CA2544362A1 - System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber - Google Patents
System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber Download PDFInfo
- Publication number
- CA2544362A1 CA2544362A1 CA002544362A CA2544362A CA2544362A1 CA 2544362 A1 CA2544362 A1 CA 2544362A1 CA 002544362 A CA002544362 A CA 002544362A CA 2544362 A CA2544362 A CA 2544362A CA 2544362 A1 CA2544362 A1 CA 2544362A1
- Authority
- CA
- Canada
- Prior art keywords
- fluid flow
- wellhead
- well
- transferring
- control system
- 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
Links
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 46
- 238000000034 method Methods 0.000 title claims abstract description 34
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 26
- 239000012530 fluid Substances 0.000 claims description 60
- 230000000977 initiatory effect Effects 0.000 claims 3
- 238000005553 drilling Methods 0.000 abstract description 21
- 238000002955 isolation Methods 0.000 abstract description 13
- 238000004891 communication Methods 0.000 abstract description 11
- 239000003381 stabilizer Substances 0.000 abstract description 7
- 238000004873 anchoring Methods 0.000 abstract description 5
- 238000005516 engineering process Methods 0.000 description 5
- 238000012423 maintenance Methods 0.000 description 5
- 238000011084 recovery Methods 0.000 description 5
- 238000012360 testing method Methods 0.000 description 5
- 239000011800 void material Substances 0.000 description 4
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 230000004044 response Effects 0.000 description 2
- 206010063659 Aversion Diseases 0.000 description 1
- 238000007792 addition Methods 0.000 description 1
- 230000000712 assembly Effects 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 230000002950 deficient Effects 0.000 description 1
- 230000001934 delay Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000009189 diving Effects 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 231100001261 hazardous Toxicity 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 230000009885 systemic effect Effects 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
Classifications
-
- 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
- E21B17/01—Risers
- E21B17/012—Risers with buoyancy elements
-
- 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
- E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
- E21B17/07—Telescoping joints for varying drill string lengths; Shock absorbers
-
- 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
-
- 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
- E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
- E21B33/064—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers specially adapted for underwater well heads
-
- 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
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
- Revetment (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
A system and method of establishing an offshore exploration and production system is disclosed, in which a well casing is disposed in communication with an adjustable buoyancy chamber and a well hole bored into the floor of a body of water.
A lower connecting member joins the well casing and the chamber, and an upper connecting member joins the adjustable buoyancy chamber and a well terminal member. The chamber's adjustable buoyancy enables an operator to vary the height or depth of the well terminal member, and to vary the vertical tension imparted to drilling and production strings throughout exploration and production operations.
Also disclosed is a system and method of adjusting the height or depth of a wellhead while associated vertical and lateral forces remain approximately constant. A
variety of well isolation members, lateral stabilizers and anchoring means, as well as several methods of practicing the invention, are also disclosed.
A lower connecting member joins the well casing and the chamber, and an upper connecting member joins the adjustable buoyancy chamber and a well terminal member. The chamber's adjustable buoyancy enables an operator to vary the height or depth of the well terminal member, and to vary the vertical tension imparted to drilling and production strings throughout exploration and production operations.
Also disclosed is a system and method of adjusting the height or depth of a wellhead while associated vertical and lateral forces remain approximately constant. A
variety of well isolation members, lateral stabilizers and anchoring means, as well as several methods of practicing the invention, are also disclosed.
Description
SYSTEM AND METHOD OF INSTALLING AND MAINTAINING AN
OFFSHORE EXPLORATION AND PRODUCTION SYSTEM HAVING
AN ADJUSTABLE BUOYANCY CHAMBER
FIELD OF THE INVENTION
The present invention relates generally to oil and gas exploration and production, and in a specific, non-limiting embodiment, to a system and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber.
BACKGROUND OF THE INVENTION
Innumerable systems and methods have been employed in efforts to find and recover hydrocarbon reserves around the world. At first, such efforts were limited to land operations involving simple but effective drilling methods that satisfactorily recovered reserves from large, productive fields. As the number of known producing fields dwindled, however, it became necessary to search in ever more remote locales, and to move offshore, in the search for new resources. Eventually, sophisticated drilling systems and advanced signal processing techniques enabled oiI and gas companies to search virtually anywhere in the world for recoverable hydrocarbons.
