US20090151955A1 - Big assembly with movable rig floor units - Google Patents
Big assembly with movable rig floor units Download PDFInfo
- Publication number
- US20090151955A1 US20090151955A1 US12/279,401 US27940107A US2009151955A1 US 20090151955 A1 US20090151955 A1 US 20090151955A1 US 27940107 A US27940107 A US 27940107A US 2009151955 A1 US2009151955 A1 US 2009151955A1
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- United States
- Prior art keywords
- rig
- rig floor
- transporter
- assembly
- receiving area
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B3/00—Rotary drilling
- E21B3/02—Surface drives for rotary drilling
- E21B3/04—Rotary tables
- E21B3/045—Rotary tables movably mounted on the drilling structure or platform
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B15/00—Supports for the drilling machine, e.g. derricks or masts
- E21B15/003—Supports for the drilling machine, e.g. derricks or masts adapted to be moved on their substructure, e.g. with skidding means; adapted to drill a plurality of wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B15/00—Supports for the drilling machine, e.g. derricks or masts
- E21B15/02—Supports for the drilling machine, e.g. derricks or masts specially adapted for underwater drilling
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
Definitions
- the present invention relates to a rig assembly for use in the oil and gas exploration and production industry.
- the present invention relates to a rig assembly with an improved rig floor, as well as to an improved rig floor, a transporter and a method of providing a rig floor of a rig assembly.
- a blow-out preventer is also provided as part of the riser string, and is either located at seabed level on the wellhead, or is located nearer to surface, if prevailing weather conditions permit. As is well known in the art, the BOP permits safe shut-down of the well in the event of an emergency situation arising.
- a vast array of equipment is required in order to bring a well into production, whether following conventional techniques, or alternatives such as that proposed in PCT/GB2005/002885.
- Much of the equipment utilised must be brought to a location adjacent a rig floor of the surface facility, for subsequent deployment, or is deployed from a level below the rig floor.
- this has been achieved utilising handling equipment including cranes, elevators and the like.
- dedicated equipment has been developed specifically for handling apparatus to be deployed from the rig, particularly large, heavy apparatus such as BOPs, which may weigh several hundred tonnes.
- handling apparatus Where dedicated equipment has been provided for handling apparatus to be deployed, this equipment has conventionally been very large, which presents a particular problem in the offshore environment, where space is severely restricted. Additionally, the handling equipment is suited only for a single use or purpose; is typically slow moving; and is not capable of being used to handle other types of apparatus.
- a rig assembly comprising:
- the transporter may also be for transporting a rig floor unit from the rig floor receiving area to the storage area, when it is desired to locate an alternative selected rig floor unit in the rig floor receiving area.
- the transporter may therefore serve for transporting rig floor units between the two areas.
- a rig floor of a rig assembly is generally defined as the work area in which a rig crew conducts operations.
- Providing a rig assembly with a plurality of movable rig floor units, a rig floor receiving area, and a transporter for transporting a selected rig floor unit from a storage area to the rig floor receiving area facilitates a rapid changeover at the rig floor area when different tasks or operations are to be performed, when compared with prior practice in the industry.
- Each rig floor unit may be adapted for performing a different task or operation or a step in a task or operation. Thus switching of equipment necessary to carry out the desired task, operation or step may be rapidly achieved simply by switching around the rig floor units. To facilitate this, each rig floor unit may be adapted to carry different equipment suited to the particular task, operation or step.
- the storage area may comprise a plurality of rig floor storage locations, each configured to receive a respective rig floor unit. Accordingly, each rig floor unit may be adapted to be located in a respective storage location in the storage area. The selected rig floor unit may be adapted to be transferred from its storage location on to the transporter, which may then transport the rig floor unit to the rig floor receiving area.
- the transporter may be movable along a path extending between the storage area and the rig floor receiving area, for transporting the rig floor units between the storage area and the rig floor receiving area.
- the transporter may therefore be movable to a position where it can access any one of the rig floor units, such that the selected rig floor unit may be transferred on to the transporter, and such that a rig floor unit returned from the rig floor receiving area to the storage area by the transporter may be transferred off the transporter.
- the rig floor units may each be configured to be releasably secured, locked or located relative to or within the transporter. This may permit safe transportation of the rig floor units between the storage area and the receiving area, as well as safe operation in use of the rig floor defined by the rig floor unit.
- One or both of the rig floor units and the transporter may comprise a locking assembly for securing the rig floor units relative to the transporter.
- the transporter may be configured to be releasably secured, locked or located relative to or within the rig floor receiving area. In this fashion, the transporter, carrying the selected rig floor, may be secured within the rig floor receiving area and may thereby locate the rig floor unit in the receiving area, to define the rig floor. It will therefore be understood that the transporter may remain within the receiving area during the time when the selected rig floor unit is in the receiving area.
- the transporter may be configured to be secured to a support structure provided in the rig floor receiving area.
- One or both of the transporter and the support structure may comprise a locking assembly for securing the transporter in the receiving area.
- the locking assembly may comprise at least one, and preferably a plurality of locking dogs, pins, latches or the like.
- the locking assembly may be hydraulically actuated, or in alternative embodiments, may be electro-mechanically or electrically actuated or a combination thereof.
- the rig floor units may each be configured to be releasably secured, locked or located relative to or within the rig floor receiving area. In this fashion, the transporter may be removed from the receiving area, if desired, following location of the rig floor unit within the rig floor receiving area.
- the rig floor units may be configured to be secured to a support structure provided in the rig floor receiving area.
- One or both of the rig floor units and the support structure may comprise a locking assembly for securing the rig floor units in the receiving area.
- the locking assembly may comprise at least one, and preferably a plurality of locking dogs, pins, latches or the like.
- the locking assembly may be hydraulically actuated, or in alternative embodiments, may be electro-mechanically or electrically actuated or a combination thereof.
- the rig assembly may comprise a transfer system for transferring the rig floor units between a storage location within the storage area and the transporter.
- the transfer system may comprise a translation device for translating the rig floor units between their storage locations and the transporter.
- the translation device may be adapted to transfer the rig floor units directly between their respective storage locations and the transporter.
- the transfer system may comprise a lift, elevator or the like for raising and/or lowering the rig floor units between a level of the storage locations and a level of the transporter.
- a rig floor unit may be translated on to the lift and the lift may then raise or lower the rig floor unit into a position where the unit may be received within the transporter.
- the transporter may be shaped to define a space in which the rig floor units are received, to facilitate transfer of the units from the lift into the transporter.
- the transporter may be shaped to straddle the rig floor units, and may comprise first and second sides spaced and connected by a connecting structure, with a space defined between the sides in which the rig floor units are received.
- the transporter may be height adjustable for raising and lowering to a level of the unit storage locations.
- the rig assembly may be modular and may therefore be adaptable for various different types of rig, according to the space available. Accordingly, the rig assembly may be configured as required to suit a particular rig.
- the rig assembly may comprise handling equipment which may be coupled to and movable with the transporter, or which may be independently movable relative to the transporter.
- the handling equipment may comprise a tubing handling device for picking up and/or supporting a length of tubing, and which may serve for transferring tubing on to the transporter. This may facilitate subsequent deployment of the tubing on to and/or through the rig floor defined by the selected rig floor unit.
- the tubing may be a length of casing, liner, riser, drill tubing, production tubing or any other tubing utilised in the industry.
- the handling device may comprise one or more electromagnetic supports for selectively picking up and/or supporting the tubing.
- the handling device may be adapted to incline the tubing to assist in transfer on to the rig floor, and may comprise a support for supporting an end of the tubing during transfer.
- the rig floor receiving area may be adapted to be provided on or in a deck of a surface facility on which the rig assembly is provided.
- the rig floor receiving area may be provided around or adjacent to a moonpool in the facility.
- the moonpool is the opening in the hull or structure of the surface facility through which equipment/apparatus passes.
- the transporter may be for transporting the selected rig floor unit to a location above the moonpool, for the deployment of equipment into the moonpool.
- the surface facility may be a vessel such as a drillship, FPSO or FSO, or a rig such as a semi-submersible, submersible or jack-up rig.
- the rig floor receiving area may be adapted to be provided on or in a frame or support which may extend overboard.
- the rig floor units may each comprise handling apparatus for handling equipment to be deployed from the rig floor.
- the rig floor units may be selected from a group comprising: a drill unit having a rotary drive for driving and rotating a string of tubing; a BOP unit for supporting a BOP; a coiled tubing injector unit for supporting a coiled tubing injector to be used for running coiled tubing; and a subsea shut-off device unit, for running a subsea shut-off device such as that disclosed in International Patent Application No. PCT/GB2005/002885.
- any desired rig floor unit may be provided.
- At least one of the rig floor units may be adapted for deploying equipment from the rig assembly.
- at least one of the rig floor units may comprise an aperture through which equipment may be deployed.
- At least one of the rig floor units may be adapted to selectively support a tubing string and may therefore serve for suspending at least part of the load of a tubing string from the rig.
- the rig assembly may comprise a support for supporting a load of a tubing string during changeover of rig floor units.
- the transporter may be configured to receive a plurality of selected rig floor units.
- the transporter may be configured to receive two units, for faster changeover.
- the transporter may be self-driven, and may therefore comprise a drive system for moving the transporter between the storage area and the rig floor receiving area.
- the drive system preferably comprises a plurality of drive wheels which are adapted to run on guide rails, but may alternatively comprise wheels, tracks or the like.
- a movable rig floor unit configured for location in a rig floor receiving area of a rig assembly to thereby define a rig floor of the rig assembly, the rig floor unit further configured to be received in a transporter for transportation from a storage area to the rig floor receiving area.
- a rig floor transporter configured to receive any one of a plurality of rig floor units, for transporting a selected one of the rig floor units from a storage area to a rig floor receiving area of a rig assembly.
- a rig comprising a rig assembly according to the first aspect of the present invention.
- a vessel comprising a rig, the rig comprising a rig assembly according to the first aspect of the present invention.
