Patent Grant
11053753
The present invention relates to the field of offshore wellbore activities, e.g. drilling a wellbore, completion of a wellbore, wellbore intervention or servicing, and/or other activities that relate to a subsea wellbore.
In WO2014/182160 an offshore vessel with a wellbore activities installation is disclosed which comprises:
In the offshore wellbore activities field operations are performed that involve the use of coiled tubing equipment including a coiled tubing injector and/or wireline equipment including a wireline lubricator. Also operations are performed that involve the use of a so-called riser tension frame, sometimes with one of said coiled tubing injector or wireline lubricator installed in the tension frame. Herein the frame is adapted to attach to the top end of a riser in the firing line. For example a riser tension frame is suspended from a heave motion compensated hoisting device so as to keep the riser tensioned while the offshore vessel is subjected to heave motion. This can e.g. be done with a fixed length tension frame. Other know riser tension frames have an integrated heave motion compensator assembly, e.g. the structure of the frame including heave motion cylinders as part of the structure of the tension frame, e.g. vertical structural legs of the frame including such cylinders. Sometimes this integrated motion compensator assembly is normally locked, so non-operative, making the riser tension frame act like a fixed length frame. The integrated motion compensator assembly is then merely provided as a back-up for the heave motion compensated hoisting device from which the tension frame is suspended in heave motion compensating mode.
It is known in the field to install in a riser tension frame one or more of a coiled tubing injector, a wireline lubricator, and one or more pressure control devices associated with said coiled tubing injector and/or said wireline lubricator. Examples of such known wellbore activities systems are described in WO2015/051156, U.S. Pat. No. 8,162,062.
Another operation common in this field is running of a tubulars string, e.g. in well completion wherein a production tubulars string is run into a subsea wellbore, wherein one or more control lines are fitted to the outside of the tubulars string. Oil and/or gas produced by the well are conveyed to the wellhead by this production tubulars string. The completion of a well using production tubing, but also some other operations running some kind of tubular string, requires the installation of control lines for electrically, hydraulically and/or optically linking various downhole devices to the wellhead and/or the surface. Control lines may be used to receive data from downhole instruments, e.g. to monitor, regulate and stimulate the flow of the fluids through the production tubing string, e.g. by selectively operating, from the surface, downhole devices such as valves, switches, sensors, relays or other devices. Control and signal lines may carry electric signals, electrical power, hydraulic signals and/or power, optic signals, pneumatic signals and/or power, etc. It is common practice to use clamps to secure these lines at intervals, e.g. at the location of threaded connectors connecting one tubular to another, to the tubulars string. Commonly this is done manually by an operator standing at a level below a slip device from which the tubulars string is suspended in the firing line.
The present invention aims to provide measures that form an improvement over existing offshore subsea wellbore activities systems, e.g. with respect to versatility, efficiency, reliability, use of deck and/or other storage space for equipment, etc.
According to a first aspect thereof the invention provides an offshore subsea wellbore activities system comprising:
This system is very versatile and efficient as the wellbore activities device allows for switching between coiled tubing operation and wireline operation, which is frequently desired in the field. Moreover the system allows to use the motion arm assembly in the process of handling for example an elongated wellbore tool that has to be fitted at the leading end of the coiled tubing that is to be deployed. Such wellbore tools are often called bottomhole assembly or BHA, and may include one or more of a downhole motor, sensitive electronics, perforator equipment, packers, valves, etc. The inventive system allows to reliably handle such a relatively expensive and fragile tool by means of the motion arm assembly in order to bring the tool in the firing line. In embodiments the motion arm assembly can be used to stab the tool into the riser, e.g. at least in part, and/or the tool is then suspended from a winch cable that extends vertically in the firing line for vertical handling of the tool in the firing line.
The system of the first aspect of the invention may also include one or more of the features discussed in the subclaims and/or in the description of the figures and/or discussed with reference to another aspect of the invention.