Initially, deepwater exploration and production efforts consisted of expensive, large scale drilling operations supported by tanker storage and transportation systems, due primarily to the fact that most offshore drilling sites are associated with difficult and hazardous sea conditions, and thus large scale operations provided the most stable and cost-effective manner in which to search for and recover hydrocarbon reserves. A
major drawback to the large-scale paradigm, however, is that explorers and producers have little financial incentive to work smaller reserves, since potential financial recovery is generally offset by the lengthy delay between exploration and production (approximately 3 to 7 years) and the large capital investment required for conventional platforms and related drilling and production equipment.
Moreover, complex regulatory controls and industry-wide risk aversion have led to standardization, leaving operators with few opportunities to significantly alter the prevailing paradigm. As a result, offshore drilling operations have traditionally been burdened with long delays between investment and profit, excessive cost overruns, and slow, inflexible recovery strategies dictated by the operational environment.
More recently, deepwater sites have been found in which much of the danger and instability present in such operations is avoided. For example, off the coast of West Africa, Indonesia and Brazil, potential drilling sites have been identified where surrounding seas and weather conditions are relatively mild and calm in comparison to other, more volatile sites such as the Gulf of Mexico and the North Sea.
These recently discovered sites tend to have favorable producing characteristics, yield positive exploration success rates, and admit to production using simple drilling techniques similar to those employed in dry land or near-shore operations.
However, since lognormal distributions of recoverable reserves tend to be spread over a large number of small fields, each of which yield less than would normally be required in order to justify the expense of a conventional large-scale operation, these regions have to date been underexplored and underproduced relative to its potential. Consequently, many potentially productive smaller fields have already been discovered, but remain undeveloped due to economic considerations. In response, explorers and producers have adapted their technologies in an attempt to achieve greater profitability by downsizing the scale of operations and otherwise reducing expense, so that recovery from smaller fields makes more financial sense, and the delay between investment and profitability is reduced.
For example, in published Patent Application No. US 2001/0047869 Al and a number of related pending applications and patents issued to Hopper et al., various methods of drilling deepwater wells are provided in which adjustments to the drilling system can be made so as to ensure a better recovery rate than would otherwise be possible with traditional fixed-well technologies. However, the Hopper system cannot be adjusted during completion, testing and production of the well, and is especially ineffective in instances where the well bore starts at a mud line in a vertical position. Tl~e Hopper system also fails to support a variety of different surface loads, and is therefore self limiting with respect to the flexibility drillers desire during actual operations.
In U.S. Letters Patent No. 4,223,737 to O'Reilly, a method is disclosed in which the problems associated with traditional, vertically oriented operations are addressed. The method of O'Reilly involves laying out a number of interconnected, horizontally disposed pipes in a string just above the sea floor (along with a blow out preventer and other necessary equipment), and then using a drive or a remote operated vehicle to force the string horizontally into the drilling medium. The O'Reilly system, however, is inflexible in that it fails to admit to practice while the well is being completed and tested. Moreover, the method utterly fails to contemplate functionality during production and workover operations. In short, the O'Reilly reference is helpful only during the initial stages of drilling a well, and would therefore not be looked to as a systemic solution for establishing and maintaining a deepwater exploration and production operation.
Other offshore operators have attempted to solve the problems associated with deepwater drilling by effectively "raising the floor" of an underwater well by disposing a submerged wellhead above a self contained, rigid framework of pipe casing that is tensioned by means of a gas filled, buoyant chamber. For example, as seen in prior U. S. Letters Patent No. 6,196,322 B 1 to Magnussen, the Atlantis Deepwater Technology Holding Group has developed an artificial buoyant seabed (ABS) system, which is essentially a gas filled buoyancy chamber deployed in conjunction with one or more segments of pipe casing disposed at a depth of between 600 and 900 feet beneath the surface of a body of water. After the ABS
wellhead is fitted with a blowout preventer during drilling, or with a production tree during production, buoyancy and tension are imparted by the ABS to a lower connecting member and all internal casings. The BOP and riser (during drilling) and production tree (during production), are supported by the lifting force of the buoyancy chamber.
Offset of the wellhead is reasonably controlled by means of vertical tension resulting from the buoyancy of the ABS.
The Atlantis ABS system is deficient, however, in several practical respects.
