Handling, testing, storing an in-riser landing string assembly onboard a floating vessel

Abstract

A method for handling and/or testing an in-riser landing string assembly onboard a floating vessel, which method comprises the use of an in-riser landing string assembly cart, e.g. a skiddable in-riser landing string assembly cart, having a cart base, e.g. a cart base configured to be skidded over skid rails on a deck of the vessel, and having a support tower erected on said cart base. The in-riser landing string assembly is arranged and retained in vertical orientation on said cart with the support tower providing lateral support for the in-riser landing string assembly, e.g. the in-riser landing string assembly being temporarily secured to the tower at different elevations along the height of the support tower.

Claims

1. A method for handling an in-riser landing string assembly onboard a floating vessel, the in-riser landing string assembly being configured to be deployed from said vessel inside a marine riser that extends between said vessel and subsea well equipment by means of landing string tubing in order to conduct one or more operations, wherein the method comprises: onboard said vessel, transferring the in-riser landing string assembly between a remote location and a deployment location; using an in-riser landing string assembly cart having a cart base and having a support tower erected on said cart base; arranging and retaining the in-riser landing string assembly in a vertical orientation on said cart with the support tower providing lateral support for the in-riser landing string assembly; and moving the cart with said in-riser landing string assembly arranged and retained in the vertical orientation thereon between said remote location and said deployment location above the marine riser, wherein the method involves the use of at least one landing string assembly umbilical winch that is arranged adjacent the deployment location, and wherein the method comprises connecting an umbilical of said winch to the in-riser landing string assembly retained by the support tower whilst the cart is offset from the deployment location, and wherein the method comprises a later displacement of the cart to the deployment location with the umbilical remaining connected to the in-riser landing string assembly.

2. The method according to claim 1, wherein the method comprises the deployment of the in-riser landing string assembly into the marine riser, wherein multiple landing string tubing joints are added to the landing string and so the in-riser landing string assembly is lowered down in the marine riser until the subsea equipment is reached where the assembly, or a part thereof, is accommodated.

3. The method according to claim 2, wherein the deployment of the landing string into the marine riser is done with the cart and support tower having been relocated or moved into an offset location remote from the deployment location, with an umbilical passing from an umbilical winch over an umbilical guide that is mounted on the support tower on the cart.

4. The method according to claim 1, wherein a structural frame of the support tower or one or more tower parts thereof is embodied with a recessed receiving space for the in-riser landing string assembly that is open in a lateral side of said structural frame, and wherein the method comprises the introduction or removal of one or more components of the landing string assembly in a lateral direction from the outside into said recessed receiving space and vice versa.

5. The method according to claim 1, wherein an in-riser landing string assembly is transferred by means of the in-riser landing string assembly cart into the deployment location above the marine riser and then one or more landing string tubing joints or stands are connected to a top end of the in-riser landing string assembly and the in-riser landing string assembly is then suspended from said one or more landing string tubing joints or stands, where after the cart with support tower is moved away and placed at a remote location.

6. The method according to claim 5, wherein, with the cart and support tower moved to a location remote from the deployment location, the in-riser landing string assembly is lowered until the landing string tubing passes through a slip device and said slip device is then made to engage on said landing string tubing, followed by stepwise lengthening of the landing string by adding landing string tubing joints or stands, until the assembly is landed onto a tubing hanger of the subsea equipment.

7. A method for handling an in-riser landing string assembly onboard a floating vessel, the in-riser landing string assembly being configured to be deployed from said vessel inside a marine riser that extends between said vessel and subsea well equipment by means of landing string tubing in order to conduct one or more operations, wherein the method comprises: onboard said vessel, transferring the in-riser landing string assembly between a remote location and a deployment location; using an in-riser landing string assembly cart having a cart base and having a support tower erected on said cart base; arranging and retaining the in-riser landing string assembly in a vertical orientation on said cart with the support tower providing lateral support for the in-riser landing string assembly; moving the cart with said in-riser landing string assembly arranged and retained in the vertical orientation thereon between said remote location and said deployment location above the marine riser; storing the support tower and one or more in-riser landing string assemblies retained by said support tower as a unit in a horizontal orientation; and upending said unit.

