US20160060993A1 - Subsea system delivery to seabed - Google Patents
Subsea system delivery to seabed Download PDFInfo
- Publication number
- US20160060993A1 US20160060993A1 US14/836,178 US201514836178A US2016060993A1 US 20160060993 A1 US20160060993 A1 US 20160060993A1 US 201514836178 A US201514836178 A US 201514836178A US 2016060993 A1 US2016060993 A1 US 2016060993A1
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- United States
- Prior art keywords
- tether
- frame structure
- seabed
- operations
- floating vessel
- 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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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0007—Equipment or details not covered by groups E21B15/00 - E21B40/00 for underwater installations
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
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- E—FIXED CONSTRUCTIONS
- E02—HYDRAULIC ENGINEERING; FOUNDATIONS; SOIL SHIFTING
- E02B—HYDRAULIC ENGINEERING
- E02B17/00—Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs or offshore constructions; Construction methods therefor
- E02B17/02—Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs or offshore constructions; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
-
- E—FIXED CONSTRUCTIONS
- E02—HYDRAULIC ENGINEERING; FOUNDATIONS; SOIL SHIFTING
- E02B—HYDRAULIC ENGINEERING
- E02B17/00—Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs or offshore constructions; Construction methods therefor
- E02B17/04—Equipment specially adapted for raising, lowering, or immobilising the working platform relative to the supporting construction
-
- E—FIXED CONSTRUCTIONS
- E02—HYDRAULIC ENGINEERING; FOUNDATIONS; SOIL SHIFTING
- E02B—HYDRAULIC ENGINEERING
- E02B17/00—Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs or offshore constructions; Construction methods therefor
- E02B17/04—Equipment specially adapted for raising, lowering, or immobilising the working platform relative to the supporting construction
- E02B17/08—Equipment specially adapted for raising, lowering, or immobilising the working platform relative to the supporting construction for raising or lowering
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/021—Devices for subsurface connecting or disconnecting by rotation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B19/002—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling
-
- E—FIXED CONSTRUCTIONS
- E02—HYDRAULIC ENGINEERING; FOUNDATIONS; SOIL SHIFTING
- E02B—HYDRAULIC ENGINEERING
- E02B17/00—Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs or offshore constructions; Construction methods therefor
- E02B17/02—Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs or offshore constructions; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto
- E02B17/021—Artificial islands mounted on piles or like supports, e.g. platforms on raisable legs or offshore constructions; Construction methods therefor placed by lowering the supporting construction to the bottom, e.g. with subsequent fixing thereto with relative movement between supporting construction and platform
Definitions
- Embodiments of the invention relate generally to operations involving subsea equipment and subsea handling of the equipment, which may be associated with hydrocarbon wells or pipelines.
- Deepwater oil and gas developments require wells and pipelines with various components disposed on the seabed. At times, the components require servicing including maintenance or capping a well. Underwater location of the components makes access difficult for supporting, carrying, removing, positioning, installing and/or operating necessary equipment at the seabed.
- a remote operated vehicle may work to carry out some tasks but has inherent limits for size and complexity of the functions to be performed.
- Currents may limit towing and positioning of buoyant structures employed in some prior approaches.
- Operators rely on conventional rigs, such as floating platforms or jack-up rigs with decks above water, for such operations as interventions.
- a blowout situation may require maintaining a safe distance away from the blowout limiting ability to position the rig above where desired. Presence of ice on the sea may also inhibit locating the rig as needed. Avoiding damage to surrounding pipelines and managing currents and possible turbulent flows of escaping hydrocarbons further complicates potential options for servicing the well or pipeline.
- a method of deploying a subsea system for seabed operations includes setting an anchor coupled to a tether thereby fixed to the seabed and coupling the tether to a frame structure carrying equipment to perform the operations. Deploying the frame structure with the equipment from a floating vessel connected to the tether while anchored enables moving the frame structure under water along the tether toward where anchored and the location for the seabed operations. The method further includes landing the frame structure on the seabed at the location of the operations.
- a subsea system for seabed operations includes a frame structure carrying equipment to perform the operations.
- a tether anchors to the seabed and couples to the frame structure for under water movement of the frame structure along the tether.
- a floating vessel connects to the tether for deployment of the frame structure with the equipment along the tether toward where anchored and the location for the seabed operations.
- FIG. 1 is a top view of a subsea structure disposed on a seabed in position for work on a well, according to embodiments of the invention.