For example, the '322 Magnussen patent specifically limits deployment of the buoyancy chamber to environments where the influence of surface waves is effectively negligible, i.e., at a depth of more than about 500 feet beneath the surface.
Those of ordinary skill in the art will appreciate that deployment at such depths is an expensive and relatively risk-laden solution, given that installation and maintenance can only be carried out by deep sea divers or remotely operated vehicles, and the fact that a relatively extensive transport system must still be installed between the top of the buoyancy chamber and the bottom of an associated recovery vessel in order to initiate production from the well.
The Magnussen system also fails to contemplate multiple anchoring systems, even in instances where problematic drilling environments are likely to be encountered. Moreover, the system lacks any control means for controlling adjustment of either vertical tension or wellhead depth during production and workover operations, and expressly teaches away from the use of lateral stabilizers that could enable the wellhead to be deployed in shallower waters subject to stronger tidal and wave forces.
Thus, there is plainly a widespread need for a system and method of disposing an offshore wellhead in a manner such that drillers can adjust both the depth of a wellhead and the vertical tension applied to associated pipe casing throughout the duration of exploration and production operations. There is also a need for an adjustable buoyancy chamber system capable of maintaining approximately constant vertical tension on an associated drilling or production string, and adjusting either the height of a wellhead at any time during exploration and production by releasing additional lengths of tension line from a buoyancy chamber height adjustment member. There is also a need for an offshore exploration and production system that flexibly admits to use in connection with both deepwater and shallow target horizons, without necessarily being configured to conform to any particular operational depth.
OFFSHORE EXPLORATION AND PRODUCTION SYSTEM HAVING
AN ADJUSTABLE BUOYANCY CHAMBER
FIELD OF THE INVENTION
The present invention relates generally to oil and gas exploration and production, and in a specific, non-limiting embodiment, to a system and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber.
BACKGROUND OF THE INVENTION
Innumerable systems and methods have been employed in efforts to find and recover hydrocarbon reserves around the world. At first, such efforts were limited to land operations involving simple but effective drilling methods that satisfactorily recovered reserves from large, productive fields. As the number of known producing fields dwindled, however, it became necessary to search in ever more remote locales, and to move offshore, in the search for new resources. Eventually, sophisticated drilling systems and advanced signal processing techniques enabled oiI and gas companies to search virtually anywhere in the world for recoverable hydrocarbons.
Initially, deepwater exploration and production efforts consisted of expensive, large scale drilling operations supported by tanker storage and transportation systems, due primarily to the fact that most offshore drilling sites are associated with difficult and hazardous sea conditions, and thus large scale operations provided the most stable and cost-effective manner in which to search for and recover hydrocarbon reserves. A
major drawback to the large-scale paradigm, however, is that explorers and producers have little financial incentive to work smaller reserves, since potential financial recovery is generally offset by the lengthy delay between exploration and production (approximately 3 to 7 years) and the large capital investment required for conventional platforms and related drilling and production equipment.
Moreover, complex regulatory controls and industry-wide risk aversion have led to standardization, leaving operators with few opportunities to significantly alter the prevailing paradigm. As a result, offshore drilling operations have traditionally been burdened with long delays between investment and profit, excessive cost overruns, and slow, inflexible recovery strategies dictated by the operational environment.
More recently, deepwater sites have been found in which much of the danger and instability present in such operations is avoided. For example, off the coast of West Africa, Indonesia and Brazil, potential drilling sites have been identified where surrounding seas and weather conditions are relatively mild and calm in comparison to other, more volatile sites such as the Gulf of Mexico and the North Sea.
These recently discovered sites tend to have favorable producing characteristics, yield positive exploration success rates, and admit to production using simple drilling techniques similar to those employed in dry land or near-shore operations.
However, since lognormal distributions of recoverable reserves tend to be spread over a large number of small fields, each of which yield less than would normally be required in order to justify the expense of a conventional large-scale operation, these regions have to date been underexplored and underproduced relative to its potential. Consequently, many potentially productive smaller fields have already been discovered, but remain undeveloped due to economic considerations. In response, explorers and producers have adapted their technologies in an attempt to achieve greater profitability by downsizing the scale of operations and otherwise reducing expense, so that recovery from smaller fields makes more financial sense, and the delay between investment and profitability is reduced.