8. A floating vessel provided with an in-riser landing string assembly that is configured to be deployed from said vessel inside a marine riser that extends between said vessel and subsea well equipment by means of landing string tubing in order to conduct one or more operations, wherein the in-riser landing string assembly is transferrable between a remote location and a deployment location, wherein the vessel is provided with an in-riser landing string assembly cart having a cart base and having a support tower erected on said cart base, wherein the cart with the support tower is configured to have the in-riser landing string assembly arranged and retained in a vertical orientation on said cart with the support tower providing lateral support for the in-riser landing string assembly, wherein the cart is configured so that, with said in-riser landing string assembly arranged and retained in the vertical orientation thereon, the cart is movable between said remote location and said deployment location above the marine riser, and wherein the vessel has a wellbore activities installation which comprises: a mast; a rig floor having a well center at the deployment location through which a tubulars string can pass along a firing line; a tubulars storage rack adjacent the mast for storage therein of multi-joint tubular stands; at least one vertical trolley rail extending along the mast; a trolley, said trolley being guided along said at least one vertical trolled rail; a top drive device attached or to be attached to the trolley, said top drive device comprising one or more top drive motors adapted to impart rotary motion to a tubulars string when connected to said top drive device; a hoisting device or drawworks adapted to move the trolley with the top drive device up and down along said at least one vertical trolley rail; a vertical motion arm rail extending along the mast; a motion arm assembly comprising a motion arm base and an extensible and retractable motion arm, wherein the motion arm base is guided by said vertical motion arm rail, and wherein the motion arm has an operative reach that encompasses the firing line, said motion arm assembly being adapted to support at least one of a well center tool and a tubular gripper member, and allowing to bring said well center tool or tubular gripper member in the firing line; and a vertical motion arm drive adapted to move the motion arm base along said vertical motion arm rail.

9. The floating vessel according to claim 8, wherein the vessel is provided with a rail system comprising skid rails extending at least between said remote location and said deployment location, and wherein the cart base is configured to be skidded over said skid rails, and wherein the vessel has a pair of skid rails extending over a rig floor, along opposite sides of a well center, with the cart base being so skiddable into the deployment location above or adjacent the well center.

10. The floating vessel according to claim 8, wherein the vessel comprises at least one landing string assembly umbilical winch that is arranged or is configured to be arranged adjacent the deployment location, and wherein said winch has an umbilical that is connected or is connectable to the in-riser landing string assembly.

11. The floating vessel according to claim 8, wherein the support tower has a tower height of between 20 and 36 meters.

12. The floating vessel according to claim 8, wherein a structural frame of the support tower or one or more tower parts thereof is embodied with a recessed receiving space for the in-riser landing string assembly that is open in a lateral side of said structural frame, said open lateral side allowing for the introduction or removal of one or more components of the landing string assembly in a lateral direction from the outside into said recessed receiving space and vice versa.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) The invention will now be explained with reference to the drawings. In the drawings:

(2) FIG. 1 shows a part of an offshore vessel for use in a wellbore activities according to the invention with a mast, trolley, vertical rails on the mast, multi-joint tubular stand storage racks, a rig floor, a moonpool, rig floor skid rails, etc.,

(3) FIG. 2 shows a plan view of the vessel of FIG. 1 with the in-riser landing string assembly cart and tower in deployment location,

(4) FIG. 3 shows the a part of the plan view of FIG. 2 on a larger scale,

(5) FIG. 4 illustrates the tower in the deployment position,

(6) FIG. 5 shows a cross section of a part of the vessel of FIG. 1 with the in-riser landing string assembly cart and tower in deployment location and with a complete in-riser landing string assembly as well as a landing string tubing joint and umbilical connected thereto,

(7) FIG. 6 shows on a larger scale a part of the view of FIG. 5,

(8) FIG. 7 shows on a larger scale another part of the view of FIG. 5,

(9) FIG. 8 illustrates that the in-riser landing string assembly cart and tower are located in a testing location somewhat remote from the deployment location, as well as the situation during deployment of the landing string into the marine riser wherein an auxiliary umbilical guide is mounted on a motion arm,

(10) FIG. 9 illustrates the two containerized tower parts that make up the tower on the in-riser landing string assembly cart of FIGS. 1-8,

(11) FIGS. 10a-d illustrate another embodiment of an in-riser landing string assembly cart.