For example the system further comprises:
For example the vertical riser load bearing structure is formed by exactly three vertical riser load bearing struts connecting said lower frame section to said upper frame section in a triangular arrangement, including one rear strut arranged at a rear side of the tension frame facing the tower and two front struts at a front side of the tension frame.
For example the lower frame section is releasably secured to said vertical riser load bearing structure, e.g. to said struts, and the lower frame section comprises a platform adapted to stand on a rig floor in an operative position over the well center.
For example the lower frame section supports, above a platform thereof, at least one of said coiled tubing injector, said wireline lubricator, and said one or more pressure control devices associated with said coiled tubing injector and/or said wireline lubricator.
For example the lower frame section is releasably secured to the vertical riser load bearing structure, and the lower frame section comprises a platform provided with downward projecting support legs protruding beneath the platform and adapted to stand on a rig floor in an operative position over the well center, wherein said platform is at an elevated position above the rig floor.
For example the system further comprises a slip device adapted to support a tubulars string suspended from said slip device, wherein the lower frame section is adapted to receive and retain said slip device.
For example the lower frame section is releasably connected to the vertical riser load bearing structure of the tension frame.
For example the lower frame section comprises a platform wherein centrally a riser top connector is arranged that is to be aligned with the firing line.
For example the lower frame section, e.g. the platform thereof, is provided with a CT storage stand to store thereon a coiled tubing (CT) pressure control device and with a WL storage stand to store thereon a wireline (WL) pressure control device, e.g. wherein said CT storage stand and said WL storage stand are arranged on diametrically opposed location relative to a central riser top connector.
For example the lower frame section has a platform whereon horizontal rails are provided.
For example the lower frame section, e.g. a platform thereof, is provided with CT pressure control device carrier that travels over rails and is adapted to carry and displace the CT pressure control device from a CT storage stand to the firing line for connection to the riser top connector and vice versa.
For example the lower frame section, e.g. a platform thereof, is provided with WL pressure control device carrier that travels over rails and is adapted to carry and displace the WL pressure control device from the WL storage stand to the firing line for connection to a riser top connector and vice versa.
For example vertical riser load bearing struts, e.g. exactly three in a triangular arrangement, connect the lower frame section to the upper frame section.
For example connecting struts are each connected at an upper end thereof via a releasable connection, e.g. via a removable connector pin, to the upper frame section.
For example connecting struts are each connected at a lower end thereof via a releasable connection, e.g. via a removable connector pin, to said lower frame section.
For example the upper and/or lower frame section each comprises sockets that are each adapted to receive therein a spigot end of a strut, wherein for each releasable connection a transverse connector pin is provided that extends through aligned apertures in the socket and the spigot end of the strut.
For example the lower frame section is releasably secured to the vertical load bearing structure, e.g. said struts, and the lower frame section comprises a platform adapted to stand on a rig floor in an operative position over the well center, possibly provided with downward projecting support legs protruding beneath the platform so that said platform stands at an elevated position above the rig floor.
For example the lower frame section is provided with a mobile arm structure having one or more mobile arms, e.g. pivotally connected to the lower frame section, and the mobile arm structure is provided with one or more rail engagement members, e.g. rollers sets, adapted to engage on one or more of said vertical rails, e.g. on trolley rails.
For example the system comprises:
For example the system comprises:
For example the system comprises:
The first aspect of the invention also relates to an offshore subsea wellbore activities system comprising:
It will be appreciated that here the versatility of the system is very great as the motion arm assembly, when fitted with the tubular gripper member, can also be employed to handle tubulars stored in the storage rack. For example, possibly in combination with one or more additional motion arm assemblies, e.g. on the same vertical rail, the motion arm assembly can be operated as a piperacker during a drilling operation wherein no use is made of the riser tension frame.
In embodiments the tubular gripper member is employed to handle a wellbore tool to be transferred between the firing line within the riser tension frame and the outside of said frame, e.g. said wellbore tool being stored in the storage rack. The wellbore tool may have a section, e.g. releasably insertable between components or modules of the wellbore tool, dedicated to be gripped by the tubular gripper member.