- FIG. 2 is a side view of the subsea structure coupled to a tether, according to embodiments of the invention.
- FIG. 3 is a view of a floating vessel and an anchor handler used to pull the tether from the floating vessel, according to embodiments of the invention.
- FIG. 4 is a schematic depicting a path of the anchor handler around an exclusion zone to position the tether intersecting the exclusion zone, according to embodiments of the invention.
- FIG. 5 is a view of the floating vessel with the tether anchored for deployment of the subsea structure, according to embodiments of the invention.
- FIG. 6 is an enlarged view of an anchor next to the well and having a sheave through which the tether passes, according to embodiments of the invention.
- FIG. 7 is a side view of the subsea structure during deployment along the tether toward the well, according to embodiments of the invention.
- FIG. 8 is a view of a conduit deployment process utilizing the tether in carrying the conduit toward the well, according to embodiments of the invention.
- Embodiments of the invention relate to methods and systems for seabed operations, such as well intervention or capping, involving subsea equipment and subsea handling of the equipment, which may be associated with hydrocarbon wells or pipelines.
- a subsea system submerges during deployment and is landed on the seabed.
- the system may include a suspension assembly coupled to a frame structure for carrying equipment used in the operations.
- the deployment of the system may include deploying the frame structure with the equipment from a floating vessel connected to an anchored tether and moving the frame structure under water along the tether toward where anchored and the location for the seabed operations.
- FIG. 1 illustrates a subsea structure 100 disposed on a seabed in position for work on a well 102 , which is shown as an example only and may represent any subsea apparatus including pipelines requiring work.
- the structure 100 includes a frame 104 made of a steel structural open network with three jack-up legs 106 , buoyancy members 108 and a suspension assembly 110 . Given an exemplary C, U or V shape of the frame 104 , an open side of the frame 104 enables the structure 100 to be moved sideways as described further herein and be disposed around and receive wellhead components of the well 102 extending from the seabed.
- the suspension assembly 110 includes a first rail 112 parallel to a second rail 114 and a cross bar 116 spanning, and perpendicular to, the first and second rails 112 , 114 .
- a hoist 118 couples equipment 120 to the cross bar 116 for carrying the equipment 120 subsea with the structure 100 .
- Operations with the well 102 rely on the equipment 120 , such as a capping and/or containment stack to kill and/or divert flow from a blowout of the well 102 .
- the equipment 120 may include a rotary drive, a pump or wellbore tools, such as logging, perforating, plugging or stimulation tools.
- the suspension assembly 110 enables movement of the equipment 120 relative to the frame 104 , which remains stable and supported on the seabed once in position for the work on the well 102 .
- control of this movement comes from an operator sending commands from above to subsea via a direct umbilical line 122 to the structure 100 or a remote operated vehicle (ROV) having a communication line back to surface.
- the ROV may interface with the structure 100 for the operation of the structure 100 and may be carried subsea by latching to the structure 100 , for example, to limit problems with long distance travel of the ROV.
- An actuation mechanism such as a piston and cylinder or rack and pinion assembly, may move the cross bar 116 along the first and second rails 112 , 114 to facilitate movement of the equipment 120 in a first horizontal direction.
- Another actuation mechanism may move the hoist 118 along the cross bar 116 for moving the equipment 120 in a second horizontal direction perpendicular to the first horizontal direction.
- a further actuation mechanism of the hoist 118 may rotate the equipment 120 and/or provide angular motion from the hoist 118 relative to the frame 104 .
- a conveyance coupling 124 shown gripping a tether 126 at two locations attaches the frame 104 to the tether 126 for deployment as described herein.
- a polyethylene cable or DYNEEMA® rope provides the tether 126 to limit weight relative to steel cables, which could also present problems due to potential for steel cables cutting pipelines on the seabed.
- a secondary tether used in combination with the tether 126 may function like the tether 126 but attaches to an opposite side of the frame 104 from the coupling 124 in situations where sea current or tide conditions challenge deployment using the tether 126 alone.
- FIG. 2 shows the subsea structure 100 coupled to the tether 126 .
- An additional actuation mechanism 214 enables raising and lowering the rails 112 , 114 in a vertical direction relative to the frame 104 and thereby adjusts height of the equipment 120 above the seabed once the legs 106 are set in a lowered position.
- the legs 106 remain retracted upward as depicted during deployment to avoid the system 100 dragging the seabed or hitting pipelines crossed as being deployed.