- a method of providing a rig floor of a rig assembly comprising the steps of:
- the method further comprises the steps of:
- the method may comprise securing the selected rig floor unit relative to the transporter, transporting the selected rig floor unit to the receiving area and securing the transporter within the receiving area. An operation or step in an operation may then be carried out from the rig floor. Alternatively, the selected rig floor unit may be secured within the receiving area and the transporter moved away from the receiving area.
- the rig floor units may be stored in respective rig floor unit storage locations within the storage area, and may be transferred on to the transporter by a transfer system.
- the storage locations may be at a level above or below that of the transporter, therefore the method may comprise lowering or raising the units from their respective storage locations to the level of the transporter, for transferring the units on to the transporter.
- a rig assembly comprising:
- FIGS. 1 and 2 are plan and side views respectively, of a vessel incorporating a rig assembly, in accordance with an embodiment of the present invention
- FIG. 3 is an enlarged plan view of the rig assembly shown in FIGS. 1 and 2 ;
- FIG. 4 is an enlarged side view of part of the rig assembly shown in FIGS. 1 and 2 ;
- FIGS. 5 and 6 are enlarged plan and side views, respectively, of a transporter forming part of the rig assembly shown in FIGS. 1 and 2 ;
- FIGS. 7 and 8 are enlarged plan and side views, respectively, of a first rig floor unit forming part of the rig assembly shown in FIGS. 1 and 2 ;
- FIGS. 9 and 10 are enlarged plan and side views, respectively, of a second rig floor unit forming part of the rig assembly shown in FIGS. 1 and 2 ;
- FIGS. 11 , 12 and 13 are enlarged plan, side and further side views, respectively, of a third rig floor unit forming part of the rig assembly shown in FIGS. 1 and 2 ;
- FIGS. 14 , 15 and 16 are enlarged plan, side and further side views, respectively, of a fourth rig floor unit forming part of the rig assembly shown in FIGS. 1 and 2 ;
- FIGS. 17 and 18 are enlarged plan and side views of handling equipment forming part of the rig assembly shown in FIGS. 1 and 2 ;
- FIGS. 19 to 24 are schematic side views illustrating use of the handling equipment shown in FIGS. 17 and 18 ;
- FIGS. 25 , 26 and 27 are enlarged plan, side and end views, respectively, of a tail loader provided on the transporter shown in FIGS. 1 to 6 ;
- FIG. 28 is a perspective view of part of a support frame, forming part of a rig assembly in accordance with an alternative embodiment of the present invention.
- FIG. 29 is a perspective view of a tubing gripping assembly forming part of the support frame shown in FIG. 28 .
- FIGS. 1 and 2 there are shown plan and side views, respectively, of a vessel in the form of a drillship 10 incorporating a rig assembly indicated generally by reference numeral 12 , in accordance with an embodiment of the present invention.
- the rig assembly 12 is shown in more detail in the enlarged plan view of FIG. 3 and comprises a rig floor receiving area 14 formed in a deck 16 of the drillship 10 , and a plurality of moveable rig floors, decks or deck units 18 , 20 , 22 and 24 which are initially spaced from the rig floor receiving area 14 .
- Each of the rig floor units 18 , 20 , 22 and 24 are configured for location in the rig floor receiving area 14 , to thereby define a rig floor of the rig assembly 12 .
- the rig assembly 12 also includes a transporter 26 , which is shown in more detail in the enlarged side view of FIG. 4 , showing part of the rig assembly 12 , and in the enlarged plan and side views of FIGS. 5 and 6 , respectively.
- the transporter 26 is configured to receive any one of the rig floor units 18 , 20 , 22 and 24 , for transporting a selected one of the rig floor units 18 , 20 , 22 and 24 from a storage area 28 ( FIGS. 1 to 4 ) to the rig floor receiving area 14 .
- the rig assembly 12 is shown in the Figures with all of the rig floor units 18 , 20 , 22 and 24 in respective storage locations 30 , 32 , 34 and 36 in the storage area 28 and thus prior to transportation of a selected one of the rig floor units from the storage area 28 to the rig floor receiving area 14 .
- a ram rig 38 is provided in the rig floor receiving area 14 above a moonpool 40 ( FIGS. 1 and 3 ) extending through a hull 41 of the drillship 10 .
- the ram rig 38 serves for suspending tubing strings from the drillship 10 and for running equipment downhole. It will be understood that a conventional derrick (not shown) may be provided in place of the ram rig 38 , if desired.
- an upper end 42 of the moonpool 40 is open prior to location of a selected one of the rig floor units 18 , 20 , 22 or 24 above the moonpool 40 .
- each of the rig floor units 18 , 20 , 22 and 24 are designed for carrying out different operations, or different steps in an operation, and carry various different types of equipment suited to the particular operation to be carried out.
- the different operations or steps can be carried out by transporting the desired rig floor unit from the storage area 28 to the rig floor receiving area 14 to a position above the moonpool 40 , to thereby define a rig floor of the rig assembly 12 .
- the selected rig floor unit 18 , 20 , 22 or 24 may then be returned from the rig floor receiving area 14 to the storage area 28 and an alternative rig floor unit selected and transported to the rig floor receiving area 14 .
- This alternative rig floor unit 18 , 20 , 22 or 24 is then located above the moonpool 40 to define a different rig floor, and permits an alternative operation, or a further step in an operation, to be carried out.
- the present invention therefore offers significant advantages over conventional procedures where apparatus required for conducting different operations must be separately transported to the rig floor receiving area using handling equipment such as cranes and elevators and, in certain-circumstances, specialised handling equipment suited only for the particular apparatus to be transported. As described above, such procedures are time-consuming and laborious. In contrast, it is anticipated that changeover of a rig floor unit 18 , 20 , 22 or 24 in place above the moonpool 40 with an alternative rig floor unit will take around 15 minutes to complete, and the operation will offer significant advantages in terms of safety when compared to conventional handling methods using cranes, elevators and the like.
- the rig assembly 12 and method of providing a rig floor of the rig assembly 12 will now be described in more detail.
- FIGS. 7 and 8 are enlarged plan and side views of the rig floor unit 18 ;
- FIGS. 9 and 10 are enlarged plan and side views of the rig floor unit 20 ;
- FIG. 11 is an enlarged plan view of the rig floor unit 22 , whilst FIGS. 12 and 13 are enlarged side views of the unit 22 shown before and during deployment of BOP assembly;
- FIG. 14 is an enlarged plan view of the rig floor unit 24 whilst FIGS. 15 and 16 are enlarged side views of the unit 24 prior to and during deployment of a subsea shut-off device of the type disclosed in International Patent Application Number PCT/GB2005/002885.
- the rig floor unit 18 comprises a frame 48 and a deck surface 50 provided on the frame 48 .
- An aperture 52 extends through the deck surface 50 , and handling equipment in the form of a support structure 54 for a coiled tubing injector 56 is provided on the frame 48 .
- the rig floor unit 18 comprises an injector deck.
- the injector deck 18 defines a rig floor which supports the coiled tubing injector 56 and permits running and control of coiled tubing through a guide 58 (indicated in broken outline), fed from a reel 60 shown in FIGS. 1 and 2 .
- the transporter 26 includes hydraulically actuated lock-down pins or cylinders 62 which, on actuation, are movable between retracted and extended positions.
- the pins 62 are shown in FIG. 5 in an extended position where the pins engage lock-down tubes 64 mounted on the frame 48 of the injector deck 18 .
- the lock-down pins 62 and lock-tubes 64 together form part of a locking assembly for securing the injector deck 18 relative to the transporter 26 .
- the transporter 26 also comprises two side frame members 66 , 68 , coupled by a connecting gantry 67 .
- a space 70 is defined between the side frame members 66 and 68 which is sized to receive the injector deck 18 . It will therefore be understood that when the injector deck 18 is located within the space 70 and locked by the pins 62 , the transporter 26 may safely transport the injector deck 18 from the storage area 28 to the rig floor receiving area 14 .
- the rig assembly 12 also includes a transfer system, best shown in FIG. 3 , which is indicated generally by reference numeral 72 .
- the transfer system 72 serves for transferring the selected rig floor unit 18 , 20 , 22 or 24 from its respective storage location 30 , 32 , 34 and 36 onto the transporter 26 , and also for returning the respective rig floor unit from the transporter 26 to its storage location.
- the transfer system 72 includes a lift 74 which can be raised and lowered.
- the lift 74 is positioned along a length of a path 76 which the transporter 26 traverses during transportation of rig floor units between the storage area 28 and the rig floor receiving area 14 .
- the transfer system 72 also includes two lateral (thwartships) translation assemblies 78 and 80 , which serve for translating selected rig floor units in the direction X-X′ ( FIG. 3 ) and onto the lift 74 by virtue of respective lateral drives 82 , 84 .
- the lateral translation assemblies 78 and 80 also include bow-stern drives 86 , 88 for translating the rig floor units in the direction of the arrows Y-Y′.
- the drives 82 , 84 and 86 , 88 each take the form of conveyors of a conventional type.
- Similar translation assemblies 90 , 92 and 94 are provided which include bow-stern drives 96 , 98 and 100 , respectively. It will therefore be understood that the rig floor units 18 , 20 , 22 and 24 may be moved around the storage locations 30 , 32 , 34 and 36 in the storage area 28 , for positioning a desired rig floor unit adjacent the lift 74 and thus for transferring the selected unit onto the lift 74 .
- the unit 20 takes the form of a drill deck suitable for drilling a well bore and includes a rotary table 102 .
- the rotary table 102 is of a conventional type, save that the table 102 is moveably mounted within the deck 50 a. This facilitates deployment of apparatus through the deck 50 a, if desired, and enables a string of tubing (not shown) to be supported by the ram rig 38 and/or a compensated support frame 104 ( FIGS. 1 and 2 ), which will be described in more detail below.
- Lock-down tubes 64 a are provided integrally within the frame 48 a.
- the unit 22 takes the form of a BOP deck. Like components of the BOP deck with the injector deck 18 share the same reference numerals, with the addition of the suffix b.