The first aspect of the invention also relates to an offshore subsea wellbore activities system comprising:
Here the riser tension frame is provided with exactly three vertical riser load bearing struts connecting said lower frame section to said upper frame section in a triangular arrangement, seen in horizontal cross-section, including one rear strut arranged at a rear side of the tension frame facing the tower and two front struts at a front side of the tension frame. This arrangement provides on the one hand a very stable structure of the tension frame, e.g. compared to known frames having exactly two struts which results in a more or less planar framework, e.g. that is less effective in an embodiment wherein the frame has to carry both the coiled tubing injector and the wireline lubricator as well as one or more pressure control devices associated with the coiled tubing injector and/or the wireline lubricator (e.g. two complete BOP ram stacks). Compared to a four struts design of the frame, the provision of just three, with one at the rear and two at the front, for enhanced integration of the described lateral firing line access passage as well as optimization of stresses on the struts and weight of the complete tension frame. For example using struts that are releasable from both the upper and lower frame section, the vertical riser load will more effectively be distributed over three legs than over four legs.
The first aspect of the invention also relates to a method for performing a wellbore activity wherein use is made of the system, e.g. for performing an offshore wireline operation wherein use is made of a system to move a wellbore tool into the firing line, which tool is to be connected to the wireline. Similarly the method may include a coiled tubing operation and the motion arm of the system is used to move a coiled tubing tool into the firing line. For example a tool is brought from a position outside the riser tension frame to a position within the tension frame and aligned with the firing line as well as above the wireline lubricator by means of the motion arm assembly.
A second aspect of the invention relates to an offshore subsea wellbore activities system comprising:
This system of the second aspect of the invention allows for the multi-functionality of the lower frame section of the riser tension frame, at least including this lower frame section playing its role as structural load bearing part of the tension frame and including the lower frame section being detached from the remainder of the riser tension frame and standing on the rig floor in operative position over the well center. As at least one of one of the coiled tubing injector, wireline lubricator, and one or more pressure control devices associated with said coiled tubing injector and/or said wireline lubricator are supported on this lower frame section above the platform, this equipment can readily be used when the lower frame section stand, detached from the rest of the frame, on the rig floor. For example the lower frame section than stands on skid rails provided on the rig floor. For example the lower frame section then is used for coiled tubing and/or wireline operations. In another embodiment it is envisaged that a slip device is placed on, or even integrated with, the lower frame section, as to allow the lower section to keep a tubulars string suspended from the slip device in the firing line.
The second aspect of the invention also relates to an offshore subsea wellbore activities system comprising:
The second aspect of the invention also relates to an offshore subsea wellbore activities system comprising:
The provision of a mobile arm structure allows to use this arm structure as part of the guidance of the tension frame relative to the tower when the frame is operated in heave compensating mode. In stored position of the lower frame section or of the entire tension frame the mobile arm structure can be brought into a retracted or collapsed mode wherein the arm structure takes up little space.
In a preferred embodiment, the one or more vertical rails on which the mobile arm structure engages extend so low that even when the lower frame structure is placed on the rig floor the arm structure can be brought into proper engagement with said one or more vertical rails. This e.g. allows the arm structure to act as a stabilizer for the lower frame structure that is standing on the rig floor, e.g. absorbing—at least in part—forces in the horizontal plane acting on the lower frame section in the course of operations being performed. Also the arm structure may act to properly position the lower frame section relative to the firing line when standing on the rig floor, e.g. to achieve alignment with the firing line and thus with a top drive device that may travel up and down above the lower section.