- the conveyance coupling 124 grips the tether 126 pulled in order to move the structure 100 .
- Alternative arrangements may move the structure 100 with a tractor of the conveyance coupling 124 to advance along the tether 126 without movement of the tether 126 .
- the conveyance coupling 124 attaching the frame 104 to the tether 126 may also include a guide through which a returning portion 226 of a loop formed by the tether 126 slides and passes without being gripped.
- control of the buoyancy members 108 sets submerged weight of the structure 100 on the seabed.
- submerged means the structure 100 is completely covered by water.
- the legs 106 extend downward relative to the frame 104 jacking up the frame 104 over the seabed and supporting the submerged weight.
- FIG. 3 illustrates a floating vessel 300 and an anchor handler 302 used to pull the tether 126 from the floating vessel 300 in an initial stage for deployment of the structure 100 .
- An anchor 304 couples to the tether 126 and hooks, as may be assisted by an ROV, to the anchor handler 302 .
- the anchor handler 302 takes the anchor 304 to where desired for being dropped and set.
- FIG. 4 shows a path of the anchor handler 302 around an exclusion zone 400 .
- the exclusion zone 400 may represent an area considered unsafe for personnel or equipment due to a well blowout beneath the exclusion zone 400 .
- the exclusion zone 400 could also result from ice on the sea preventing access by the floating vessel 300 , provided the anchor 304 may be preset or the anchor handler 302 , e.g., a subsea vessel, may still be able to tow the anchor 304 to where desired.
- the anchor handler 302 and the tether 126 move through the path over time and are thus depicted at five distinct times for schematic representation as the anchor handler 302 moves further away from the floating vessel 300 .
- the tether 126 intersects the exclusion zone 400 without need to have the anchor handler 302 travel through the exclusion zone 400 .
- the floating vessel 300 at all times remains disposed at least 1000 meters in a horizontal direction away from above a location for the well 102 or the seabed operations during the deploying of the structure 100 and the operation at the well 102 using the structure 100 .
- FIG. 5 illustrates a subsequent step in the deployment of the structure 100 with the tether 126 anchored to the seabed 502 . Due to the final position of the anchor handler 302 , the anchor 304 sets proximate the well 102 . In some embodiments, the tether 126 through use of a clump weight 504 , for example, fixes to the seabed 502 at another location away from the anchor 304 and in a direction toward the floating vessel 300 .
- the floating vessel 300 includes a winch 506 to provide aforementioned pull of the tether 126 used to advance the structure 100 .
- the operator for the structure 100 and/or the ROV may reside on the floating vessel 300 .
- Controlling the buoyancy members 108 for submergence of the structure 100 may occur by trimming gas tanks forming the buoyancy members 108 .
- Variable lift provided by the buoyancy members 108 adjusts for weight of the equipment 120 needed to be carried.
- the winch 506 then takes in the return portion 226 of the tether 126 to cause an advancing portion of the tether 126 let out from another spool on the vessel 300 to advance toward the well 102 .
- the buoyancy members 108 may provide neutral buoyancy for the structure 100 or otherwise provide lift selected to maintain the structure 100 submerged and above the seabed without over countering the anchor 304 and weight 504 .
- FIG. 6 shows a sheave 600 through which the tether 126 passes proximate the well 102 and is an enlarged detailed view around the well 102 in FIG. 5 .
- a linker 602 such as a chain, connects the anchor 304 to the sheave 600 held off the seabed by a float 604 .
- the sheave 600 forms the point where the tether 126 loops back toward the vessel 300 as the return portion 226 and may be disposed between the anchor 304 and the well 102 opposite the well 102 from the vessel 300 .
- FIG. 7 illustrates the subsea structure 100 during deployment along the tether 126 toward the well 102 .
- Final intake of the structure 100 toward the well 102 may employ use of the ROV and a winch between the well 102 and the structure 100 .
- the operations on the seabed then commence with the structure 100 as desired.
- Some embodiments may also utilize the structure 100 to assist with making a conduit connection given the following description regarding conduit deployment.
- the structure 100 remains secured to the seabed 502 to enable leaving and abandoning the structure 100 without risks from drifting.
- recovery of the structure 100 may take place by reversing the deployment procedure and direction of pull to the tether 126 .
- Compressed air to the buoyancy members 108 may lift the structure 100 for the recovery.