(12) FIG. 11a-c illustrate the 40 ft. tower parts of the cart of FIG. 10a-d,

(13) FIG. 12a-c illustrate the 20 ft. tower part of the cart of FIG. 10a-d,

(14) FIG. 13 illustrates the combined lower and upper assemblies when lowered,

(15) FIG. 14 illustrates the combination of FIG. 13 with the riser and subsea equipment on the well head,

(16) FIG. 15 illustrates the handling of assemblies with the support tower as a unit on a catwalk machine,

(17) FIG. 16 illustrates the upending of the unit of FIG. 15,

(18) FIG. 17 illustrates the unit being upended and suspended from the drawworks,

(19) FIG. 18 illustrates the lowering of the unit onto the corresponding cart base,

(20) FIG. 19 illustrates the testing of the assemblies whilst other activity is performed at the well center,

(21) FIG. 20 illustrates the placing of the cart in the deployment location,

(22) FIG. 21 illustrates the handling of the lower assembly whilst the cart with upper assembly has been moved back to a testing location,

(23) FIG. 22 illustrates the lowering of the interconnected production tubing and assembly,

(24) FIG. 23 illustrates the combination of assemblies having been lowered,

(25) FIG. 24 illustrates the use of a riser tension frame in heave compensation mode in combination with the inventive cart.

DETAILED DESCRIPTION OF EMBODIMENTS

(26) FIG. 1 shows a part of the hull 1 of an offshore vessel. It is envisaged that the depicted offshore vessel is adapted for performing offshore drilling and/or other wellbore related activities, e.g. well completion, well intervention, etc.

(27) Here it is illustrated that the vessel is a monohull vessel having a moonpool (inside the depicted part) through which imaginary firing line 2 extends to the subsea site of a subsea wellbore, where a well head is provided with subsea equipment like a subsea tree and/or Blow Out Preventer (BOP) stack or the like.

(28) The depicted part has a deck 3 and a rig floor or drill floor 4 that is, as preferred, flush with the deck 2. The rig floor 4 has a well center 5, here recessed to receive therein one or more slip devices as will be explained.

(29) On the deck 3 and over the rig floor 4 pairs of parallel skid rails 6,7,8 extend, with the rails 6 extending over the deck 3 as well as over the rig floor 4 and on opposite sides of the well center 5. The rails 7, 8 are orthogonal to the rails 6, for example as shown here the rails 6 being transverse to the elongated hull of the vessel and the rails 7, 8 extending in longitudinal direction of the hull.

(30) As is known in the field a marine riser 9 extends between the vessel and the subsea equipment, e.g. the vessel having a riser tensioner system that engages the top portion of the marine riser.

(31) FIG. 1 shows a mast 10 that is here embodied with a closed contoured steel structure with the firing line 2 outside of the mast 10 itself.

(32) Here the mast 10 is arranged adjacent the moonpool.

(33) In another, less preferred embodiment due to the envisaged height of the support tower and the in-riser landing string assembly or assemblies to be handled in conjunction with the present invention, the mast 10 could be replaced by a derrick that is placed over the moonpool, so that the firing line 2 extends within the framework of the derrick.

(34) Other arrangements, e.g. with the mast 10 arranged over an elongated moonpool to form two moonpool areas, e.g. front and aft of the mast 10, are equally known and advantageous in conjunction with the present invention.

(35) As illustrated in FIGS. 5 and 6 one or more slip devices 11, 12 can be arranged at or near the well center. These figures show two such slip devices 11, 12 in a sunken compartment below the surface of the rig floor 4. The slip devices 11, 12 are movable, e.g. skiddable between opposed parking positions remote from the firing line and an operative position aligned with the firing line 2. As known in the art a slip device 11, 12 can retain a suspended tubular string, e.g. a landing string tubing.

(36) The mast 10 is provided at the side of the well center 5 with two parallel vertical trolley rails 17, 18.