The second aspect of the invention also relates to a riser tension frame for use in offshore subsea wellbore activities aboard an offshore vessel having a hull subjected to heave motion, wherein the riser tension frame comprises:
The second aspect of the invention also relates to an offshore subsea wellbore activities system comprising:
A third aspect of the invention relates to a riser tension frame for use in offshore subsea wellbore activities aboard an offshore vessel having a hull subjected to heave motion, wherein the riser tension frame comprises:
The third aspect of the invention also relates to a method for onboard assembly of a riser tension frame for use in offshore subsea wellbore activities aboard an offshore vessel having a hull subjected to heave motion, wherein the riser tension frame comprises:
The riser tension frame of the third aspect of the invention allows for assembly and disassembly, e.g. in view of storage when not in use. Also one can envisage lengthening of shortening of the frame depending on the planned operations to be performed by exchanging one length of struts for another length of struts. The struts, when disassembled, can e.g. be stored horizontally. As explained herein, in embodiments, the lower frame section is also embodied for use when detached from the tension frame, e.g. standing on the rig floor over the well center or even supported on heave motion compensator cylinders that extend underneath the lower frame section (e.g. between the lower frame section and the rig floor). When the lower section is used as stand-alone component it is desirable to allow for storage of the remainder of the tension frame in disassembled state so as to reduce storage spaced requirements.
In an embodiment it is envisaged that the struts, when disassembled, as stored horizontally belowdecks in a storage hold within the hull, e.g. within a hold that is also used for horizontal storage of riser sections or stands.
The riser tension frame is preferably embodied with the struts being fixed length monolithic steel struts, e.g. of rectangular cross section. One or more of the struts may be, possibly permanently, fitted with walkways and/or stairs to allow personnel to have access to, for example, one or more of a coiled tubing injector, wireline lubricator, wellbore tool position within the frame (e.g. in the firing line), or other components, etc. in the tension frame.
A fourth aspect of the invention relates to an offshore subsea wellbore activities system comprising:
In an embodiment the frame section is provided with a riser attachment device adapted to attach a riser to said frame section so as to extend in a firing line.
In an embodiment the frame section comprises a platform wherein centrally a riser top connector is arranged that is to be aligned with the firing line.
In an embodiment the frame section is provided with a coiled tubing injector and associated pressure control device and/or with a wireline lubricator and associated pressure control device.
In an embodiment the frame section placed on top of a group of heave motion compensation cylinders is provided with a mobile arm structure having one or more mobile arms, e.g. pivotally connected to the frame section, wherein said mobile arm structure is provided with one or more rail engagement members, e.g. rollers sets, adapted to engage on one or more of said vertical rails on the tower.
In an embodiment the frame section placed on top of a group of heave motion compensation cylinders comprises a platform, which platform is provided with a CT storage stand to store thereon a coiled tubing (CT) pressure control device and with a WL storage stand to store therein a wireline (WL) pressure control device, wherein said CT storage stand and said WL storage stand are arranged on diametrically opposed locations relative to a central riser top connector, and wherein the platform is provided with CT pressure control device carrier that travels over rails and is adapted to carry and displace the CT pressure control device from the CT storage stand to the firing line for connection to the riser top connector and vice versa, and wherein the platform is provided with WL pressure control device carrier that travels over rails and is adapted to carry and displace the WL pressure control device from the WL storage stand to the firing line for connection to the riser top connector and vice versa.
In an embodiment a coiled tubing injector is fitted on top of the coiled tubing pressure control device as a unit, wherein the carrier is adapted to move said unit between the parked position and the operative position in the firing line.
In another embodiment the frame section placed on top of a group of heave motion compensation cylinders is provided with a separate carrier for a coiled tubing injector, allowing to move the coiled tubing injector separate from an associated pressure control device.
In another embodiment the frame section placed on top of a group of heave motion compensation cylinders is provided with a separate carrier for a wireline lubricator, allowing to move the wireline lubricator separate from an associated pressure control device.