- the structure 100 may release from the tether 126 and be picked up from straight above with conventional techniques since risk preventing deployment access is gone due to the operations performed.
- FIG. 8 shows a conduit deployment process from a service vessel 800 utilizing the tether 126 to carry a conduit 802 toward the well 102 .
- Buoyancy modules 804 counter weight of the conduit 802 .
- the conduit 802 may connect to the containment stack added to the well 102 to recover escaping hydrocarbons and provide a flow pathway to a vessel capable of handling/processing/storing hydrocarbons.
- a ROV 806 clamps the conduit 802 to the tether 126 .
- the floating vessel 300 then pulls the tether 126 to advance the tether 126 toward the well 102 , as described with respect to the structure 100 .
- the conduit 802 upon being taken along the tether 126 to the well 102 may be connected to the well 102 using the ROV 806 .
Abstract
Methods and systems relate to seabed operations, such as well intervention or capping, involving subsea equipment and subsea handling of the equipment, which may be associated with hydrocarbon wells or pipelines. A subsea system submerges during deployment and is landed on the seabed. The system may include a suspension assembly coupled to a frame structure for carrying equipment used in the operations. The deployment of the system may include deploying the frame structure with the equipment from a floating vessel connected to an anchored tether and moving the frame structure under water along the tether toward where anchored and the location for the seabed operations.
Description
- This application is a non-provisional application which claims benefit under 35 USC §119(e) to U.S. Provisional Application Ser. No. 62/045,110 filed Sep. 3, 2014, entitled “SUBSEA SYSTEM DELIVERY TO SEABED,” which is incorporated herein in its entirety.
- None.
- Embodiments of the invention relate generally to operations involving subsea equipment and subsea handling of the equipment, which may be associated with hydrocarbon wells or pipelines.
- Deepwater oil and gas developments require wells and pipelines with various components disposed on the seabed. At times, the components require servicing including maintenance or capping a well. Underwater location of the components makes access difficult for supporting, carrying, removing, positioning, installing and/or operating necessary equipment at the seabed.
- A remote operated vehicle (ROV) may work to carry out some tasks but has inherent limits for size and complexity of the functions to be performed. Currents may limit towing and positioning of buoyant structures employed in some prior approaches. Operators rely on conventional rigs, such as floating platforms or jack-up rigs with decks above water, for such operations as interventions.
- However, a blowout situation may require maintaining a safe distance away from the blowout limiting ability to position the rig above where desired. Presence of ice on the sea may also inhibit locating the rig as needed. Avoiding damage to surrounding pipelines and managing currents and possible turbulent flows of escaping hydrocarbons further complicates potential options for servicing the well or pipeline.
- Therefore, a need exists for systems and methods to enable subsea handling of equipment associated with a hydrocarbon well or pipeline located on a seabed.
- For one embodiment, a method of deploying a subsea system for seabed operations includes setting an anchor coupled to a tether thereby fixed to the seabed and coupling the tether to a frame structure carrying equipment to perform the operations. Deploying the frame structure with the equipment from a floating vessel connected to the tether while anchored enables moving the frame structure under water along the tether toward where anchored and the location for the seabed operations. The method further includes landing the frame structure on the seabed at the location of the operations.
- In one embodiment, a subsea system for seabed operations includes a frame structure carrying equipment to perform the operations. A tether anchors to the seabed and couples to the frame structure for under water movement of the frame structure along the tether. A floating vessel connects to the tether for deployment of the frame structure with the equipment along the tether toward where anchored and the location for the seabed operations.
- A more complete understanding of the present invention and benefits thereof may be acquired by referring to the following description taken in conjunction with the accompanying drawings.
-
FIG. 1 is a top view of a subsea structure disposed on a seabed in position for work on a well, according to embodiments of the invention. -
FIG. 2 is a side view of the subsea structure coupled to a tether, according to embodiments of the invention. -
FIG. 3 is a view of a floating vessel and an anchor handler used to pull the tether from the floating vessel, according to embodiments of the invention. -
FIG. 4 is a schematic depicting a path of the anchor handler around an exclusion zone to position the tether intersecting the exclusion zone, according to embodiments of the invention. -
FIG. 5 is a view of the floating vessel with the tether anchored for deployment of the subsea structure, according to embodiments of the invention. -
FIG. 6 is an enlarged view of an anchor next to the well and having a sheave through which the tether passes, according to embodiments of the invention. -
FIG. 7 is a side view of the subsea structure during deployment along the tether toward the well, according to embodiments of the invention. -
FIG. 8 is a view of a conduit deployment process utilizing the tether in carrying the conduit toward the well, according to embodiments of the invention. - Turning now to the detailed description of the preferred arrangement or arrangements of the present invention, it should be understood that the inventive features and concepts may be manifested in other arrangements and that the scope of the invention is not limited to the embodiments described or illustrated. The scope of the invention is intended only to be limited by the scope of the claims that follow.
