desired. Thus, as can be appreciated any one, some, or all of the components of the coiled tubing equipment 700 or wireline equipment 800 can be hung off from the hang-off portion or hang-off section. The coiled tubing equipment 700 includes any one or more of: topsides coiled tubing injector head 715; a gooseneck 714; apparatus for suspending the coiled tubing injector head 715 from the handling tower, the apparatus including any one or more of passive heave compensator 712, connecting members 713, e.g. wires, for connecting the coiled tubing injector head 715 to the passive heave compensator 712, and connector 711 for connecting the passive heave compensator to hoisting gear supported on the tower, typically to a main hoisting winch; a length of coiled tubing 740; a subsea injector device 716 on the coiled tubing 740; a subsea stripper 717 on the coiled tubing 740; one or more tools 719; and end connector 718 through which the one or more tools 719 are connected to the end of the coiled tubing 740. The coiled tubing 740 is in certain examples passed over the gooseneck 714 and through the coiled tubing injector head 715, the subsea injector device 716, and / or the subsea stripper 717. The configuration shown in Figure 18 demonstrates how the coiled tubing equipment 700 once assembled and suspended in the handling tower and above the moonpool may generally be configured.

[0083] The wireline equipment 800 includes any one or more of: a support arm 811 configured to be coupled to the tower for use in wireline operations; a passive heave compensator cylinder 812; a sheave 814 arranged on the passive heave compensator; a length of wireline 840; subsea pressure control head 817 on the wireline; one or more wireline tools 819; end connector 818 of the wireline for connecting the one or more tools to an end of the wireline 840. The passive heave compensator comprises a part connecting to the sheave and a part connecting the support arm to compensate for heave induced motions of the vessel relative to the hang off point of the wireline at the sheave 814. The wireline is in certain examples passed over the sheave 814 and / or through the pressure control head and / or connected to a winch to be spoolable in or out from a winch (not shown). The configuration shown in Figure 19 demonstrates how the wireline equipment 800 once assembled and suspended in the handling tower and above the moonpool may generally be configured.

[0084] The subsea well entry equipment 900 in this example comprises a tubular lubricator body 901 for accommodating one or more tools 809, 709 deployed from a vessel, within the lubricator body. The apparatus 900 is generally representative both for wireline and coiled tubing operations, although the configuration of the lubricator may differ for wireline and coiled tubing operations. In a coiled tubing operation, a subsea stripper 717 is provided for connection to the upper end 901 of the lubricator. In a wireline operation, a pressure control head 817 is provided for connecting to the upper end 901. However, both the stripper 717 and the pressure control head 817 provide fluid sealing and pressure containment between the inside of the lubricator body 901 and the surrounding sea and must be connected to the lubricator for providing the necessary pressure containment before the tool string on the wireline 840 or on coiled tubing 740 enters the wellbore. A lower end 902 of the lubricator body is configured to be coupled to the subsea wellhead. More specifically, the lower end 902 is configured to connect to a pressure control package. The upper end 903 of the lubricator body 901 is configured to couple with the pressure control head 917 on the wireline 840. Valves 905, 906 allow for sluicing the tool string into the interior of the lubricator body 901 . The valve 906 may then be opened to allow pressure communication between the lubricator and the wellbore through the pressure control package. The one or more tools 709, 809 can be lowered into the well from the lubricator.

[0085] The guider body or articulated guider body can in various examples also have a plurality of hang-off portions or hang-off sections with different parts on different hang-off portions. In various examples, one or more hang-off portions are used for wireline equipment and one or more other hang-off portions are used for coiled tubing equipment.

[0086] Although various examples above are described with the handling tower defining an interior above moonpool, in alternative examples the handling tower extends upward from a side of the moonpool to reach over it and / or the moonpool is arranged at least partially outside the tower. It can thus be appreciated that the well intervention equipment although can for example be arranged above the moonpool yet not within an interior space of the tower such as for example the interior space 10, 10’, 10” as described above.

Claims

CLAIMS1. A vessel comprising: a hull; a moonpool; a handling tower for handling well intervention equipment above the moonpool; a mount arranged outside, or on an outside of, the handling tower; and a guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment; the first end connected to the mount and the second end extending away from the mount, the guider body being pivotably rotatable relative to the mount about a vertical axis, so as thereby to move the hang-off portion of the guider body relative to the handling tower, in use, between a parking position in which the well intervention equipment is hung off outside the handling tower and at least one operational position in which the well intervention equipment is hung off above the moonpool.

2. A vessel as claimed in claim 1 , wherein the hang-off portion is arranged at or near the second end.

3. A vessel as claimed in claim 1 or 2, wherein the hang-off portion is arranged between the first and second ends.

4. A vessel as claimed in any of claims 1 to 3, wherein through so rotating the guider body, at least one hang-off portion is movable at least partially through a side opening or port of the handling tower between the parking position and the at least one operational position.