In an embodiment an intermediate horizontal frame member is fitted in the structure of the frame section at a level above the one or more pressure control devices, with one or more carriers being provided on said intermediate horizontal frame member to perform transfer of a coiled tubing injector and/or of a wireline lubricator, each between a respective parked position and a firing line position. For example such an additional carrier may include a lifting mechanism adapted to lift and lower the carried injector and/or lubricator relative to the associated pressure control device in view of making and breaking the connection.
In an embodiment the frame section comprises a platform and wherein a surface flow tree that may be arranged in a top region of a riser is mounted below the platform.
The fourth aspect of the invention also relates to a method for performing wellbore activities wherein use is made of the system comprising a frame section that is placed on top of a group of heave motion compensation cylinders, e.g. on four of such cylinders, configured to allow the frame section to perform a heave compensating motion in an associated range of travel along the tower.
It will be appreciated that any aspect discussed herein, and (optional) detailed features thereof, can also be combined with one or more of the other aspects of the invention.
It will be appreciated that the present invention also relates to a riser tension frame as discussed herein for use in wellbore activities on a heave motion subjected vessel and to such use thereof.
The present invention also relates to methods wherein use is made of a system and/or riser tension frame and/or lower riser frame section and/or frame section supported on top of a group of heave motion compensation cylinders as described herein.
The various aspects of the invention will now be described in more detail with reference to non-limiting embodiments, some of them shown in the drawings.
In the drawings:
It is envisaged that the depicted an offshore vessel is adapted for performing offshore drilling and/or other wellbore related activities, e.g. well completion, well intervention, etc.
As shown in
The mast 1 is at the side of the well center 5 provided with two parallel vertical trolley rails 7, 8.
A trolley 20 is guided along the trolley rails 7,8.
A top drive device 30 is attached to the trolley 20.
The top drive device 30 comprises in this example four electric top drive motors 31 which commonly drive, via gearbox or transmission in housing 32, a rotary stem or quill 33. As known in the art the quill 33 is connectable, e.g. via a threaded connection, e.g. via a saver sub, to the top end of a tubular aligned with the firing line. Thereby the top drive device 30 is able to impart rotary motion and drive torque to a tubulars string.
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. The travelling block 52 here is fitted to the frame of the trolley 20. 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.
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 7,8.
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.
As is preferred the assemblies 70, 71, 72, 80, 81, 82 have an identical structure. For example with reference to
The assembly 71 further comprises an extensible and retractable motion arm 75, here a telescopic arm with a first arm section 75a connected to the base 74, and one or more, here two, telescopic second and third arm sections 75b, 75c. 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 3 so that the arm can handle drilling tubulars and/or well center equipment, or other tooling that needs to be presented or held in the firing line. As is preferred the arm 75, here the first arm section 75a, 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.
The assembly 70 further comprises a motion arm assembly vertical drive, e.g. with one or more motors 78 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 78 is sufficiently strong to do so while the motion arm assembly carries a load in the firing line 3 of at least 1000 kg, preferably at least 5000 kg.
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.
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.
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, etc.
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 5 in the firing line 3. 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.
In an embodiment it is preferred that the one or more motion arm assemblies 70, 71, 72, 80, 81, 82, e.g. at least one, is provided with a motion arm assembly vertical drive that forms part of a heave motion synchronization system, e.g. an electronic control unit that controls the vertical drive motor 78. Herein this synchronization system is adapted to bring a motion arm assembly and any object carried thereby, e.g. a wellbore tool or a tubular retrieved from a storage rack, into a vertical motion that is synchronous with the heave compensation motion of a still to be described riser tension frame or lower frame section thereof. This synchronization capability of the motion arm assembly with the heave motion for example allows the transfer of such wellbore tool or tubular between a position outside of the riser tension frame and a position within the riser tension frame and aligned with the firing line.
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 heave motion compensation motions relative to the tower 10. The riser tension frame can be equipped with a boarding station, e.g. with a safety door or other barrier, governing the transfer between the man-riding cage or basket and the riser tension frame.