- Embodiments of the invention relate to methods and systems for seabed operations, such as well intervention or capping, involving subsea equipment and subsea handling of the equipment, which may be associated with hydrocarbon wells or pipelines. A subsea system submerges during deployment and is landed on the seabed. The system may include a suspension assembly coupled to a frame structure for carrying equipment used in the operations. The deployment of the system may include deploying the frame structure with the equipment from a floating vessel connected to an anchored tether and moving the frame structure under water along the tether toward where anchored and the location for the seabed operations.
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FIG. 1 illustrates asubsea structure 100 disposed on a seabed in position for work on awell 102, which is shown as an example only and may represent any subsea apparatus including pipelines requiring work. Thestructure 100 includes aframe 104 made of a steel structural open network with three jack-uplegs 106,buoyancy members 108 and asuspension assembly 110. Given an exemplary C, U or V shape of theframe 104, an open side of theframe 104 enables thestructure 100 to be moved sideways as described further herein and be disposed around and receive wellhead components of thewell 102 extending from the seabed. - For some embodiments, the
suspension assembly 110 includes afirst rail 112 parallel to asecond rail 114 and across bar 116 spanning, and perpendicular to, the first andsecond rails hoist 118couples equipment 120 to thecross bar 116 for carrying theequipment 120 subsea with thestructure 100. Operations with the well 102 rely on theequipment 120, such as a capping and/or containment stack to kill and/or divert flow from a blowout of thewell 102. For other examples of installation, removal or repair work to be performed, theequipment 120 may include a rotary drive, a pump or wellbore tools, such as logging, perforating, plugging or stimulation tools. - The
suspension assembly 110 enables movement of theequipment 120 relative to theframe 104, which remains stable and supported on the seabed once in position for the work on thewell 102. As with any operation of thestructure 100, control of this movement comes from an operator sending commands from above to subsea via a directumbilical line 122 to thestructure 100 or a remote operated vehicle (ROV) having a communication line back to surface. The ROV may interface with thestructure 100 for the operation of thestructure 100 and may be carried subsea by latching to thestructure 100, for example, to limit problems with long distance travel of the ROV. - An actuation mechanism, such as a piston and cylinder or rack and pinion assembly, may move the
cross bar 116 along the first andsecond rails equipment 120 in a first horizontal direction. Another actuation mechanism may move thehoist 118 along thecross bar 116 for moving theequipment 120 in a second horizontal direction perpendicular to the first horizontal direction. A further actuation mechanism of thehoist 118 may rotate theequipment 120 and/or provide angular motion from thehoist 118 relative to theframe 104. - A
conveyance coupling 124 shown gripping atether 126 at two locations attaches theframe 104 to thetether 126 for deployment as described herein. In some embodiments, a polyethylene cable or DYNEEMA® rope provides thetether 126 to limit weight relative to steel cables, which could also present problems due to potential for steel cables cutting pipelines on the seabed. A secondary tether used in combination with thetether 126 may function like thetether 126 but attaches to an opposite side of theframe 104 from thecoupling 124 in situations where sea current or tide conditions challenge deployment using thetether 126 alone. -
FIG. 2 shows thesubsea structure 100 coupled to thetether 126. Anadditional actuation mechanism 214 enables raising and lowering therails frame 104 and thereby adjusts height of theequipment 120 above the seabed once thelegs 106 are set in a lowered position. Thelegs 106 remain retracted upward as depicted during deployment to avoid thesystem 100 dragging the seabed or hitting pipelines crossed as being deployed. - During deployment the
structure 100 moves along thetether 126. In some embodiments, theconveyance coupling 124 grips thetether 126 pulled in order to move thestructure 100. Alternative arrangements may move thestructure 100 with a tractor of theconveyance coupling 124 to advance along thetether 126 without movement of thetether 126. Theconveyance coupling 124 attaching theframe 104 to thetether 126 may also include a guide through which a returningportion 226 of a loop formed by thetether 126 slides and passes without being gripped. - Once in position at the well 102 as depicted in
FIG. 1 , control of thebuoyancy members 108, e.g., by gas release, sets submerged weight of thestructure 100 on the seabed. As used herein, submerged means thestructure 100 is completely covered by water. Thelegs 106 extend downward relative to theframe 104 jacking up theframe 104 over the seabed and supporting the submerged weight. -
FIG. 3 illustrates a floatingvessel 300 and ananchor handler 302 used to pull thetether 126 from the floatingvessel 300 in an initial stage for deployment of thestructure 100. Ananchor 304 couples to thetether 126 and hooks, as may be assisted by an ROV, to theanchor handler 302. Theanchor handler 302 takes theanchor 304 to where desired for being dropped and set. -