- a BOP support structure 54 b on a frame 48 b of the BOP deck 22 serves both for supporting the BOP 44 , and for raising and lowering the BOP 44 by virtue of a deployment cylinder 106 of the ram rig 38 , for lowering the BOP 44 through the aperture 52 b and into the moonpool 40 . This facilitates coupling of tubing (not shown) to the BOP 44 , for deploying the BOP 44 from the drillship 10 .
- a first tubing section is suspended from the ramrig 38 and coupled to the BOP 44 .
- the BOP 44 and first tubing section are then lowered down through the BOP deck aperture 52 b and through the support frame 104 , and the BOP 44 is positioned below the frame 104 .
- the BOP is suspended from the frame 104 by a tubing gripper device on the frame, an example of which will be described in more detail below.
- the BOP 44 With the BOP 44 suspended below the support frame 104 , the BOP 44 is lowered through the moonpool 40 and from the drillship 10 towards a seabed. Successive tubing sections are coupled together to end-to-end in a fashion known in the art, to progressively extend the tubing string. This is achieved by lowering the frame 104 out of the moonpool 40 ; suspending the tubing string and BOP 44 from the deck 50 b using slips or the like (not shown); releasing the gripping device on the frame 104 from the tubing; and stripping the frame 104 back along the tubing up the moonpool 40 . The tubing string/BOP 44 is then once again supported from the frame 104 using the gripping device, the slips released and the tubing/BOP 44 lowered a further distance.
- the support frame 104 forms part of a compensating system for compensating movement of the drillship 10 relative to the seabed, and can be operated in both active and passive compensation modes.
- the unit 24 takes the form of a deck for deploying the subsea shut-off device 46 , and like components of the deck 24 with the injector deck 18 share the same reference numerals, with the addition of the suffix c.
- a support structure 54 c supports the shut-off device 46 during transportation, in the position shown in FIG. 15 , and this also permits access to the device 46 for maintenance purposes.
- the device 46 is rotated to the position shown in FIG. 16 and is suspended from the ram rig 38 .
- the device 46 is then released from the support structure 54 a, tubing (not shown) coupled to the shutoff device 46 , and the deck 50 c released from the receiving area 14 and removed from its position above the moonpool 40 , using the transporter 26 .
- the shutoff device 46 is then lowered through the moonpool 40 to a position below the support frame 104 , and is suspended from the frame 104 using a gripping device.
- the deck 50 c can then be returned above the moonpool 40 , and the shutoff device 46 deployed from the drillship 10 with the assistance of slips or the like on the deck 50 c, in the fashion described above in relation to the BOP 44 of FIGS. 11 to 13 .
- the transporter 26 includes transporter lock-down pins 108 , which are hydraulically actuated in a similar fashion to the pins 62 .
- the transporter pins 108 are shaped for engaging lock-down tubes 110 provided in deck areas 112 , 114 , which thereby form support structures for the transporter 26 .
- the transporter 26 is mounted for movement along a pair of guide rails and includes powered track runners 118 ( FIG. 6 ) for moving the transporter 26 along the rails 116 .
- the rig assembly 12 is operated to bring a selected rig floor unit 18 , 20 , 22 or 24 to the rig floor receiving area 14 as follows. Initially, each of the units 18 , 20 , 22 and 24 are located in their respective storage locations 30 , 32 , 34 or 36 and the transporter is in the position shown in FIGS. 1 to 4 . In a first procedure, it is desired to locate the drill deck 20 above the moonpool 14 . This is achieved by raising the lift 74 up to the level of the drill deck 20 ( FIG. 4 ) and translating the drill deck 20 from its storage location 32 using the lateral drives 82 . It will be noted that the lift 74 includes similar drives 120 for positioning the drill deck 20 on the lift.
- the lift 74 then lowers the drill deck 20 to the level of the lock-down pins 62 on the transporter 26 , and the transporter 26 is driven along the guide rails 116 to a position were the drill deck 20 is received within the space 70 , with the drill deck lock-down tubes 64 in alignment with the pins 62 .
- This movement is permitted by virtue of the connecting gantry 67 of the tranporter 26 , which passes over the top of the drill deck 20 .
- larger equipment such as the BOP assembly 44
- the lock-down pins 62 are actuated, engaging in the tubes 64 , and the drill deck 20 is then locked and secured relative to the transporter 26 .
- the transporter 26 is then returned along the guide rails 116 , and moves to a position where the drill deck 20 is above the moonpool 40 , with the transporter lock-down pins 108 aligned with the transporter lock-down tubes 110 .
- the pins 108 are then actuated, to lock and secure the transporter 26 within the rig floor receiving area 14 . This therefore secures the drill deck 20 within the receiving area 14 , and the drill deck 20 now forms the rig floor.
- the transporter lock-down pins 108 are disengaged, and the transporter returned to a position where the drill deck 20 is above the lift 74 .
- the lift 74 is then raised to bear the load of the drill deck 20 , and the lock-down pins 62 disengaged.
- the transporter 26 is then translated back along the guide rails 116 , and the drill deck 20 returned to the storage location 32 , utilising the lift drives 120 and the lateral drives 82 .
- the drill deck 20 is firstly transferred to a holding storage location 122 by the bow-stern drives 86 on the translation assembly 78 , and the injector deck 18 is then transferred on to the lateral translation assembly 78 by the bow-stern drives 96 on the assembly 90 .
- the injector deck 18 is then transferred on to the lift 74 , and secured to the transporter 26 before being carried to the receiving area 14 and secured as described above.
- the injector deck 18 is returned to the storage location 30 in a similar fashion to the drill deck 20 , and the BOP deck 22 or shut-off device deck 24 may then be carried to the receiving area 14 in the fashion described.
- the rig assembly 12 additionally includes tubing handling equipment in the form of a casing car, which is shown in the enlarged plan and side views of FIGS. 17 and 18 , respectively, and indicated generally by reference numeral 124 .
- the casing car 124 is self-driven, in a similar fashion to the transporter 26 , but is powered and controlled by the transporter 26 and connected by an umbilical or the like (not shown).
- the casing car 124 includes a lifting arm 126 which is pivotally mounted to a beam 128 , the beam 128 being driven and rotatable about an axis 132 relative to the frame 130 . Additionally, the beam 128 can be driven along the length of a cross-frame arm 133 .
- the lifting arm 126 carries a pair of electromagnets 134 which, when actuated, collect a casing section 136 from a store 138 on the deck 16 . Lifting of the casing section 136 , deployment onto the transporter 26 and thus onto the rig floor is shown in the schematic views of FIGS. 19 to 24 .
- the lifting arm 126 is initially positioned relative to the casing section 136 to be lifted such that the section 136 lies horizontally when lifted, on rotation of the beam 128 .
- the support arm 140 carries a bucket 142 which, when in the position indicated by broken outline in FIG. 18 , inclines the casing section 136 from the horizontal, to facilitate transfer of the casing section 136 from the casing car 124 on to the tranporter 26 .
- the support arm 140 is also rotatable to the position shown in solid outline in FIG. 18 , where the bucket 142 forms a support for an end 144 of the casing section 136 . Following movement to the position shown in FIG. 24 , the casing section 136 is vertical and ready for deployment utilising the ram rig 38 .
- a tail loader 146 is provided in the transporter 26 and is shown in more detail in the plan, side and end views, respectively, of FIGS. 25 to 26 .
- the tail loader 146 includes a V-ramp 148 for receiving the casing section 136 , and a pair of arms 150 which are mounted to the V-ramp and which carry a roller 152 .
- the roller 152 tapers towards a central section 154 which co-operates with the V-ramp 148 to support the casing section 136 .
- the arms 150 are rotatable in the direction of the arrow Z ( FIG. 26 ), to bring the roller 150 into contact with the casing-section 136 and to support the casing section safely during deployment into the ram rig 38 , and indeed during deployment through the moonpool 40 .
- the support frame 104 includes a leader frame 156 which is supported on a tension frame 158 .
- the leader frame 156 is movable within the moonpool 40 and locks out towards a lower end 160 of the moonpool, whilst the tension frame 158 can be deployed into the water below the drillship 10 , following the teachings of PCT/GB2006/001822.
- Four arms 162 are pivotally coupled to the tension frame 158 and, in the position of FIG. 3 , provide a mounting for the gripper device (not shown).
- the gripper device When it is desired to have full access down the moonpool 40 through the tension frame 158 , the gripper device is removed from its location on the arms 162 , and the arms pivoted to folded positions. This provides unrestricted passage through the tension frame 158 , for example, for the BOP 44 .
- FIG. 28 there is shown a perspective view of part of an alternative support frame 104 ′.
- Like components of the support frame 104 ′ with the support frame 104 share the same reference numerals, with the addition of the suffix ′. Only the differences between the frames 104 ′ and 104 will be described herein in detail.
- FIG. 28 in fact shows a tension frame 158 ′ of the support frame 104 ′.
- the tension frame 158 ′ includes four main columns 164 , each of which carries a respective inwardly extending lug or boss 166 . These lugs 166 are provided in place of the pivoting arms 162 of the frame 104 , and provide mountings for a tubing gripping assembly 168 , which is shown in the perspective view of FIG. 29 .
- the gripping assembly 168 includes a releasable gripper device 170 , and is shown gripping and supporting tubing in the form of a drill collar 172 .
- the gripper device 170 is provided within a central hub 174 , from which four mounting arms 176 extend.
- Each of the mounting arms 176 include a pair of shaped wedges 178 , which are shaped to engage around the lugs 166 , such that the gripping assembly 168 can be releasably mounted on the lugs 166 and thus located within the tension frame 158 ′.
- the gripping assembly 168 can be selectively removed from its location within the tension frame 158 ′ when full clearance through the support frame 104 ′ is required, for example, for the passage of the BOP 44 , simply by lifting the assembly 168 up off the lugs 166 . Following passage of the BOP 44 through the support frame 104 ′, the gripping assembly 168 can be returned to its position within the tension frame 158 ′.
- the gripper device 170 includes a pair of hinged gripper arms 180 , each of which carries a half-cylindrical slip or tubing grip 182 .