The drawings show, as part of a wellbore activities device, a riser tension frame 200 that is to be suspended along the front side of the mast 10 by means of the hoisting device 50 and the trolley 20 in a manner that allows, as is known for riser tension frames, to perform a heave compensation of the frame 200. As preferred and depicted the frame 200 is a fixed length frame, so lacking internal heave compensation cylinders. For example the winch or winches of the hoisting device 50 are of the active heave compensation type and/or one or more heave compensation devices act on the cable from which the travelling block 51 is suspended. In yet another design a heave compensator device could be arranged between the fixed length frame and the trolley.
In a non-depicted embodiment the frame 200 is not suspended from the trolley 20 but from the top drive device 30, e.g. from bails connected to a part of the top drive device 30. The latter design is not preferred due to the need to have the top drive device 30 in place when operating the riser tension frame 200 and the strains placed on the top drive device 30 requiring a heavy design thereof.
In general the riser tension frame 200 comprises:
The wellbore activities device further comprises:
As depicted here each of the coiled tubing injector 300 and the wireline lubricator 400 is received by and individually movable within the riser tension frame 200 between a parking position remote from the firing line 3 and an operative position aligned with the firing line 3 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 explained in the introduction many operations involving coiled tubing and/or wireline require the use of long and slender wellbore tools, e.g. bottomhole assemblies to be fitted at the leading end of the coiled tubing string or wireline. Also such tools can be arranged at intermediate positions in the string in some cases.
As explained, according to some aspects of the invention, it is proposed to perform the transfer of for example such expensive and rather fragile slender wellbore tools 150 by means of one or more of the motion arm assemblies, e.g. as here motion arm assembly 71. Even, as explained during heave motion compensation operation, such transfer might be performed if the motion arm assembly is suitably motorized or otherwise.
In order to allow for this use of the one or more motion arm assemblies it is envisaged that the wellbore activities device, here the tension frame 200 plus preferably the CT injector 400, WL lubricator 300, and associated pressure control devices 320, 420 and any other components installed in or on said frame 200, such as walkways, provides a lateral firing line access passage 280 (depicted with dashed line in
It is envisaged that, e.g. in a lower zone thereof, the passage 280 is dimensioned to allow for the transfer of objects having a greater cross-sectional dimension than a relatively slender wellbore tool or wellbore tubular. For example the passage 280 has a lower zone that is dimensioned to allow for access to the firing line 3 of a roughneck device held on the arm of a motion arm assembly, e.g. to assist in making or breaking of threaded connections, possibly with a tubular also being held in the firing line by an arm of a higher located arm assembly. Of course one can envisage that the passage 280 is wide over its entire height, e.g. 3 ft. or more, instead of being wide in a lower zone and narrow in an upper zone.
One can also envisage that a motion arm assembly on the tower 10 is used to handle one or more of the:
For example a motion arm assembly is used to transfer such a component into and/or out of the frame 200, possibly with said frame 200 then being arranged out of alignment with the firing line in order to facilitate access to the component by means of the motion arm assembly as such transfer does not necessitate proper alignment with the firing line.
As illustrated, e.g. in
The lower frame section 250 supports, above the platform 251, the coiled tubing injector 300, the wireline lubricator 400, and the associated pressure control devices 320,420.
The versatility of the removable lower frame section 250 is further depicted in
The versatility of the removable lower frame section 250 is further depicted in
As illustrated here, see e.g.,
The platform is provided with a CT storage stand 256 to store thereon a coiled tubing (CT) pressure control device 320 and with a WL storage stand 257 to store therein a wireline (WL) pressure control device 420. The CT storage stand 256 and WL storage stand 257 are arranged on diametrically opposed location relative to central riser top connector 255. In embodiments the stand 256 and/or stand 257 is provided with a connector, e.g. a HydraConn connector, similar to connector 255.
Also rails 258 are provided on said platform 251, here as preferred a pair of rails extending from left to right and along the front and the rear of the region where one can exchangeably fit the connector 255 or the slip device 6c.