FIG. 4 shows a path of theanchor handler 302 around anexclusion zone 400. Theexclusion zone 400 may represent an area considered unsafe for personnel or equipment due to a well blowout beneath theexclusion zone 400. Theexclusion zone 400 could also result from ice on the sea preventing access by the floatingvessel 300, provided theanchor 304 may be preset or theanchor handler 302, e.g., a subsea vessel, may still be able to tow theanchor 304 to where desired. - The
anchor handler 302 and thetether 126 move through the path over time and are thus depicted at five distinct times for schematic representation as theanchor handler 302 moves further away from the floatingvessel 300. In a final position of theanchor handler 302, thetether 126 intersects theexclusion zone 400 without need to have theanchor handler 302 travel through theexclusion zone 400. For some embodiments, the floatingvessel 300 at all times remains disposed at least 1000 meters in a horizontal direction away from above a location for the well 102 or the seabed operations during the deploying of thestructure 100 and the operation at the well 102 using thestructure 100. -
FIG. 5 illustrates a subsequent step in the deployment of thestructure 100 with thetether 126 anchored to theseabed 502. Due to the final position of theanchor handler 302, theanchor 304 sets proximate thewell 102. In some embodiments, thetether 126 through use of aclump weight 504, for example, fixes to theseabed 502 at another location away from theanchor 304 and in a direction toward the floatingvessel 300. - The floating
vessel 300 includes awinch 506 to provide aforementioned pull of thetether 126 used to advance thestructure 100. In addition, the operator for thestructure 100 and/or the ROV may reside on the floatingvessel 300. Once thetether 126 is set as depicted, thestructure 100, which is towed by thevessel 300 or a tug or is lifted off a side of thevessel 300, is submerged and attaches to thetether 126. - Controlling the
buoyancy members 108 for submergence of thestructure 100 may occur by trimming gas tanks forming thebuoyancy members 108. Variable lift provided by thebuoyancy members 108 adjusts for weight of theequipment 120 needed to be carried. Thewinch 506 then takes in thereturn portion 226 of thetether 126 to cause an advancing portion of thetether 126 let out from another spool on thevessel 300 to advance toward thewell 102. While thestructure 100 is traveling underwater in a horizontal direction toward the well 102, thebuoyancy members 108 may provide neutral buoyancy for thestructure 100 or otherwise provide lift selected to maintain thestructure 100 submerged and above the seabed without over countering theanchor 304 andweight 504. -
FIG. 6 shows asheave 600 through which thetether 126 passes proximate the well 102 and is an enlarged detailed view around the well 102 inFIG. 5 . Alinker 602, such as a chain, connects theanchor 304 to thesheave 600 held off the seabed by afloat 604. Thesheave 600 forms the point where thetether 126 loops back toward thevessel 300 as thereturn portion 226 and may be disposed between theanchor 304 and the well 102 opposite the well 102 from thevessel 300. -
FIG. 7 illustrates thesubsea structure 100 during deployment along thetether 126 toward thewell 102. Final intake of thestructure 100 toward the well 102 may employ use of the ROV and a winch between the well 102 and thestructure 100. The operations on the seabed then commence with thestructure 100 as desired. - Some embodiments may also utilize the
structure 100 to assist with making a conduit connection given the following description regarding conduit deployment. After use, thestructure 100 remains secured to theseabed 502 to enable leaving and abandoning thestructure 100 without risks from drifting. However, recovery of thestructure 100 may take place by reversing the deployment procedure and direction of pull to thetether 126. Compressed air to thebuoyancy members 108 may lift thestructure 100 for the recovery. In some embodiments, thestructure 100 may release from thetether 126 and be picked up from straight above with conventional techniques since risk preventing deployment access is gone due to the operations performed. -
FIG. 8 shows a conduit deployment process from aservice vessel 800 utilizing thetether 126 to carry aconduit 802 toward thewell 102. Buoyancy modules 804 counter weight of theconduit 802. Theconduit 802 may connect to the containment stack added to the well 102 to recover escaping hydrocarbons and provide a flow pathway to a vessel capable of handling/processing/storing hydrocarbons. - For the deployment process, a
ROV 806 clamps theconduit 802 to thetether 126. The floatingvessel 300 then pulls thetether 126 to advance thetether 126 toward the well 102, as described with respect to thestructure 100. Theconduit 802 upon being taken along thetether 126 to the well 102 may be connected to the well 102 using theROV 806. - In closing, it should be noted that the discussion of any reference is not an admission that it is prior art to the present invention, especially any reference that may have a publication date after the priority date of this application. At the same time, each and every claim below is hereby incorporated into this detailed description or specification as additional embodiments of the present invention.