(37) A trolley 20 is guided along the trolley rails 17,18.

(38) A top drive device 30 (not shown in detail here) is releasably attached to the trolley 20. The top drive device 30 is able to impart rotary motion and drive torque to a tubulars string.

(39) A main firing line hoisting device 50, often called drawworks, is provided and is adapted to move the trolley 20 with the top drive device 30 up and down along the vertical trolley rails 7,8. Here the hoisting device 50 comprises a crown block 51, a travelling block 52, and a hoisting cable arranged in a multiple fall arrangement between said blocks 51, 52. One or more winches of the hoisting device, e.g. arranged within or underneath the mast 10, operate the hoisting cable. These one or more winches may be heave compensated winches as is known in the art and/or one or more other heave compensation devices may be arranged to act on the cable, e.g. on the cable stretch between the one or more winches and the crown block 51 as is known in the art. This allows to move the travelling block 52, and thus the trolley 20, in a heave compensating mode.

(40) A left-hand motion arm rail 60 and a right-hand motion arm rail 61 are present on opposed lateral sides of a vertical path of travel of the trolley 20 with the top drive device 30 along said the vertical trolley rails 17,18.

(41) On each of said motion arm rails 60, 61 at least one, here three as is preferred, motion arm assembly 70, 71, 72, 80, 81, 82 is arranged. Each assembly is, as preferred independently controlled from any other motion arm assembly on the same rail 60, 61, vertically mobile along the respective rail by a respective motion arm assembly vertical drive.

(42) As is preferred the assemblies 70, 71, 72, 80, 81, 82 have an identical structure. For example the assembly 71 has a base 74 that is mounted vertically mobile on the vertical rail 60.

(43) The assembly 71 further comprises an extensible and retractable motion arm 75, here a telescopic arm with a first arm section connected to the base 74, and one or more, here two, telescopic second and third arm sections. For example the arm sections are extensible by associated hydraulic cylinders of the arm 75. The motion arm has an operative reach that encompasses the firing line 2 so that the arm can handle tubulars and/or well center equipment, or other tooling that needs to be presented or held in the firing line.

(44) As is preferred the arm 75, here the first arm section, is connected to the base 74 via a slew bearing 76 allowing to rotate the arm about a vertical axis by means of an associated slew drive.

(45) The assembly 70 further comprises a motion arm assembly vertical drive, e.g. with one or more motors each driving a pinion meshing with a rack that extends along the rail 60. Thereby the base 74 can move along the at least one vertical motion arm rail 60 and, for example, the drive with motor is sufficiently strong to do so while the motion arm assembly carries a load in the firing line 2 of at least 1000 kg, preferably at least 5000 kg.

(46) At the end of the motion arm 75 a mechanical coupler part is provided. By means of the coupler part the motion arm assembly 70, here each of the depicted motion arm assemblies, is able to support at least one of a well center tool, e.g. an iron roughneck tool 85, or a tubular gripper member 90, and allowing to bring said well center tool or tubular gripper member in the firing line.

(47) For this reason each of said tubular gripper members 90 and/or the iron roughneck tool 85 is provided with a mechanical coupler part that is adapted to be mated with the mechanical coupler part that is fitted on the motion arm 75 such that the respective gripper member, iron roughneck tool, or other well center tool, becomes fixed to the respective motion arm and fully and directly follows any motion of the motion arm.

(48) Left and right of the mast 10 the depicted vessel has a tubulars storage rack 110, 120, here embodied as carrousels as is known in the art, adapted to store therein multi-joint tubular stands, e.g. triples, quads, or even stands of six joints, in vertical orientation therein. The tubular stands can comprises drill pipe, casing, landing string tubing, etc.

(49) As is known in the art, by means of two or three of the motion arm assemblies 70, 71, 72, 80, 81, 82 a multi-joint tubular can be gripped by said assemblies in unison and then transferred between a storage rack 110, 120 on the one hand and a position over the well center in the firing line 2. So the motion arm assembly is, as is preferred, usable as part of a piperacker. Of course it will be possible to grip and carry one tubular joint or something similar, even when much heavier, by means of a single motion arm assembly, in particular when a single motion arm assembly would be rated to carry a roughneck device.