5. A vessel as claimed in any of claims 1 to 4, wherein in the parking position, the hang- off portion is arranged outside the handling tower, and wherein in at least one operational position at least one hang-off portion is arranged at least partially inside the handling tower.

6. A vessel as claimed in any preceding claim, wherein the guider body is a vertically arranged panel.

7. A vessel comprising: a hull; a moonpool;a handling tower for handling well intervention equipment above the moonpool; a mount arranged outside, or on an outside of, the handling tower; and an articulated guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment; the first end connected to the mount and the second end extending away from the mount, the articulated guider body being pivotably rotatable about a vertical axis relative to the mount and articulated sections of the guider body being individually rotatable relative to one another and the mount, one pivotably rotatable relative to the next about a vertical axis, so as thereby to move the hang-off portion of the guider body relative to the handling tower, in use, between a parking position in which the well intervention equipment is hung off outside the handling tower and at least one operational position in which the well intervention equipment is hung off above the moonpool.

8. A vessel as claimed in claim 7, wherein the articulated sections are vertically arranged panels.

9. A vessel as claimed in claim 7 or claim 8, wherein the articulated sections include a first, proximal section and a second, distal section, and optionally at least one intermediate section.

10. A vessel as claimed in claim 9, at least one hang-off portion being a portion of the distal section or an intermediate section.

11. A vessel as claimed in claim 9 or 10, wherein the distal section has a first hang-off portion for hanging off first well intervention equipment on one side of the distal section and a second hang-off portion for hanging off second well intervention equipment on an opposite side of the distal section.

12. A vessel as claimed in claim 11 , wherein: in a first operational position, the first hang hang-off portion is arranged for locating the first well intervention equipment either or both: inside the tower at or near the centre of the tower; and / or over the moonpool at or near the centre of the moonpool; and in a second operational position, the second hang-off portion is arranged for locating the second well intervention equipment either or both: inside the tower at or near the centre of the tower; and / or over the moonpool at or near the centre of the moonpool.

13. A vessel as claimed in claim 12, wherein the distal section is rotated relative to an adjacent intermediate or proximal portion to move between the first operational position and the second operational position.

14. A vessel as claimed in any of claims 7 to 13, wherein in the parking position, the hang- off portion is arranged outside the handling tower, and wherein in at least one operational position at least one hang-off portion is arranged at least partially above the moonpool and / or at least partially inside the handling tower.

15. A vessel as claimed in any of claims 7 to 14, wherein through so rotating the articulated guider body, at least one hang-off portion is movable at least partially through an access side opening or port of the handling tower between the parking position and the at least one operational position.

16. A vessel as claimed in claim 4 or claim 15, wherein in the parking position, the hang- off portion is arranged away from and / or outside the width extent of the opening.

17. A vessel as claimed in claim 16, wherein the access opening is an opening having a width transverse to a central longitudinal axis of the vessel, and wherein in the parking position the hang-off position is arranged outside of the transverse extent of the opening and closer to the vessel side than to the central longitudinal axis.

18. A vessel as claimed in any of claims 15 to 17, wherein the access opening is an opening having a width extending transverse to a longitudinal axis of the vessel, and wherein in the parking position, the hang-off portion and / or second end of the guider body arranged away from the opening so as not to obstruct the opening and / or so as to allow access of other equipment through the opening into an interior of the tower.

19. A vessel as claimed in any preceding claim, wherein in the parking position, the guider body extends from the mount away from an outside of the tower.

20. A vessel as claimed in any preceding claim, wherein the hang-off portion comprises one or more elements for coupling well intervention equipment to the guider body for hanging off well intervention equipment.

21. A vessel as claimed in any preceding claim, wherein the hang-off portion comprises vertical guide rails and a part arranged to be mounted to the guide rails for permittingmovement of the part up / down along the guide rails and retaining movement laterally, the part configured to have an injector head assembly connected thereto.

22. A vessel as claimed in any preceding claim, wherein the hang-off portion comprises one or more elements for coupling passive heave compensator device on the guider.

23. A vessel as claimed in any preceding claim, wherein the guider body is disposed on the mount, extending toward the second end in suspended relationship above deck level.

24. A vessel as claimed in any preceding claim, wherein the guider body has a first hang- off portion for hanging off first well intervention equipment on one side of the guider body and a second hang-off portion for hanging off second well intervention equipment on the opposite side of the guider body.

25. A vessel as claimed in any preceding claim, including the well intervention equipment, the well intervention equipment coupled to the at least one hang-off portion.