- Although the systems and processes described herein have been described in detail, it should be understood that various changes, substitutions, and alterations can be made without departing from the spirit and scope of the invention as defined by the following claims. Those skilled in the art may be able to study the preferred embodiments and identify other ways to practice the invention that are not exactly as described herein. It is the intent of the inventors that variations and equivalents of the invention are within the scope of the claims while the description, abstract and drawings are not to be used to limit the scope of the invention. The invention is specifically intended to be as broad as the claims below and their equivalents.
Claims (20)
1. A method of deploying a subsea system for seabed operations, comprising:
setting an anchor coupled to a tether thereby fixed to the seabed,
coupling the tether to a frame structure carrying equipment to perform the operations;
deploying the frame structure with the equipment from a floating vessel connected to the tether while anchored;
moving the frame structure under water along the tether toward where anchored and the location for the seabed operations; and
landing the frame structure on the seabed at the location of the operations.
2. The method according to claim 1 , wherein the floating vessel is disposed at least 1000 meters in a horizontal direction away from above a location for the seabed operations during the deploying of the frame structure.
3. The method according to claim 1 , wherein the moving of the frame structure is by advancing the tether with a winch on the floating vessel while the frame structure grips the tether.
4. The method according to claim 1 , wherein the moving of the frame structure is by advancing the tether in a loop while the frame structure grips an advancing portion of the loop and a returning portion of the loop slides through a guide on the frame structure.
5. The method according to claim 1 , wherein the moving of the frame structure includes pulling the tether looped through a sheave coupled to the anchor creating a return portion of the tether going back to the floating vessel from the sheave and an opposite advancing portion of the tether gripped by the frame structure.
6. The method according to claim 1 , further comprising pulling the anchor from the floating vessel around an exclusion zone with an anchor handler to a point where the anchor is to be released for the setting with the tether intersecting the exclusion zone.
7. The method according to claim 1 , further comprising fixing the tether to the seabed at another location away from the anchor in a direction of the floating vessel.
8. The method according to claim 1 , further comprising moving a conduit along the tether toward where anchored by advancing the tether in a loop while the conduit is connected to an advancing portion of the loop.
9. The method according to claim 1 , wherein the landing of the frame structure includes controlling ballasts to set weight of the frame structure on the seabed.
10. The method according to claim 1 , wherein the equipment includes at least one of a well capping stack and a well containment stack installed on a well as part of the operations.
11. A subsea system for seabed operations, comprising:
a frame structure carrying equipment to perform the operations;
a tether anchored to the seabed and coupled to the frame structure for under water movement of the frame structure along the tether; and
a floating vessel connected to the tether for deployment of the frame structure with the equipment along the tether toward where anchored and the location for the seabed operations.
12. The subsea system according to claim 11 , wherein the floating vessel connected to the tether is disposed at least 1000 meters in a horizontal direction away from above a location for the seabed operations.
13. The subsea system according to claim 11 , wherein the frame structure is moveable by advancing the tether with a winch on the floating vessel while the frame structure grips the tether.
14. The subsea system according to claim 11 , wherein the frame structure is moveable by advancing the tether in a loop while the frame structure grips an advancing portion of the loop and a returning portion of the loop slides through a guide on the frame structure.