(50) In an embodiment it is envisaged that a motion arm assembly, preferably provided with said synchronization functionality, is provided with a man-riding basket or cage, e.g. allowing transfer of personnel to the riser tension frame while performing a heave motion compensation motions relative to the tower 10.

(51) The vessel is equipped with an in-riser landing string assembly cart 130, here a skiddable in-riser landing string assembly cart.

(52) The cart 130 has a cart base 131, here a cart base configured to be skidded over the skid rails 6, 7, 8 of the vessel.

(53) The cart 130 further has a support tower 140 erected on the cart base 131.

(54) The cart base 131 is skiddable in two orthogonal directions over the rail system of the vessel having rails in said two orthogonal directions with a skid mechanism 132 operable to move the cart base in an X-direction and another skid mechanism 133 operable to move the cart base in a Y-direction. This allows to skid the cart 130 over the rails 6,7,8 into a deployment location above or adjacent the well center 5 of the rig floor 4.

(55) Schematically, yet to scale, depicted in FIGS. 2-8 is an in-riser landing string assembly 150 which is arranged and retained in vertical orientation on the cart 130 with the support tower 140 providing lateral support for the in-riser landing string assembly 150. For example the assembly 150 is temporarily secured to the support tower 140 at different elevations along the height of the support tower 140 by any suitable securing members, e.g. movable clamps, rope, chain, etc.

(56) Generally the cart 130 is configured to move over the rails 6, 7, 8, whilst retaining the assembly 150, and be stationed in various locations, including a deployment location above the marine riser 9 in the firing line 2, where the assembly 150 is deployed into the marine riser 9.

(57) The vessel is also equipped with at least one landing string assembly umbilical winch 160, e.g. arranged or configured to be arranged adjacent the deployment location, e.g. along a side of the rig floor 4, e.g. also adjacent a testing location for the cart which is somewhat remote from the deployment location so as to keep the firing line clear allowing for other activities to be done in the firing line whilst the assembly 150 retained by the cart 130 is subjected to one or more tests.

(58) The winch 160 has a reel onto which an umbilical 161 is wound, that is configured to be connected to the assembly 150. Testing is for example done with the umbilical 161 connected to the assembly 150 whilst the in-riser landing string assembly 150 is retained by the support tower 140 and whilst the cart 130 is offset from the deployment location, for example the testing location depicted in FIG. 8 which corresponds with the location of the cart during the descent of the landing string into the riser as also depicted in FIG. 8.

(59) As preferred, after testing at the remote, or somewhat remote, testing location, the cart 130 and assembly 140 thereon is moved into the deployment location and during this displacement the umbilical 161 remains connected to the in-riser landing string assembly 150.

(60) FIG. 5 illustrates that for the deployment of the in-riser landing string assembly 150 into the marine riser 9, multiple landing string tubing joints 165, e.g. as pre-assembled multi-joint landing string tubing stands, are connected to the assembly 150 and stepwise added to the landing string and so the in-riser landing string assembly is lowered down in the marine riser 9 until the subsea equipment, e.g. comprising a BOP stack, is reached where the assembly, or a part thereof, is accommodated.

(61) As shown in FIG. 8 it is proposed that the deployment of the landing string into the marine riser 9 is in majority done with the cart 130 and support tower 140 having been relocated or moved into an offset location, e.g. into the testing location, remote, from the deployment location. Herein the umbilical 161 passes from umbilical winch 160 over an umbilical guide 163 that is mounted on the support tower 140 on the cart. Also depicted is the use of auxiliary umbilical guide 164 for the umbilical being arranged at the deployment location, e.g. above a well center of a rig floor. Here, as preferred, the guide 164 is held by a motion arm 75.

(62) It is envisaged that the support tower 140 has a tower height of at least 12 meters, e.g. of between 20 and 36 meters, here in FIGS. 2-9 of 24 meters (80 ft.).

(63) In FIGS. 2-9 the support tower 140 has two interconnected tower parts 141, 142 each having a length of 12 meters, (40 ft.). in FIG. 9 the tower parts 141, 142 are shown in side view and from above. Each tower part 141, 142 is configured for shipment and/or handling and/or storage as a 40 ft. ISO intermodal freight container.