26. Apparatus for mounting to a vessel, the vessel comprising a hull, a moonpool, a handling tower for handling well intervention equipment above the moonpool, and a mount configured to be arranged outside, or on an outside of, the handling tower on the vessel, the apparatus comprising: a guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment; the first end configured to be connected to the mount and the second end to extend away from the mount, the guider body configured to be pivotably rotatable relative to the mount about a vertical axis, for moving, in use, the hang-off portion of the guider body relative to the handling tower between a parking position in which, in use, the well intervention equipment is hung off outside the handling tower and at least one operational position in which, in use, the well intervention equipment is hung off above the moonpool.

27. Apparatus for mounting to a vessel, the vessel comprising a hull, a moonpool, and a handling tower for handling well intervention equipment above moonpool, and a mount configured to be arranged outside, or on an outside of, the handling tower on the vessel, the apparatus comprising: an articulated guider body having first and second ends and at least one hang-off portion for hanging off well intervention equipment;the first end configured to be connected to the mount and the second end extending away from the mount, the articulated guider body configured to be pivotably rotatable about a vertical axis relative to the mount and articulated sections of the guider body configured to be individually rotatable relative to one another and the mount, one pivotably rotatable relative to the next about a vertical axis, for moving, in use, the hang-off portion of the guider body relative to the handling tower between a parking position in which, in use, the well intervention equipment is hung off outside the handling tower and at least one operational position in which, in use, the well intervention equipment is hung off above the moonpool.

28. A method of preparing for deployment of coiled tubing from the vessel of any one of claims 1 to 6 or claims 19 to 25 when dependent upon any of claims 1 to 6, the method comprising the step of: hanging off coiled tubing well intervention equipment from the hang-off portion of the guider body.

29. A method as claimed in claim 28, which further comprises the step of pivotably rotating the guider body about the vertical axis relative to the mount between the parking position and the at least one operational position.

30. A method of preparing for deployment of coiled tubing from the vessel of any one of claims 7 to 18 or any one of claims 19 to 25 when dependent upon any one of claims 7 to 18, the method comprising the step of: hanging off coiled tubing well intervention equipment from the hang-off portion of the articulated guider body.31 . A method as claimed in claim 30, which further comprises: pivotably rotating either or both of: the articulated guider body about a vertical axis relative to the mount; and articulated sections of the guider body individually relative to one another and the mount, one section pivotably rotating relative to the next about a vertical axis; thereby moving the hang-off portion between the parking position and the at least one operational position.

32. A method as claimed in any of claims 28 to 31 , wherein the coiled tubing equipment comprises a spooled-out length of coiled tubing passed through the topsides coiled tubing injector head, the coiled tubing equipment in the parking position being located outside the handling tower, near a side of the vessel;the method further comprising in the parking position load testing the coiled tubing and / or coiled tubing equipment using external load testing means located quayside or on another external structure with the vessel docked or moored.

33. A method as claimed in any of claims 28 to 32, which further comprises moving at least part of the hang-off portion through a side port of the handling tower, locating coiled tubing deployment equipment inside the tower; suspending the coiled tubing deployment equipment from the handling tower; using the coiled tubing deployment equipment to deploy coiled tubing through the moonpool.

34. A method as claimed in any of claims 28 to 33, wherein the tower is provided with guide rails for guiding coiled tubing deployment equipment upward or downward along the tower to allow heave compensation in use, and an injector head deployment frame arranged on the tower guide rails, and the method further comprises: using the guider body to move the hang-off portion into an operational position whereby the coiled tubing injector head is arranged over the moonpool and / or within the handling tower; connecting the coiled tubing injector head to the injector head deployment frame; disconnecting the coiled tubing injector head from the guider body; moving the hang-off portion of the guider body away from the moonpool, from a position over the moonpool to a position outside the moonpool, e.g. through the opening toward the parked position.

35. A method as claimed in any of claims 28 to 34, wherein a coiled tubing injector head is coupled with the hang-off portion and the hang-off portion includes guide rails, the coiled tubing injector head being arranged on a frame configured to run on the guide rails, and the method further comprises: using the guider body to move the hang-off portion into the at least one operational position, thereby arranging the coiled tubing injector head and the guide rails in the deployment region over the moonpool and / or within the handling tower; suspending coiled tubinq equipment including the coiled tubing injector head from the tower, allowing the coiled tubing injector head to move upward or downward on the guide rails of the hang-off portion for compensating for heave motions; deploying coiled tubing through the moonpool.

36. A method as claimed in claim 35, wherein the vessel further comprises at guide rail extension section, and the method further comprises:aligning the guide rail of the extension section with the guide rails of the hang-off portion of the guider body; allowing the suspended coiled tubing injector head to move upward or downward along the handling tower guided by the aligned guide rails of the hang-off section and the guide rail extension section.

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