- the arms 180 are pivotally mounted to the hub 174 by pins 181 , and are moved between disengaged and engaged positions by hydraulic pistons 184 .
- the arms 180 are shown in FIG. 29 in their engaged positions, where the slips 182 are seated in an upper end of a bore of a hollow mounting 186 which is located within the hub 174 , defining a cylindrical collar.
- the slips 182 are each shaped to engage an upset or shoulder on the drill collar 172 , for suspending a tubing string including the drill collar 172 from the tension frame 158 ′.
- the pistons 184 are actuated to rotate the slips 182 away from the upper end of the mounting 186 bore. It will be understood that this facilitates release of the tension frame 158 ′ from the tubing string, such that the frame 158 ′ may be stripped along the tubing for coupling further tubing sections, such as a further drill collar 172 .
- Movement of the tension frames 158 , 158 ′ is controlled using winches and tensioner devices according to the teachings of PCT/GB2006/001822.
- movement of the tension frame 158 or 158 ′ is controlled such that the location of equipment relative to a seabed is precisely controlled during deployment of the equipment from the drillship 10 . This is particularly important, for example, during lowering of a tubing string carrying the BOP 44 where the drillship 10 is pitching, rolling and heaving under applied wind, wave and tidal loads.
- a passive compensation mode movement of the tension frame 158 or 158 ′ relative to the drillship 10 , due to movement of the drillship 10 , is damped out using the winches and tensioner devices.
- the rig assembly described herein, including the rig floor units 18 - 24 , transporter 26 and support frame 104 offers particular advantages in that the load of tubing/equipment can be transferred between the frame 104 and the drillship 10 deck, facilitating changeout of the deck units.
- the locking assemblies may comprise locking dogs, latches or the like.
- the locking assemblies may be hydraulically actuated, electro-mechanically or electrically actuated, or indeed a combination thereof.
- the rig floor units may each be configured to be releasably secured, locked or located relative to or within the rig floor receiving area. In this fashion, the transporter may be removed from the receiving area, if desired, following location of the rig floor unit within the rig floor receiving area.
- the translation devices may be adapted to transfer the rig floor units directly between their respective storage locations and the transporter.
- the transporter may be height adjustable for raising and lowering to a level of the unit storage locations.
- the tubing handling device may serve for picking up and/or supporting any desired type of tubing, which may be a length of casing, liner, riser, drill tubing, production tubing or any other tubing utilised in the industry. In place of electromagnets, any other suitable support may be provided.
- the surface facility may be an alternative vessel such as an FPSO or FSO, or a rig such as a semi-submersible, submersible or jack-up rig.
- the rig floor receiving area may be provided on or in a frame or support which may extend overboard.
- Any desired rig floor unit may be provided, including suitable support/deployment apparatus or equipment.
- the transporter may be configured to receive a plurality of selected rig floor units.
- the transporter may be configured to receive two units, for faster changeover.
- a separate drive system may be provided for moving the transporter/handling equipment.
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Abstract
The invention relates to a rig assembly for use in the oil and gas exploration and production industry. In an embodiment of the invention, a rig assembly (12) for a drill ship (10) is disclosed. The rig assembly (12) comprises a rig floor receiving area (14); a plurality of movable rig floor units (18, 20, 22 and 24), each rig floor unit (18, 20, 22 and 24) configured for location in the rig floor receiving area (14), to thereby define a rig floor of the rig assembly (12); and a transporter (26) configured to receive any one of the rig floor units (18, 20, 22 and 24), for transporting a selected one of the rig floor units (18, 20, 22 and 24) from a storage area (28) to the rig floor receiving area (14).
Description
- The present invention relates to a rig assembly for use in the oil and gas exploration and production industry. In particular, but not exclusively, the present invention relates to a rig assembly with an improved rig floor, as well as to an improved rig floor, a transporter and a method of providing a rig floor of a rig assembly.
- In the oil and gas exploration and production industry, access to subterranean oil and gas reserves is typically achieved by drilling a well from surface and installing and cementing a series of concentric casing strings in the drilled borehole, extending from a wellhead. The borehole is then extended to a desired depth and a liner installed in the extended section, the liner extending from the bottom or ‘shoe’ of the lowermost casing string. Following cleaning and testing of the lined borehole, production tubing is installed extending from surface down through the casing and liner to a producing formation. Well fluids flow into the production tubing from the formation and are thereby recovered to surface.
- In an offshore environment, it is necessary to install a large diameter tubing, known as a riser, extending from the wellhead to a surface facility such as a drillship, floating production storage and offloading vessel (FPSO), drilling rig or the like. Tubing strings including liner, drill strings, production tubing and other intervention or tool strings are all run into the borehole through the riser. A blow-out preventer (BOP) is also provided as part of the riser string, and is either located at seabed level on the wellhead, or is located nearer to surface, if prevailing weather conditions permit. As is well known in the art, the BOP permits safe shut-down of the well in the event of an emergency situation arising.
- Other types of procedures have been proposed for gaining access to well fluids, including the method proposed by one of the present co-inventors in International Patent Application No. PCT/GB2005/002885, whereby a subsea shut-off device including a ball gripping mechanism is latched to a template at surface, and drilled in casing is suspended from the device at any position using the gripping mechanism so that the device is run to the sea floor on a casing string. The casing string is drilled into place and converted into a riser, and this is all done on a single trip to speed up the operation and reduce risk. The casing string is captured and sealed within the subsea shut-off device after installing and spacing out a surface BOP.
- A vast array of equipment is required in order to bring a well into production, whether following conventional techniques, or alternatives such as that proposed in PCT/GB2005/002885. Much of the equipment utilised must be brought to a location adjacent a rig floor of the surface facility, for subsequent deployment, or is deployed from a level below the rig floor. Conventionally, this has been achieved utilising handling equipment including cranes, elevators and the like. In more recent years, dedicated equipment has been developed specifically for handling apparatus to be deployed from the rig, particularly large, heavy apparatus such as BOPs, which may weigh several hundred tonnes.
- The handling of equipment utilising cranes and elevators is generally undesired, and can lead to accidents, particularly on vessels which are subject to relatively large movements under applied wind, wave and tidal loading. Additionally, the handling of apparatus using such equipment is typically time-consuming and laborious. It will be appreciated that, in view of the high rental costs involved in leasing offshore equipment such as floating rigs and drillships, it is generally desired to minimise the time taken to carry out all types of procedure in the industry.
- Where dedicated equipment has been provided for handling apparatus to be deployed, this equipment has conventionally been very large, which presents a particular problem in the offshore environment, where space is severely restricted. Additionally, the handling equipment is suited only for a single use or purpose; is typically slow moving; and is not capable of being used to handle other types of apparatus.
- Whilst space restrictions are less pronounced in onshore facilities, it will be understood that many of the above problems are of equal concern.
- It is amongst the objects of embodiments of the present invention to obviate or mitigate at least one of the foregoing disadvantages.
- According to a first aspect of the present invention, there is provided a rig assembly comprising:
-
- a rig floor receiving area;
- a plurality of movable rig floor units, each rig floor unit configured for location in the rig floor receiving area, to thereby define a rig floor of the rig assembly; and
- a transporter configured to receive any one of the rig floor units, for transporting a selected one of the rig floor units from a storage area to the rig floor receiving area.
- It will be understood that the transporter may also be for transporting a rig floor unit from the rig floor receiving area to the storage area, when it is desired to locate an alternative selected rig floor unit in the rig floor receiving area. The transporter may therefore serve for transporting rig floor units between the two areas.
- It will also be understood that a rig floor of a rig assembly is generally defined as the work area in which a rig crew conducts operations.
- Providing a rig assembly with a plurality of movable rig floor units, a rig floor receiving area, and a transporter for transporting a selected rig floor unit from a storage area to the rig floor receiving area, facilitates a rapid changeover at the rig floor area when different tasks or operations are to be performed, when compared with prior practice in the industry.
- Each rig floor unit may be adapted for performing a different task or operation or a step in a task or operation. Thus switching of equipment necessary to carry out the desired task, operation or step may be rapidly achieved simply by switching around the rig floor units. To facilitate this, each rig floor unit may be adapted to carry different equipment suited to the particular task, operation or step.
- The storage area may comprise a plurality of rig floor storage locations, each configured to receive a respective rig floor unit. Accordingly, each rig floor unit may be adapted to be located in a respective storage location in the storage area. The selected rig floor unit may be adapted to be transferred from its storage location on to the transporter, which may then transport the rig floor unit to the rig floor receiving area.
- The transporter may be movable along a path extending between the storage area and the rig floor receiving area, for transporting the rig floor units between the storage area and the rig floor receiving area. The transporter may therefore be movable to a position where it can access any one of the rig floor units, such that the selected rig floor unit may be transferred on to the transporter, and such that a rig floor unit returned from the rig floor receiving area to the storage area by the transporter may be transferred off the transporter. The rig floor units may each be configured to be releasably secured, locked or located relative to or within the transporter. This may permit safe transportation of the rig floor units between the storage area and the receiving area, as well as safe operation in use of the rig floor defined by the rig floor unit. One or both of the rig floor units and the transporter may comprise a locking assembly for securing the rig floor units relative to the transporter. The transporter may be configured to be releasably secured, locked or located relative to or within the rig floor receiving area. In this fashion, the transporter, carrying the selected rig floor, may be secured within the rig floor receiving area and may thereby locate the rig floor unit in the receiving area, to define the rig floor. It will therefore be understood that the transporter may remain within the receiving area during the time when the selected rig floor unit is in the receiving area.
- The transporter may be configured to be secured to a support structure provided in the rig floor receiving area. One or both of the transporter and the support structure may comprise a locking assembly for securing the transporter in the receiving area. The locking assembly may comprise at least one, and preferably a plurality of locking dogs, pins, latches or the like. The locking assembly may be hydraulically actuated, or in alternative embodiments, may be electro-mechanically or electrically actuated or a combination thereof.