15. The subsea system according to claim 11 , wherein the frame structure is moveable by pulling the tether looped through a sheave coupled to the anchor creating a return portion of the tether going back to the floating vessel from the sheave and an opposite advancing portion of the tether gripped by the frame structure.
16. The subsea system according to claim 11 , further comprising an anchor handler to pull the anchor from the floating vessel in a desired path around an exclusion zone.
17. The subsea system according to claim 11 , wherein the tether is anchored to the seabed at first and second locations located toward the seabed operations and toward the floating vessel with respect to one another.
18. The subsea system according to claim 11 , further comprising a conduit moveable along the tether toward where anchored by advancing the tether in a loop while the conduit is connected to an advancing portion of the loop.
19. The subsea system according to claim 11 , wherein the frame structure includes ballasts controllable to set weight of the frame structure on the seabed.
20. The subsea system according to claim 11 , wherein the equipment includes at least one of a well capping stack and a well containment stack for installation on a well as part of the operations.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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PCT/US2015/046987 WO2016036563A1 (en) | 2014-09-03 | 2015-08-26 | Subsea system delivery to seabed |
US14/836,178 US20160060993A1 (en) | 2014-09-03 | 2015-08-26 | Subsea system delivery to seabed |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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US201462045110P | 2014-09-03 | 2014-09-03 | |
US14/836,178 US20160060993A1 (en) | 2014-09-03 | 2015-08-26 | Subsea system delivery to seabed |
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US20160060993A1 true US20160060993A1 (en) | 2016-03-03 |
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US14/836,178 Abandoned US20160060993A1 (en) | 2014-09-03 | 2015-08-26 | Subsea system delivery to seabed |
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US (1) | US20160060993A1 (en) |
WO (1) | WO2016036563A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2018044174A1 (en) * | 2016-09-01 | 2018-03-08 | Statoil Petroleum As | Marine installation |
US10781670B1 (en) * | 2019-10-10 | 2020-09-22 | Trendsetter Engineering, Inc. | Process for non-vertical installation and removal of a subsea structure |
Families Citing this family (2)
Publication number | Priority date | Publication date | Assignee | Title |
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CN105967089B (en) * | 2016-06-13 | 2017-05-10 | 广东精铟海洋工程股份有限公司 | Double-acting continuous lifting system for offshore platform and lifting method thereof |
US11078661B2 (en) | 2019-10-04 | 2021-08-03 | Timothy William Canby | Rolling block restraint connector having an improved linkage assembly |
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US8801327B2 (en) * | 2011-08-04 | 2014-08-12 | Halo Maritime Defense Systems, Inc. | Marine ropeway |
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NO304958B1 (en) * | 1997-06-05 | 1999-03-08 | Alsthom Cge Alcatel | Device for installing an elongated element |
WO2003062042A1 (en) * | 2002-01-24 | 2003-07-31 | Stolt Offshore Limited | Method and apparatus for deploying articles in deep waters |
BRPI0403295B1 (en) * | 2004-08-17 | 2015-08-25 | Petroleo Brasileiro Sa | Subsea oil production system, installation method and use |
US8695711B2 (en) * | 2010-06-04 | 2014-04-15 | J. Ray Mcdermott, S.A. | Subsea well containment and intervention apparatus |
EP2511996B1 (en) * | 2011-04-15 | 2014-05-14 | Optoplan AS | Subsea cable installation unit |
-
2015
- 2015-08-26 US US14/836,178 patent/US20160060993A1/en not_active Abandoned
- 2015-08-26 WO PCT/US2015/046987 patent/WO2016036563A1/en active Application Filing
Patent Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
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US8801327B2 (en) * | 2011-08-04 | 2014-08-12 | Halo Maritime Defense Systems, Inc. | Marine ropeway |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2018044174A1 (en) * | 2016-09-01 | 2018-03-08 | Statoil Petroleum As | Marine installation |
US20190195026A1 (en) * | 2016-09-01 | 2019-06-27 | Equinor Energy As | Marine installation |
US11015398B2 (en) * | 2016-09-01 | 2021-05-25 | Equinor Energy As | Marine installation |
AU2017320458B2 (en) * | 2016-09-01 | 2022-10-20 | Equinor Energy As | Marine installation |
US10781670B1 (en) * | 2019-10-10 | 2020-09-22 | Trendsetter Engineering, Inc. | Process for non-vertical installation and removal of a subsea structure |
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WO2016036563A1 (en) | 2016-03-10 |
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