(64) As can be seen in e.g. FIGS. 4, 9 the structural frame of the tower parts 141, 142 is embodied with a recessed receiving space 145 for the in-riser landing string assembly 150. This recess 145 that is open in a lateral side, e.g. in a front side, of the structural frame when in upright orientation or relative to the main longitudinal axis thereof. This lateral opening of the recess 145 may be used for the introduction and/or removal of one or more components of the landing string assembly 150, preferably the entire landing string assembly 150, and/or of a landing string tubing joint 165 and/or of a stand of multiple landing string tubing joints, in lateral direction from the outside into the recessed receiving space and vice versa.

(65) As will be appreciated, e.g. looking at FIGS. 5 and 7, the in-riser landing string assembly 150 is transferred by means of the in-riser landing string assembly cart 130, e.g. skidded, into the deployment location above the marine riser 9 and then one or more landing string tubing joints or stands 165 are connected to a top end of the in-riser landing string assembly 150 and the in-riser landing string assembly is then suspended from these one or more landing string tubing joints or stands, e.g. using the drawworks 50, where after the cart 130 with support tower 140 is moved away and placed at a remote location, e.g. back to a testing location, as shown in FIG. 8.

(66) With the cart 130 and support tower 140 moved to a location remote from the deployment location, the in-riser landing string assembly is lowered until the landing string tubing passes through a slip device 11, 12 and this slip device is then made to engage on the landing string tubing, followed by stepwise lengthening of the landing string by adding landing string tubing joints or stands, e.g. until the assembly is lowered sufficiently, e.g. is landed onto a tubing hanger of the subsea equipment.

(67) FIG. 9 depicts that the tower parts 141, 142 include platforms 146 and corresponding railings at different heights so as to facilitate access of personnel to the assembly 150 retained by the support tower.

(68) FIG. 9 depicts that the tower parts 141, 142 include at axial ends thereof ISO container corner fitting members 147 that allow for handling of the parts as freight containers and may also be of use for interconnecting the parts 141, 142 to one another and/or to the cart base 131.

(69) FIG. 9 illustrates that the guide 163 can be stored within the contour of a tower part 142, e.g. for reduced space during storage and/or shipping. Here the guide 163 is pivotally connected to the tower part 142.

(70) With reference to FIGS. 10a-d now another embodiment of an in-riser landing string assembly cart 230 will be discussed.

(71) As the cart 130 the cart 230 is comprised of a cart base 231, which may be of the same structure as discussed with reference to cart base 131, and a support tower 240.

(72) FIG. 10a shows the cart base 231 on the rails 6 over the well center 5. There above, disconnected from the cart base 231 the tower 240 is depicted.

(73) It will be appreciated that the depicted tower 240 is even taller than the tower 140, namely an extra 20 ft. or 6 meters for the third part and, as preferred, some extra height due to intermediate tower parts between the containerized parts 241, 242, 243, so a total height of more than 30 meters (100 ft.).

(74) The tower 240 is composed here mainly of three tower parts 241, 242, and 243. Herein the parts 242 and 243 are 12 meters, 40 ft., long, and the part 241, here the lower part, is 6 meters, 20 ft. long.

(75) Each of the parts 141, 142, 143 is provided with platforms 244, e.g. every 3 meters (10 ft.), railings, and with ladders 245 to gain access to the tower 240.

(76) FIGS. 10a-d depict that the tower parts 241, 242, 243 include at axial ends thereof ISO container corner fitting members 247 that allow for handling of the parts as freight containers and may also be of use for interconnecting the parts 241, 242, 243 to one another and/or to the cart base 231. Here, intermediate short length tower parts 248 are placed between the parts 241, 242 and between parts 242, 243 respectively.

(77) The FIGS. 10a-d also illustrate that the tower 240 is embodied to retain two in-riser landing string assemblies simultaneously in side by side arrangement. This is foreseen to deal with operations that require very long assemblies to exceed a practical maximum height of the cart and support tower. For instance assemblies having a length of more than 30 meters.