- In alternative embodiments, the rig floor units may each be configured to be releasably secured, locked or located relative to or within the rig floor receiving area. In this fashion, the transporter may be removed from the receiving area, if desired, following location of the rig floor unit within the rig floor receiving area.
- The rig floor units may be configured to be secured to a support structure provided in the rig floor receiving area. One or both of the rig floor units and the support structure may comprise a locking assembly for securing the rig floor units in the receiving area. The locking assembly may comprise at least one, and preferably a plurality of locking dogs, pins, latches or the like. The locking assembly may be hydraulically actuated, or in alternative embodiments, may be electro-mechanically or electrically actuated or a combination thereof.
- The rig assembly may comprise a transfer system for transferring the rig floor units between a storage location within the storage area and the transporter. The transfer system may comprise a translation device for translating the rig floor units between their storage locations and the transporter. The translation device may be adapted to transfer the rig floor units directly between their respective storage locations and the transporter. However, in embodiments of the invention, the transfer system may comprise a lift, elevator or the like for raising and/or lowering the rig floor units between a level of the storage locations and a level of the transporter. In use, a rig floor unit may be translated on to the lift and the lift may then raise or lower the rig floor unit into a position where the unit may be received within the transporter. The transporter may be shaped to define a space in which the rig floor units are received, to facilitate transfer of the units from the lift into the transporter. In particular, the transporter may be shaped to straddle the rig floor units, and may comprise first and second sides spaced and connected by a connecting structure, with a space defined between the sides in which the rig floor units are received. In a variation, the transporter may be height adjustable for raising and lowering to a level of the unit storage locations.
- The rig assembly may be modular and may therefore be adaptable for various different types of rig, according to the space available. Accordingly, the rig assembly may be configured as required to suit a particular rig.
- The rig assembly may comprise handling equipment which may be coupled to and movable with the transporter, or which may be independently movable relative to the transporter. The handling equipment may comprise a tubing handling device for picking up and/or supporting a length of tubing, and which may serve for transferring tubing on to the transporter. This may facilitate subsequent deployment of the tubing on to and/or through the rig floor defined by the selected rig floor unit. It will be understood that the tubing may be a length of casing, liner, riser, drill tubing, production tubing or any other tubing utilised in the industry. The handling device may comprise one or more electromagnetic supports for selectively picking up and/or supporting the tubing. The handling device may be adapted to incline the tubing to assist in transfer on to the rig floor, and may comprise a support for supporting an end of the tubing during transfer.
- The rig floor receiving area may be adapted to be provided on or in a deck of a surface facility on which the rig assembly is provided. The rig floor receiving area may be provided around or adjacent to a moonpool in the facility. It will be understood that the moonpool is the opening in the hull or structure of the surface facility through which equipment/apparatus passes. The transporter may be for transporting the selected rig floor unit to a location above the moonpool, for the deployment of equipment into the moonpool. It will be understood that the surface facility may be a vessel such as a drillship, FPSO or FSO, or a rig such as a semi-submersible, submersible or jack-up rig. Alternatively, the rig floor receiving area may be adapted to be provided on or in a frame or support which may extend overboard.
- The rig floor units may each comprise handling apparatus for handling equipment to be deployed from the rig floor. The rig floor units may be selected from a group comprising: a drill unit having a rotary drive for driving and rotating a string of tubing; a BOP unit for supporting a BOP; a coiled tubing injector unit for supporting a coiled tubing injector to be used for running coiled tubing; and a subsea shut-off device unit, for running a subsea shut-off device such as that disclosed in International Patent Application No. PCT/GB2005/002885. However, it will be understood that, in principle, any desired rig floor unit may be provided. At least one of the rig floor units may be adapted for deploying equipment from the rig assembly. For example, in embodiments of the invention, at least one of the rig floor units may comprise an aperture through which equipment may be deployed.
- At least one of the rig floor units may be adapted to selectively support a tubing string and may therefore serve for suspending at least part of the load of a tubing string from the rig. The rig assembly may comprise a support for supporting a load of a tubing string during changeover of rig floor units.
- If desired, the transporter may be configured to receive a plurality of selected rig floor units. Thus, for example, where the rig assembly comprises three or more rig floor units, the transporter may be configured to receive two units, for faster changeover.
- The transporter may be self-driven, and may therefore comprise a drive system for moving the transporter between the storage area and the rig floor receiving area. The drive system preferably comprises a plurality of drive wheels which are adapted to run on guide rails, but may alternatively comprise wheels, tracks or the like.
- According to a second aspect of the present invention, there is provided a movable rig floor unit, the rig floor unit configured for location in a rig floor receiving area of a rig assembly to thereby define a rig floor of the rig assembly, the rig floor unit further configured to be received in a transporter for transportation from a storage area to the rig floor receiving area.
- According to a third aspect of the present invention, there is provided a rig floor transporter, the transporter configured to receive any one of a plurality of rig floor units, for transporting a selected one of the rig floor units from a storage area to a rig floor receiving area of a rig assembly.
- Further features of the rig floor unit and the transporter of the second and third aspects of the invention, respectively, are defined above in relation to the first aspect of the invention.
- According to a fourth aspect of the present invention, there is provided a rig comprising a rig assembly according to the first aspect of the present invention.
- According to a fifth aspect of the present invention, there is provided a vessel comprising a rig, the rig comprising a rig assembly according to the first aspect of the present invention.
- According to a sixth aspect of the present invention, there is provided a method of providing a rig floor of a rig assembly, the method comprising the steps of:
-
- providing a plurality of movable rig floor units, each rig floor unit configured for location in a rig floor receiving area of a rig assembly, the rig floor units located in a storage area on a rig;
- selecting one of the rig floor units;
- mounting the selected rig floor unit on a transporter configured to receive any one of the rig floor units;
- transporting the selected rig floor unit from the storage area to the rig floor receiving area using the transporter; and
- locating the selected rig floor unit in the rig floor receiving area, to thereby form a rig floor of the rig assembly.
- Preferably, the method further comprises the steps of:
-
- returning the selected rig floor unit from the rig floor receiving area to the storage area using the transporter;
- selecting an alternative rig floor unit;
- mounting the alternative rig floor unit on the transporter;
- transporting the alternative rig floor unit from the storage area to the rig floor receiving area using the transporter; and
- locating the alternative rig floor unit in the rig floor receiving area, to thereby form an alternative rig floor of the rig assembly. These steps may be repeated as necessary or as desired in order to define a number of different rig floors, which may permit a range of operations to be carried out. Indeed, the method may further comprise the steps of performing an operation or a step in an operation from the rig floor defined by the selected rig floor unit, before returning the unit to the storage area and, following location of the alternative unit in the receiving area, performing an operation or a further step in an operation from the alternative rig floor.
- The method may comprise securing the selected rig floor unit relative to the transporter, transporting the selected rig floor unit to the receiving area and securing the transporter within the receiving area. An operation or step in an operation may then be carried out from the rig floor. Alternatively, the selected rig floor unit may be secured within the receiving area and the transporter moved away from the receiving area.
- The rig floor units may be stored in respective rig floor unit storage locations within the storage area, and may be transferred on to the transporter by a transfer system. The storage locations may be at a level above or below that of the transporter, therefore the method may comprise lowering or raising the units from their respective storage locations to the level of the transporter, for transferring the units on to the transporter.
- According to a seventh aspect of the present invention, there is provided a rig assembly comprising:
-
- a rig floor receiving area;
- a plurality of movable rig floor units, each rig floor unit configured for location in the rig floor receiving area, to thereby define a rig floor of the rig assembly; and
- a transporter configured to receive any one of the rig floor units, for transporting a rig floor unit between a storage area and the rig floor receiving area.