The platform is provided with CT pressure control device carrier 260 that travels over said rails 258 and is adapted to carry and displace the CT pressure control device 320 from the CT storage stand 256 to the firing line 3 for connection to the riser top connector 255 and vice versa. Also the platform is provided with WL pressure control device carrier 265 that travels over rails 258 and is adapted to carry and displace the WL pressure control device 420 from the WL storage stand 257 to the firing line 3 for connection to the riser top connector 255 and vice versa.
It is depicted that the coiled tubing injector 300 is fitted on top of the coiled tubing pressure control device 320 and is moved by the carrier 260 as a unit between the parked position and the operative position in the firing line. In another embodiment a separate carrier is provided for the injector 300, allowing to move the injector separate from the associated pressure control device 320. The same may be done for the wireline lubricator 400 and its associated pressure control device 420. For example an intermediate horizontal frame member is fitted in the structure of the frame 200 at a level above the pressure control devices 320, 420, with one or more carriers being provided on said intermediate horizontal frame member to perform transfer of the injector 300 and/or lubricator 400 between a parked position and a firing line position. For example such an additional carrier may include a lifting mechanism adapted to lift and lower the carried injector 300 and/or lubricator 400 relative to the associated pressure control device 320, 420 in view of making and breaking the connection.
The carriers 260, 265 here each include a lifting mechanism, here including one or more hydraulic jacks 266, 267, allowing to controllably raise and lower the respective component or unit of components, e.g. to obtain release from the storage stand and to mate with the connector 255 and vice versa.
Concerning the structure of the tension frame 200 it is envisaged, in embodiments, that the vertical riser load bearing struts 230, 231, 232, connecting the lower frame section 250 to the upper frame section 210 are releasable at both ends. So struts 230, 231, 232 are each connected at an upper end thereof via a releasable connection, e.g. via a removable connector pin 235, 236, 237 to upper frame section 210. The struts 230, 231, 232 are each connected at a lower end thereof via a releasable connection, e.g. via a removable connector pin, 241, 242, 243 to lower frame section 250. As depicted here the upper and lower frame section 210, 250 each comprises sockets 250a,b,c that are each adapted to receive therein a lower spigot end of a strut. And for each releasable connection a transverse connector pin 235, 236, 237, 241, 242, 243 is provided that extends through aligned apertures in the socket and the spigot end of the strut.
It will be appreciated that such modular design of the tension frame allows for reduced storage space when disassembled.
It will be appreciated that onboard assembly of riser tension frame 200 is possible if the vessel is equipped with a proper crane, which is common for such vessels. For example one could proceed position the lower frame section 250 on deck within reach of a crane, then raise the vertical riser load bearing struts 230, 231, 232 by the crane and placed them vertically with their spigot ends in the sockets of the lower frame section 250 and then secure them therein by means of said transverse connector pins. Then, subsequently, the upper frame section 210 is placed on the vertically arranged struts 230, 231, 232 by means of the crane so that the top spigot ends of the struts are received in the corresponding sockets of the upper frame section 210 and then secured therein by means of transverse connector pins.
It will be appreciated that a removable pin type connection is proposed between the lower frame section 250 and the remainder of the riser tension frame 250, which may be done irrespective of the presence of struts or an alternative vertical load bearing construction. In an embodiment the pins are driven by an associated actuator, e.g. hydraulic jack, mounted on the lower frame section to facilitate the release and engagement of these connector pins.
It is illustrated that the lower frame section 250 is releasably secured to vertical load bearing structure, e.g. to struts 230,231,232, and that the lower frame section comprises a platform 251 adapted to stand on a rig floor 4 in an operative position over the well center, possibly provided with downward projecting support legs 252 protruding beneath the platform so that said platform stands at an elevated position above the rig floor.