(78) In FIGS. 10a-d two assemblies 151 and 152 are schematically shown, with assembly 151 being a lower assembly 151 and assembly 152 being an upper assembly that is configured to be secured on top of the lower assembly 151 during the deployment process.

(79) In FIGS. 11a-11c and 12a-c the tower parts 241, 242, (with 243 being the same as 242) are shown in more detail. Here it is also illustrated that the tower part 241 may be provided with a stub 250, 251 or the like to receive and support the lower end of the respective assembly 151, 152.

(80) The FIGS. 11a-c, 12a-c, also illustrate that the structural frame of the tower parts 241, 242, 243 is embodied with a recessed receiving space 252 for the in-riser landing string assemblies 151, 152. This recess 252 that is open in a lateral side, e.g. in a front side, of the structural frame of the entire tower 240 when in upright orientation or relative to the main longitudinal axis thereof. This allows e.g. to skid the cart 230 with tower 240 away from the deployment location once an assembly 151 has become suspended and lifted from its stub.

(81) FIG. 13 schematically depicts the combined assemblies 151, 152 joined at A during the deployment procedure onboard the vessel after the landing string has been lowered to the level of the equipment on well head 200 on seabed 201. As can be seen, in this example, the lower assembly 151 comprises components like the SSTT component, latch mechanism component, shear sub component, and retainer valve component, as well as (at the lower end) the THRT component. As discussed the composition of the assembly may be varied according to the specific requirements. Here the upper assembly in particular comprises an N2 injection component, e.g. in view of gas lift functionality. The combined assembly 151, 152 is very tall and therefore the handling as two (or more) pre-assembled assemblies by means of one or more carts 130, 230, is advantageous.

(82) FIG. 14 schematically depicts this combined assemblies 151, 152 with the lower end of the marine riser 9 and with the subsea equipment on the well head 200. Here a BOP stack 205 is provided as well as a further subsea tool 206 stacked thereon. It can be seen that shear rams of the BOP are at the level of the shear sub. It is also shown that the THRT has been landed on the TH or tubing hanger.

(83) FIG. 15 schematically illustrates that the support tower 240 with the one or more assemblies 151, 152 retained thereby, has served for the purpose of storage of said one or more assemblies 151, 152 in horizontal orientation, e.g. somewhere on deck or in a hold, e.g. riser storage hold, of the vessel.

(84) Once use of the assemblies 151, 152 is envisaged, the entire unit of tower 240 and assemblies 151, 152 is in this example placed on a catwalk machine 220 of the vessel, e.g. the catwalk machine commonly used for handling riser and/or tubulars. The catwalk machine 220 is then advanced towards the mast 10, e.g. as shown so that the front (or later upper) end of the support tower 240 is underneath the drawworks 50, here trolley 20. Then this end is secured to the drawworks, here to the trolley 20 for the procedure of upending this entire unit of support tower 240 and one or more assemblies 151, 152.

(85) FIG. 16 schematically illustrates that the support tower 240 with the one or more assemblies 151, 152 retained thereby is upended as a unit using the drawworks 50, here with the catwalk machine 220, e.g. the skate 221 thereof support the lower end of the unit during the upending procedure.

(86) The FIG. 17 illustrates that the unit of support tower 240 and retained assemblies 151, 152 has been completely brought into vertical orientation using the drawworks. Also the cart base 231 has been brought into position below the suspended unit in advance of the mating of the unit and the cart base 231.

(87) FIG. 18 depicts that the unit has been lowered or otherwise arranged on the cart body 231 and properly secured thereto, e.g. using pins, bolts, or other securing or fastening members. Now the tower 240 with assemblies 151, 152 can be skidded away from this location, that corresponds to the deployment location, e.g. to a remote testing location, e.g. some 5 to 15 meters over rails 6.

(88) FIG. 19 illustrates the cart 230 with assemblies 151, 152 being located at a testing location, remote from the deployment location in the firing line 2. Also shown are two umbilical winches 160a, b, each with an umbilical 161a, b. Herein umbilical 161a is connected to assembly 152 and umbilical 161b to assembly 151.

(89) As shown the tower 240 has guides 263, 264 for each of the umbilicals.