- Embodiments of the present invention will now be described, by way of example only, with reference to the accompanying drawings, in which:
-
FIGS. 1 and 2 are plan and side views respectively, of a vessel incorporating a rig assembly, in accordance with an embodiment of the present invention; -
FIG. 3 is an enlarged plan view of the rig assembly shown inFIGS. 1 and 2 ; -
FIG. 4 is an enlarged side view of part of the rig assembly shown inFIGS. 1 and 2 ; -
FIGS. 5 and 6 are enlarged plan and side views, respectively, of a transporter forming part of the rig assembly shown inFIGS. 1 and 2 ; -
FIGS. 7 and 8 are enlarged plan and side views, respectively, of a first rig floor unit forming part of the rig assembly shown inFIGS. 1 and 2 ; -
FIGS. 9 and 10 are enlarged plan and side views, respectively, of a second rig floor unit forming part of the rig assembly shown inFIGS. 1 and 2 ; -
FIGS. 11 , 12 and 13 are enlarged plan, side and further side views, respectively, of a third rig floor unit forming part of the rig assembly shown inFIGS. 1 and 2 ; -
FIGS. 14 , 15 and 16 are enlarged plan, side and further side views, respectively, of a fourth rig floor unit forming part of the rig assembly shown inFIGS. 1 and 2 ; -
FIGS. 17 and 18 are enlarged plan and side views of handling equipment forming part of the rig assembly shown inFIGS. 1 and 2 ; -
FIGS. 19 to 24 are schematic side views illustrating use of the handling equipment shown inFIGS. 17 and 18 ; -
FIGS. 25 , 26 and 27 are enlarged plan, side and end views, respectively, of a tail loader provided on the transporter shown inFIGS. 1 to 6 ; -
FIG. 28 is a perspective view of part of a support frame, forming part of a rig assembly in accordance with an alternative embodiment of the present invention; and -
FIG. 29 is a perspective view of a tubing gripping assembly forming part of the support frame shown inFIG. 28 . - Turning firstly to
FIGS. 1 and 2 , there are shown plan and side views, respectively, of a vessel in the form of adrillship 10 incorporating a rig assembly indicated generally byreference numeral 12, in accordance with an embodiment of the present invention. Therig assembly 12 is shown in more detail in the enlarged plan view ofFIG. 3 and comprises a rig floor receiving area 14 formed in adeck 16 of thedrillship 10, and a plurality of moveable rig floors, decks ordeck units rig floor units rig assembly 12. Therig assembly 12 also includes atransporter 26, which is shown in more detail in the enlarged side view ofFIG. 4 , showing part of therig assembly 12, and in the enlarged plan and side views ofFIGS. 5 and 6 , respectively. Thetransporter 26 is configured to receive any one of therig floor units rig floor units FIGS. 1 to 4 ) to the rig floor receiving area 14. - The
rig assembly 12 is shown in the Figures with all of therig floor units respective storage locations storage area 28 and thus prior to transportation of a selected one of the rig floor units from thestorage area 28 to the rig floor receiving area 14. - A
ram rig 38 is provided in the rig floor receiving area 14 above a moonpool 40 (FIGS. 1 and 3 ) extending through ahull 41 of thedrillship 10. Theram rig 38 serves for suspending tubing strings from thedrillship 10 and for running equipment downhole. It will be understood that a conventional derrick (not shown) may be provided in place of theram rig 38, if desired. As shown particularly inFIGS. 1 and 3 , anupper end 42 of themoonpool 40 is open prior to location of a selected one of therig floor units moonpool 40. - As will be described in more detail below, each of the
rig floor units rig floor units storage area 28 to the rig floor receiving area 14 to a position above themoonpool 40, to thereby define a rig floor of therig assembly 12. Once located in the receiving area 14, the desired operation or steps are carried out and, following completion of the operation, the selectedrig floor unit storage area 28 and an alternative rig floor unit selected and transported to the rig floor receiving area 14. This alternativerig floor unit moonpool 40 to define a different rig floor, and permits an alternative operation, or a further step in an operation, to be carried out. - The present invention therefore offers significant advantages over conventional procedures where apparatus required for conducting different operations must be separately transported to the rig floor receiving area using handling equipment such as cranes and elevators and, in certain-circumstances, specialised handling equipment suited only for the particular apparatus to be transported. As described above, such procedures are time-consuming and laborious. In contrast, it is anticipated that changeover of a
rig floor unit moonpool 40 with an alternative rig floor unit will take around 15 minutes to complete, and the operation will offer significant advantages in terms of safety when compared to conventional handling methods using cranes, elevators and the like. - The
rig assembly 12 and method of providing a rig floor of therig assembly 12 will now be described in more detail. - The
rig floor units FIGS. 7 to 16 . Of these,FIGS. 7 and 8 are enlarged plan and side views of therig floor unit 18;FIGS. 9 and 10 are enlarged plan and side views of therig floor unit 20;FIG. 11 is an enlarged plan view of therig floor unit 22, whilstFIGS. 12 and 13 are enlarged side views of theunit 22 shown before and during deployment of BOP assembly; andFIG. 14 is an enlarged plan view of therig floor unit 24 whilstFIGS. 15 and 16 are enlarged side views of theunit 24 prior to and during deployment of a subsea shut-off device of the type disclosed in International Patent Application Number PCT/GB2005/002885. - As shown in
FIGS. 7 and 8 , therig floor unit 18 comprises aframe 48 and adeck surface 50 provided on theframe 48. Anaperture 52 extends through thedeck surface 50, and handling equipment in the form of asupport structure 54 for acoiled tubing injector 56 is provided on theframe 48. It will therefore be understood that therig floor unit 18 comprises an injector deck. When theinjector deck 18 is provided in the receiving area 14 above themoonpool 40, theinjector deck 18 defines a rig floor which supports the coiledtubing injector 56 and permits running and control of coiled tubing through a guide 58 (indicated in broken outline), fed from areel 60 shown inFIGS. 1 and 2 . - As shown particularly in
FIGS. 4 to 6 , thetransporter 26 includes hydraulically actuated lock-down pins orcylinders 62 which, on actuation, are movable between retracted and extended positions. Thepins 62 are shown inFIG. 5 in an extended position where the pins engage lock-downtubes 64 mounted on theframe 48 of theinjector deck 18. The lock-downpins 62 and lock-tubes 64 together form part of a locking assembly for securing theinjector deck 18 relative to thetransporter 26. Thetransporter 26 also comprises twoside frame members gantry 67. Aspace 70 is defined between theside frame members injector deck 18. It will therefore be understood that when theinjector deck 18 is located within thespace 70 and locked by thepins 62, thetransporter 26 may safely transport theinjector deck 18 from thestorage area 28 to the rig floor receiving area 14. - The
rig assembly 12 also includes a transfer system, best shown inFIG. 3 , which is indicated generally byreference numeral 72. Thetransfer system 72 serves for transferring the selectedrig floor unit respective storage location transporter 26, and also for returning the respective rig floor unit from thetransporter 26 to its storage location. To achieve this, thetransfer system 72 includes alift 74 which can be raised and lowered. Thelift 74 is positioned along a length of apath 76 which thetransporter 26 traverses during transportation of rig floor units between thestorage area 28 and the rig floor receiving area 14. Thetransfer system 72 also includes two lateral (thwartships)translation assemblies FIG. 3 ) and onto thelift 74 by virtue of respective lateral drives 82, 84. Thelateral translation assemblies drives - Further,
similar translation assemblies rig floor units storage locations storage area 28, for positioning a desired rig floor unit adjacent thelift 74 and thus for transferring the selected unit onto thelift 74. - Returning now to
FIGS. 9 and 10 , where therig floor unit 20 is shown, theunit 20 takes the form of a drill deck suitable for drilling a well bore and includes a rotary table 102. Like components of thedrill deck 20 with theinjector deck 18 share the same reference numerals, with the addition of the suffix a. The rotary table 102 is of a conventional type, save that the table 102 is moveably mounted within thedeck 50 a. This facilitates deployment of apparatus through thedeck 50 a, if desired, and enables a string of tubing (not shown) to be supported by theram rig 38 and/or a compensated support frame 104 (FIGS. 1 and 2 ), which will be described in more detail below. Lock-downtubes 64 a are provided integrally within theframe 48 a. - Returning to
FIGS. 11 to 13 , where therig floor unit 22 is shown, theunit 22 takes the form of a BOP deck. Like components of the BOP deck with theinjector deck 18 share the same reference numerals, with the addition of the suffix b. ABOP support structure 54 b on aframe 48 b of theBOP deck 22 serves both for supporting theBOP 44, and for raising and lowering theBOP 44 by virtue of adeployment cylinder 106 of theram rig 38, for lowering theBOP 44 through theaperture 52 b and into themoonpool 40. This facilitates coupling of tubing (not shown) to theBOP 44, for deploying theBOP 44 from thedrillship 10. Typically, a first tubing section is suspended from theramrig 38 and coupled to theBOP 44. TheBOP 44 and first tubing section are then lowered down through theBOP deck aperture 52 b and through thesupport frame 104, and theBOP 44 is positioned below theframe 104. Following the teachings of PCT/GB2006/001822 to one of the present co-inventors, the disclosure of which is incorporated herein by way of reference, the BOP is suspended from theframe 104 by a tubing gripper device on the frame, an example of which will be described in more detail below. - With the
BOP 44 suspended below thesupport frame 104, theBOP 44 is lowered through themoonpool 40 and from thedrillship 10 towards a seabed. Successive tubing sections are coupled together to end-to-end in a fashion known in the art, to progressively extend the tubing string. This is achieved by lowering theframe 104 out of themoonpool 40; suspending the tubing string andBOP 44 from thedeck 50 b using slips or the like (not shown); releasing the gripping device on theframe 104 from the tubing; and stripping theframe 104 back along the tubing up themoonpool 40. The tubing string/BOP 44 is then once again supported from theframe 104 using the gripping device, the slips released and the tubing/BOP 44 lowered a further distance. Additional tubing, suspended from theramrig 38, is then coupled to the tubing section extending up through themoonpool 40, and the tubing string/BOP 44 lowered a further distance. This process is repeated until theBOP 44 has been deployed down to the seabed and connected to a wellhead. - In accordance with the teachings of PCT/GB2006/001822, the
support frame 104 forms part of a compensating system for compensating movement of thedrillship 10 relative to the seabed, and can be operated in both active and passive compensation modes. - Returning now to
FIGS. 14 to 16 , where therig floor unit 24 is shown, theunit 24 takes the form of a deck for deploying the subsea shut-offdevice 46, and like components of thedeck 24 with theinjector deck 18 share the same reference numerals, with the addition of the suffix c. A support structure 54 c supports the shut-offdevice 46 during transportation, in the position shown inFIG. 15 , and this also permits access to thedevice 46 for maintenance purposes. When thedevice 46 is to be deployed into themoonpool 40, thedevice 46 is rotated to the position shown inFIG. 16 and is suspended from theram rig 38. Thedevice 46 is then released from the support structure 54 a, tubing (not shown) coupled to theshutoff device 46, and the deck 50 c released from the receiving area 14 and removed from its position above themoonpool 40, using thetransporter 26. Theshutoff device 46 is then lowered through themoonpool 40 to a position below thesupport frame 104, and is suspended from theframe 104 using a gripping device. The deck 50 c can then be returned above themoonpool 40, and theshutoff device 46 deployed from thedrillship 10 with the assistance of slips or the like on the deck 50 c, in the fashion described above in relation to theBOP 44 ofFIGS. 11 to 13 . - Returning once more to