The figures also depict that the lower frame section 250 is provided with a mobile arm structure 285 having one or more mobile arms 286, here pivotally connected about a horizontal pivot axis to the rear side of the lower frame section 250. The mobile arm structure is provided with one or more rail engagement members, here two rollers sets 287, 288, each adapted to engage on a respective vertical rails, here each on a respective vertical trolley rails 7, 8. The frame section 250 preferably comprises one or more actuators 289, e.g. hydraulic jacks, to perform the motion of the mobile arm structure 285.
As preferred the rail or rails onto which the arm structure 285 engages extends so low towards or even onto the level of the rig floor 4 that that when the lower frame structure stands on the rig floor the rail engagement members, here roller sets 287, 288, can be brought into engagement with the respective rail. This allows to use to arm structure as both a positioner for the frame section (to guarantee alignment with the firing line) and as a stabilizer, e.g. absorbing horizontal forces acting on the frame section 250 during various operations.
The depicted system also comprises a pair of parallel skid rails 15 provided on rig floor 4 and extending along opposed sides of the well center 5. It is envisaged that a skid pallet 16, see
As best illustrated in
As depicted there the frame of the trolley 20 is provided with a pair of mobile tensile links 21, 22, here outwardly pivotable, that depend from the trolley and are connected or connectable to the top frame section 210 of the riser tension frame 200. Here each of the tensile links 21, 22 has an eyelet at the lower end thereof and the tension frame top section has opposed hooks 211, 212 that can be mated with an eyelet of the link 21,22, here a left-hand and right-hand hook 211, 212.
As depicted the riser tension frame 200 and the trolley 20 have a spigot and socket connection arrangement 25, se
As depicted, in an embodiment, the trolley 20 has a vertical central rear frame member 26 on which the top drive device 30 is vertically guided, e.g. allowing to lower the top drive device 30 down along the member 26 when removing the top drive 30 from the trolley 20.
As depicted, in an embodiment, the rear frame member 26 of the trolley 20 lines up with the rear strut 232 of the frame 200 and interconnects therewith directly, e.g. via the mentioned connection 26 or another connection.
As depicted in
It is illustrated that the riser tension frame 200 has a vertical firing line access passage 202 all the way from the top section 210 to the lower frame section 250, in particular extending through the top section in the firing line 3. This allows for the use of the top drive 30, e.g. of the mud swivel commonly associated with the top drive 30, or of an independent mud swivel 38, in operations using the tension frame 200.
The top frame section 250 is provided with a mobile top sheave 252 that is displaceable between a firing line position where a cable or wire can be passed from the top sheave along the firing line and a retracted or parked position (see 252b in
| Number | Date | Country | Kind |
|---|---|---|---|
| 2018018 | Dec 2016 | NL | national |
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/NL2017/050838 | 12/14/2017 | WO | 00 |
| Publishing Document | Publishing Date | Country | Kind |
|---|---|---|---|
| WO2018/111103 | 6/21/2018 | WO | A |
| Number | Name | Date | Kind |
|---|---|---|---|
| 8162062 | Barone et al. | Apr 2012 | B1 |
| 9611706 | Pinckard | Apr 2017 | B2 |
| 20120318530 | Wollum | Dec 2012 | A1 |
| 20130213662 | Beck | Aug 2013 | A1 |
| 20140308105 | Soertveit et al. | Oct 2014 | A1 |
| 20150096761 | Roodenburg | Apr 2015 | A1 |
| Number | Date | Country |
|---|---|---|
| 2 418 684 | Apr 2006 | GB |
| WO 2014182160 | Nov 2014 | WO |
| WO 2015051156 | Apr 2015 | WO |
| WO-2015133895 | Sep 2015 | WO |
| Entry |
|---|
| International Search Report, issued in PCT/NL2017/050838, dated Jan. 19, 2018. |
| Written Opinion of the International Searching Authority, issued in PCT/NL2017/050838, dated Jan. 19, 2018. |
| Number | Date | Country | |
|---|---|---|---|
| 20200011141 A1 | Jan 2020 | US |