(90) It will be appreciate that testing can now be done, with umbilicals 161a, b connected to the respective assembly 151, 152 whilst the firing line 2 is clear and functional for other activities, e.g. lower production tubing 275 into the well via the marine riser 2 using the drawworks 50. This is depicted in FIG. 19 where the stage has been reached that the production tubing hanger TH is held at the level of the rig floor 4, e.g. by a support device 270 placed between the slip devices 11, 12.

(91) The FIG. 19 depicts that the process of lowering the production tubing 275, and attaching one or more control lines to the exterior thereof, has been done using a lower frame section 280 of a riser tension frame 290 as discussed in detail in co-pending NL 2018018 which is incorporated herein by reference.

(92) FIG. 20 illustrates the transfer of the cart 230 and the assemblies 151, 152 to the deployment location over the well center 5, here so that lower assembly 151 is aligned with the firing line 2 and the drawworks 50. This shift from the testing location to the deployment location is done with the one or more umbilicals 161a, b remaining connected. The lower frame section 280 has been shifted, also using a skid arrangement over rails 6 to the other side.

(93) FIG. 21 depicts that the lower assembly 151 has been secured to the drawworks of the rig, e.g. using an elevator 31 of the top drive 30 or otherwise and lifted from its stub 251. Due to the opened recess in the tower 240 the cart could then be shifted back to the testing location, so that the assembly 151 is moved in lateral direction out of the tower recess. The THRT component can now be brought into proper engagement with the TH production tubing hanger and some testing, if desired can be done whilst both the TH and THRT are in proximity of the rig floor 4.

(94) FIG. 22 depicts the lowering of the assembly 151, here connected to the production tubing 275 via the interconnected TH and THRT, into the marine riser 9. The cart 230 is still in a remote testing location. Once the assembly 151 has been lowered sufficiently, a top portion thereof is held in suitable manner, e.g. using device 270, in proximity of the level of the rig floor, such that the cart 230 can be brought back into deployment location for the removal of the upper assembly 152 from the cart 240 using the drawworks 50. This is done in similar manner as assembly 152. Once suspended from the drawworks 50 the cart 240 is moved away, and the assembly 152 lowered onto the lower assembly 151 and secured to one another.

(95) FIG. 23 illustrates that the combination of interconnected assemblies 151, 152 has been lowered into the riser 9 with the umbilicals 161a, b being guided on the tower top by guides 263, 264 and by one or more auxiliary guides 295 held by a motion arm 75.

(96) FIG. 23 also illustrates the riser tension frame 290 which is disclosed in detail in co-pending NL 2018018 which is incorporated herein by reference.

(97) The riser tension frame 290 is adapted to be suspended from the drawworks 50, allowing to operate the frame in heave compensation mode by means of heave motion functionality of the drawworks as preferred.

(98) The frame 290 is provided with a riser attachment device adapted to attach the riser to the frame. This is depicted in FIG. 24.

(99) Here the frame 290 is suspended from the trolley 20.

(100) The frame 290 comprises a coiled tubing injector 300 as well as a wireline lubricator 400. As preferred each of the injector 300 and lubricator 400 is received by and individually movable within the suspended riser tension frame 290 between a parking position remote from the firing line 2 and an operative position aligned with said firing line 2 allowing to use a selected one of said coiled tubing injector and said wireline lubricator for performing a coiled tubing operation or a wireline operation respectively when aligned with the firing line. As preferred the riser tension frame 290 provides a lateral firing line access passage having a height of at least 40 ft. and a width of at least 1 ft. allowing to transfer an elongated wellbore tool or a wellbore tubular in vertical orientation thereof by means of the motion arm assembly 70, 71, 72, 80, 81, 82 in a substantially lateral motion between and a remote position outside of the riser tension frame and an operative position within the riser tension frame and aligned with the firing line 2.

(101) FIG. 24 depicts the riser 9 being suspended from riser tension frame 290 that is in turn suspended from the drawworks supported trolley 20. In use the frame 290 moves up and down in heave compensation mode as depicted here by motion of the umbilicals 161a, b. The tower 240 is arranged adjacent the tension frame 290 and serves to guide the umbilicals.