FIGS. 4 to 6 , it will be noted that thetransporter 26 includes transporter lock-downpins 108, which are hydraulically actuated in a similar fashion to thepins 62. The transporter pins 108 are shaped for engaging lock-downtubes 110 provided indeck areas transporter 26. Thetransporter 26 is mounted for movement along a pair of guide rails and includes powered track runners 118 (FIG. 6 ) for moving thetransporter 26 along therails 116. - The
rig assembly 12 is operated to bring a selectedrig floor unit units respective storage locations FIGS. 1 to 4 . In a first procedure, it is desired to locate thedrill deck 20 above the moonpool 14. This is achieved by raising thelift 74 up to the level of the drill deck 20 (FIG. 4 ) and translating thedrill deck 20 from itsstorage location 32 using the lateral drives 82. It will be noted that thelift 74 includessimilar drives 120 for positioning thedrill deck 20 on the lift. Thelift 74 then lowers thedrill deck 20 to the level of the lock-downpins 62 on thetransporter 26, and thetransporter 26 is driven along theguide rails 116 to a position were thedrill deck 20 is received within thespace 70, with the drill deck lock-downtubes 64 in alignment with thepins 62. This movement is permitted by virtue of the connectinggantry 67 of thetranporter 26, which passes over the top of thedrill deck 20. However, it will be understood that where larger equipment, such as theBOP assembly 44, has to be carried by thetransporter 26, it may be necessary for thelift 74 to carry theBOP assembly 44 further down in to thehull 41 of thedrillship 10, and then to raise it up following positioning of thetransporter 26. - With the
drill deck 20 in position, the lock-downpins 62 are actuated, engaging in thetubes 64, and thedrill deck 20 is then locked and secured relative to thetransporter 26. Thetransporter 26 is then returned along theguide rails 116, and moves to a position where thedrill deck 20 is above themoonpool 40, with the transporter lock-downpins 108 aligned with the transporter lock-downtubes 110. Thepins 108 are then actuated, to lock and secure thetransporter 26 within the rig floor receiving area 14. This therefore secures thedrill deck 20 within the receiving area 14, and thedrill deck 20 now forms the rig floor. - Following completion of a drilling procedure utilising the
drill deck 20, it is desired to return thedrill deck 20 to thestorage area 28 and to select an alternative rig floor unit from theinjector deck 18,BOP deck 22 and shut-offdevice deck 24. To achieve this, the transporter lock-downpins 108 are disengaged, and the transporter returned to a position where thedrill deck 20 is above thelift 74. Thelift 74 is then raised to bear the load of thedrill deck 20, and the lock-downpins 62 disengaged. Thetransporter 26 is then translated back along theguide rails 116, and thedrill deck 20 returned to thestorage location 32, utilising the lift drives 120 and the lateral drives 82. If it is now desired to transfer theinjector deck 18 from itsstorage location 30 to the receiving area 14, thedrill deck 20 is firstly transferred to a holdingstorage location 122 by the bow-stern drives 86 on thetranslation assembly 78, and theinjector deck 18 is then transferred on to thelateral translation assembly 78 by the bow-stern drives 96 on theassembly 90. Theinjector deck 18 is then transferred on to thelift 74, and secured to thetransporter 26 before being carried to the receiving area 14 and secured as described above. Following completion of a procedure utilising theinjector deck 18, theinjector deck 18 is returned to thestorage location 30 in a similar fashion to thedrill deck 20, and theBOP deck 22 or shut-offdevice deck 24 may then be carried to the receiving area 14 in the fashion described. - The
rig assembly 12 additionally includes tubing handling equipment in the form of a casing car, which is shown in the enlarged plan and side views ofFIGS. 17 and 18 , respectively, and indicated generally byreference numeral 124. Thecasing car 124 is self-driven, in a similar fashion to thetransporter 26, but is powered and controlled by thetransporter 26 and connected by an umbilical or the like (not shown). - The
casing car 124 includes alifting arm 126 which is pivotally mounted to abeam 128, thebeam 128 being driven and rotatable about anaxis 132 relative to theframe 130. Additionally, thebeam 128 can be driven along the length of across-frame arm 133. The liftingarm 126 carries a pair ofelectromagnets 134 which, when actuated, collect acasing section 136 from astore 138 on thedeck 16. Lifting of thecasing section 136, deployment onto thetransporter 26 and thus onto the rig floor is shown in the schematic views ofFIGS. 19 to 24 . The liftingarm 126 is initially positioned relative to thecasing section 136 to be lifted such that thesection 136 lies horizontally when lifted, on rotation of thebeam 128. Thesupport arm 140 carries abucket 142 which, when in the position indicated by broken outline inFIG. 18 , inclines thecasing section 136 from the horizontal, to facilitate transfer of thecasing section 136 from thecasing car 124 on to thetranporter 26. Thesupport arm 140 is also rotatable to the position shown in solid outline inFIG. 18 , where thebucket 142 forms a support for anend 144 of thecasing section 136. Following movement to the position shown inFIG. 24 , thecasing section 136 is vertical and ready for deployment utilising theram rig 38. - To assist in deployment of the
casing section 136, atail loader 146 is provided in thetransporter 26 and is shown in more detail in the plan, side and end views, respectively, ofFIGS. 25 to 26 . Thetail loader 146 includes a V-ramp 148 for receiving thecasing section 136, and a pair ofarms 150 which are mounted to the V-ramp and which carry aroller 152. As shown inFIG. 27 , theroller 152 tapers towards acentral section 154 which co-operates with the V-ramp 148 to support thecasing section 136. As shown particularly inFIGS. 22 to 24 , thearms 150 are rotatable in the direction of the arrow Z (FIG. 26 ), to bring theroller 150 into contact with the casing-section 136 and to support the casing section safely during deployment into theram rig 38, and indeed during deployment through themoonpool 40. - Considering now the
support frame 104 in more detail, thesupport frame 104 includes aleader frame 156 which is supported on atension frame 158. Theleader frame 156 is movable within themoonpool 40 and locks out towards alower end 160 of the moonpool, whilst thetension frame 158 can be deployed into the water below thedrillship 10, following the teachings of PCT/GB2006/001822. Four arms 162, best shown inFIG. 3 , are pivotally coupled to thetension frame 158 and, in the position ofFIG. 3 , provide a mounting for the gripper device (not shown). When it is desired to have full access down themoonpool 40 through thetension frame 158, the gripper device is removed from its location on the arms 162, and the arms pivoted to folded positions. This provides unrestricted passage through thetension frame 158, for example, for theBOP 44. - Turning now to
FIG. 28 , there is shown a perspective view of part of analternative support frame 104′. Like components of thesupport frame 104′ with thesupport frame 104 share the same reference numerals, with the addition of the suffix ′. Only the differences between theframes 104′ and 104 will be described herein in detail. -
FIG. 28 in fact shows atension frame 158′ of thesupport frame 104′. Thetension frame 158′ includes fourmain columns 164, each of which carries a respective inwardly extending lug orboss 166. Theselugs 166 are provided in place of the pivoting arms 162 of theframe 104, and provide mountings for atubing gripping assembly 168, which is shown in the perspective view ofFIG. 29 . The grippingassembly 168 includes areleasable gripper device 170, and is shown gripping and supporting tubing in the form of adrill collar 172. Thegripper device 170 is provided within acentral hub 174, from which four mountingarms 176 extend. Each of the mountingarms 176 include a pair of shapedwedges 178, which are shaped to engage around thelugs 166, such that the grippingassembly 168 can be releasably mounted on thelugs 166 and thus located within thetension frame 158′. The grippingassembly 168 can be selectively removed from its location within thetension frame 158′ when full clearance through thesupport frame 104′ is required, for example, for the passage of theBOP 44, simply by lifting theassembly 168 up off thelugs 166. Following passage of theBOP 44 through thesupport frame 104′, the grippingassembly 168 can be returned to its position within thetension frame 158′. - The
gripper device 170 includes a pair of hingedgripper arms 180, each of which carries a half-cylindrical slip ortubing grip 182. Thearms 180 are pivotally mounted to thehub 174 bypins 181, and are moved between disengaged and engaged positions byhydraulic pistons 184. Thearms 180 are shown inFIG. 29 in their engaged positions, where theslips 182 are seated in an upper end of a bore of a hollow mounting 186 which is located within thehub 174, defining a cylindrical collar. Theslips 182 are each shaped to engage an upset or shoulder on thedrill collar 172, for suspending a tubing string including thedrill collar 172 from thetension frame 158′. To release thedrill collar 172, thepistons 184 are actuated to rotate theslips 182 away from the upper end of the mounting 186 bore. It will be understood that this facilitates release of thetension frame 158′ from the tubing string, such that theframe 158′ may be stripped along the tubing for coupling further tubing sections, such as afurther drill collar 172. - Movement of the tension frames 158, 158′ is controlled using winches and tensioner devices according to the teachings of PCT/GB2006/001822. In an active compensation mode, movement of the
tension frame drillship 10. This is particularly important, for example, during lowering of a tubing string carrying theBOP 44 where thedrillship 10 is pitching, rolling and heaving under applied wind, wave and tidal loads. In a passive compensation mode, movement of thetension frame drillship 10, due to movement of thedrillship 10, is damped out using the winches and tensioner devices. - The rig assembly described herein, including the rig floor units 18-24,
transporter 26 andsupport frame 104 offers particular advantages in that the load of tubing/equipment can be transferred between theframe 104 and thedrillship 10 deck, facilitating changeout of the deck units. - Various modifications may be made to the foregoing without departing from the spirit and scope of the present invention.
- For example, the locking assemblies may comprise locking dogs, latches or the like. The locking assemblies may be hydraulically actuated, electro-mechanically or electrically actuated, or indeed a combination thereof.
- The rig floor units may each be configured to be releasably secured, locked or located relative to or within the rig floor receiving area. In this fashion, the transporter may be removed from the receiving area, if desired, following location of the rig floor unit within the rig floor receiving area.
- The translation devices may be adapted to transfer the rig floor units directly between their respective storage locations and the transporter.
- The transporter may be height adjustable for raising and lowering to a level of the unit storage locations.
- The tubing handling device may serve for picking up and/or supporting any desired type of tubing, which may be a length of casing, liner, riser, drill tubing, production tubing or any other tubing utilised in the industry. In place of electromagnets, any other suitable support may be provided.
- Where the rig assembly is for a surface facility, the surface facility may be an alternative vessel such as an FPSO or FSO, or a rig such as a semi-submersible, submersible or jack-up rig.
- The rig floor receiving area may be provided on or in a frame or support which may extend overboard.
- Any desired rig floor unit may be provided, including suitable support/deployment apparatus or equipment.
- The transporter may be configured to receive a plurality of selected rig floor units. Thus, for example, where the rig assembly comprises three or more rig floor units, the transporter may be configured to receive two units, for faster changeover.
- Instead of being self-driven, a separate drive system may be provided for moving the transporter/handling equipment.
Claims (39)
1. A rig assembly comprising:
a rig floor receiving area;
a plurality of movable rig floor units, each rig floor unit configured for location in the rig floor receiving area, to thereby define a rig floor of the rig assembly; and
a transporter configured to receive any one of the rig floor units, for transporting a selected one of the rig floor units from a storage area to the rig floor receiving area.
2. A rig assembly as claimed in claim 1 , wherein the transporter is also for transporting a rig floor unit from the rig floor receiving area to the storage area.
3. A rig assembly as claimed in claim 1 , wherein each rig floor unit is adapted for performing a different task.
4. A rig assembly as claimed in claim 3 , wherein each rig floor unit carries different equipment suited to the particular task to be performed.
5. A rig assembly as claimed in claim 1 , wherein the storage area comprises a plurality of rig floor storage locations, each configured to receive a respective rig floor unit.
6. A rig assembly as claimed in claim 1 , wherein the transporter is movable along a path extending between the storage area and the rig floor receiving area, for transporting the rig floor units between the storage area and the rig floor receiving area.
7. A rig assembly as claimed in claim 1 , wherein the rig floor units are each configured to be releasably secured to the transporter.
8. A rig assembly as claimed in claim 7 , wherein at least one of the rig floor units and the transporter comprise a locking assembly for securing the rig floor units relative to the transporter.
9. A rig assembly as claimed in claim 1 , wherein the transporter is configured to be releasably secured within the rig floor receiving area.
10. A rig assembly as claimed in claim 1 , wherein the transporter is configured to be secured to a support structure provided in the rig floor receiving area.
11. A rig assembly as claimed in claim 10 , wherein at least one of the transporter and the support structure comprise a locking assembly for securing the transporter in the receiving area.
12. A rig assembly as claimed in claim 1 , wherein the rig floor units are each configured to be releasably secured within the rig floor receiving area.
13. A rig assembly as claimed in claim 12 , wherein the rig floor units are each configured to be secured to a support structure provided in the rig floor receiving area.
14. A rig assembly as claimed in claim 13 , wherein at least one of the rig floor units and the support structure comprise a locking assembly for securing the rig floor units in the receiving area.
15. A rig assembly as claimed in claim 1 , further comprising a transfer system for transferring the rig floor units between a storage location within the storage area and the transporter.
16. A rig assembly as claimed in claim 15 , wherein the transfer system comprises a translation device for translating the rig floor units between their storage locations and the transporter.
17. A rig assembly as claimed in claim 15 , wherein the transfer system comprises a lift for raising and/or lowering the rig floor units between a level of the storage locations and a level of the transporter.
18. A rig assembly as claimed in claim 1 , wherein the transporter is shaped to straddle the rig floor units.
19. A rig assembly as claimed in claim 5 , wherein the transporter is height adjustable for raising and lowering to a level of the unit storage locations.
20. A rig assembly as claimed in claim 1 , further comprising tubing handling equipment coupled to and movable with the transporter.
21. A rig assembly as claimed in claim 20 , wherein the handling equipment comprises a tubing handling device for picking up and supporting a length of tubing, and for transferring the tubing on to the transporter.
22. A rig assembly as claimed in claim 1 , wherein the transporter is for transporting the selected rig floor unit to a location above a moonpool of a surface facility, for the deployment of equipment into the moonpool.
23. A rig assembly as claimed in claim 1 , wherein the rig floor receiving area is adapted to be provided on a frame extending overboard from a surface facility.
24. A rig assembly as claimed in claim 1 , wherein the rig floor units each comprise handling apparatus for handling equipment to be deployed from the rig floor.
25. A rig assembly as claimed in claim 1 , wherein the rig floor units are selected from the group comprising: a drill unit having a rotary drive for driving and rotating a string of tubing; a BOP unit for supporting a BOP; a coiled tubing injector unit for supporting a coiled tubing injector to be used for running coiled tubing; and a subsea shut-off device unit, for running a subsea shut-off device.
26. A rig assembly as claimed in claim 1 , wherein at least one of the rig floor units comprises an aperture through which equipment may be deployed.
27. A rig assembly as claimed in claim 1 , comprising a support for supporting a load of a tubing string during changeover of rig floor units.
28. A rig assembly as claimed in claim 1 , wherein the transporter is configured to receive a plurality of selected rig floor units simultaneously.
29. A rig assembly as claimed in claim 1 , wherein the transporter comprises a drive system for moving the transporter between the storage area and the rig floor receiving area.
30. A rig comprising a rig assembly, the rig assembly comprising
a rig floor receiving area;
a plurality of movable rig floor units, each rig floor unit configured for location in the rig floor receiving area, to thereby define a rig floor of the rig assembly; and
a transporter configured to receive any one of the rig floor units, for transporting a selected one of the rig floor units from a storage area to the rig floor receiving area.
31. A vessel comprising a rig, the rig comprising a rig assembly, the rig assembly comprising
a rig floor receiving area;
a plurality of movable rig floor units, each rig floor unit configured for location in the rig floor receiving area, to thereby define a rig floor of the rig assembly; and
a transporter configured to receive any one of the rig floor units, for transporting a selected one of the rig floor units from a storage area to the rig floor receiving area.
32. A method of providing a rig floor of a rig assembly, the method comprising the steps of:
providing a plurality of movable rig floor units, each rig floor unit configured for location in a rig floor receiving area of a rig assembly, the rig floor units located in a storage area on a rig;
selecting one of the rig floor units;
mounting the selected rig floor unit on a transporter configured to receive any one of the rig floor units;
transporting the selected rig floor unit from the storage area to the rig floor receiving area using the transporter; and
locating the selected rig floor unit in the rig floor receiving area, to thereby form a rig floor of the rig assembly.
33. A method as claimed in claim 32 , further comprising the steps of:
returning the selected rig floor unit from the rig floor receiving area to the storage area using the transporter;
selecting an alternative rig floor unit;
mounting the alternative rig floor unit on the transporter;
transporting the alternative rig floor unit from the storage area to the rig floor receiving area using the transporter; and
locating the alternative rig floor unit in the rig floor receiving area, to thereby form an alternative rig floor of the rig assembly.
34. A method as claimed in claim 32 , further comprising the steps of
performing an operation from the rig floor defined by the selected rig floor unit;
returning the unit to the storage area; and,
subsequent to locating the alternative unit in the receiving area, performing an operation from the alternative rig floor.
35. A method as claimed in claim 32 , further comprising securing the selected rig floor unit relative to the transporter, transporting the selected rig floor unit to the receiving area and then securing the transporter within the receiving area.
36. A method as claimed in claim 32 , further comprising securing the selected rig floor unit within the receiving area and moving the transporter away from the receiving area.
37. A method as claimed in claim 32 , further comprising storing the rig floor units in respective storage locations within the storage area, and transferring the units from their storage locations on to the transporter using a transfer system.
38. A movable rig floor unit, the rig floor unit configured for location in a rig floor receiving area of a rig assembly to thereby define a rig floor of the rig assembly, the rig floor unit further configured to be received in a transporter for transportation from a storage area to the rig floor receiving area.
39. A rig floor transporter, the transporter configured to receive any one of a plurality of rig floor units, for transporting a selected one of the rig floor units from a storage area to a rig floor receiving area of a rig assembly.
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
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GBGB0602946.6A GB0602946D0 (en) | 2006-02-14 | 2006-02-14 | Rig assembly |
GB0602946.6 | 2006-02-14 | ||
PCT/GB2007/000509 WO2007093787A1 (en) | 2006-02-14 | 2007-02-14 | Big assembly with movable rig floor units |
Publications (1)
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US20090151955A1 true US20090151955A1 (en) | 2009-06-18 |
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US12/279,401 Abandoned US20090151955A1 (en) | 2006-02-14 | 2007-02-14 | Big assembly with movable rig floor units |
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US20090025937A1 (en) * | 2007-07-20 | 2009-01-29 | Larry Robinson | System and Method to Facilitate Interventions from an Offshore Platform |
US20090129867A1 (en) * | 2007-11-20 | 2009-05-21 | Millheim Keith K | Self-Standing Riser and Buoyancy Device Deployment and Positioning System |
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US20110067887A1 (en) * | 2008-03-06 | 2011-03-24 | James Devin Moncus | Coiled Tubing Well Intervention System and Method |
WO2012146622A1 (en) | 2011-04-26 | 2012-11-01 | Ihc Holland Ie B.V. | Vessel comprising a moon pool and a hoisting arrangement and method of lowering items into the sea |
WO2012168428A1 (en) * | 2011-06-09 | 2012-12-13 | Aker Mh As | Deck arrangement on a vessel or platform for performing subsea operations |
US20140196948A1 (en) * | 2013-01-11 | 2014-07-17 | A.P. Moller - Maersk A/S | Drilling rig |
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CN106103266A (en) * | 2014-03-03 | 2016-11-09 | 伊特里克公司 | Offshore drilling ship |
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US10227824B2 (en) | 2014-11-20 | 2019-03-12 | Maersk Drilling A/S | Mobile offshore drilling unit, a method of using such a unit and a system comprising such a unit |
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GB0822604D0 (en) * | 2008-12-11 | 2009-01-21 | Geoprober Drilling Ltd | Assembly and method for supporting and deploying an object from a vessel |
AU2012230291B2 (en) * | 2011-03-22 | 2017-02-02 | Tfi Marine Limited | A mooring component having a smooth stress-strain response to high loads |
GB2531781A (en) * | 2014-10-30 | 2016-05-04 | Nat Oilwell Varco Norway As | Rig floor for a drilling rig |
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US8202023B2 (en) * | 2007-11-20 | 2012-06-19 | Millheim Keith K | Self-standing riser and buoyancy device deployment and positioning system |
US20110067887A1 (en) * | 2008-03-06 | 2011-03-24 | James Devin Moncus | Coiled Tubing Well Intervention System and Method |
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Also Published As
Publication number | Publication date |
---|---|
WO2007093787A1 (en) | 2007-08-23 |
GB0602946D0 (en) | 2006-03-22 |
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