For example, in published Patent Application No. US 2001/0047869 Al and a number of related pending applications and patents issued to Hopper et al., various methods of drilling deepwater wells are provided in which adjustments to the drilling system can be made so as to ensure a better recovery rate than would otherwise be possible with traditional fixed-well technologies. However, the Hopper system cannot be adjusted during completion, testing and production of the well, and is especially ineffective in instances where the well bore starts at a mud line in a vertical position. Tl~e Hopper system also fails to support a variety of different surface loads, and is therefore self limiting with respect to the flexibility drillers desire during actual operations.
In U.S. Letters Patent No. 4,223,737 to O'Reilly, a method is disclosed in which the problems associated with traditional, vertically oriented operations are addressed. The method of O'Reilly involves laying out a number of interconnected, horizontally disposed pipes in a string just above the sea floor (along with a blow out preventer and other necessary equipment), and then using a drive or a remote operated vehicle to force the string horizontally into the drilling medium. The O'Reilly system, however, is inflexible in that it fails to admit to practice while the well is being completed and tested. Moreover, the method utterly fails to contemplate functionality during production and workover operations. In short, the O'Reilly reference is helpful only during the initial stages of drilling a well, and would therefore not be looked to as a systemic solution for establishing and maintaining a deepwater exploration and production operation.
Other offshore operators have attempted to solve the problems associated with deepwater drilling by effectively "raising the floor" of an underwater well by disposing a submerged wellhead above a self contained, rigid framework of pipe casing that is tensioned by means of a gas filled, buoyant chamber. For example, as seen in prior U. S. Letters Patent No. 6,196,322 B 1 to Magnussen, the Atlantis Deepwater Technology Holding Group has developed an artificial buoyant seabed (ABS) system, which is essentially a gas filled buoyancy chamber deployed in conjunction with one or more segments of pipe casing disposed at a depth of between 600 and 900 feet beneath the surface of a body of water. After the ABS
wellhead is fitted with a blowout preventer during drilling, or with a production tree during production, buoyancy and tension are imparted by the ABS to a lower connecting member and all internal casings. The BOP and riser (during drilling) and production tree (during production), are supported by the lifting force of the buoyancy chamber.
Offset of the wellhead is reasonably controlled by means of vertical tension resulting from the buoyancy of the ABS.
The Atlantis ABS system is deficient, however, in several practical respects.
For example, the '322 Magnussen patent specifically limits deployment of the buoyancy chamber to environments where the influence of surface waves is effectively negligible, i.e., at a depth of more than about 500 feet beneath the surface.
Those of ordinary skill in the art will appreciate that deployment at such depths is an expensive and relatively risk-laden solution, given that installation and maintenance can only be carried out by deep sea divers or remotely operated vehicles, and the fact that a relatively extensive transport system must still be installed between the top of the buoyancy chamber and the bottom of an associated recovery vessel in order to initiate production from the well.
The Magnussen system also fails to contemplate multiple anchoring systems, even in instances where problematic drilling environments are likely to be encountered. Moreover, the system lacks any control means for controlling adjustment of either vertical tension or wellhead depth during production and workover operations, and expressly teaches away from the use of lateral stabilizers that could enable the wellhead to be deployed in shallower waters subject to stronger tidal and wave forces.
Thus, there is plainly a widespread need for a system and method of disposing an offshore wellhead in a manner such that drillers can adjust both the depth of a wellhead and the vertical tension applied to associated pipe casing throughout the duration of exploration and production operations. There is also a need for an adjustable buoyancy chamber system capable of maintaining approximately constant vertical tension on an associated drilling or production string, and adjusting either the height of a wellhead at any time during exploration and production by releasing additional lengths of tension line from a buoyancy chamber height adjustment member. There is also a need for an offshore exploration and production system that flexibly admits to use in connection with both deepwater and shallow target horizons, without necessarily being configured to conform to any particular operational depth.
BRIEF DESCRIPTION OF THE DRAWINGS
Figure 1 is a side view of an offshore exploration and production system in which an adjustable buoyancy chamber is employed to adjust the height or depth of an associated well terminal member.
Figures 2A and 2B are side views of an offshore exploration and production system, in which lateral and vertical forces on an adjustable buoyancy chamber are held approximately constant while the height of an associated well terminal member is adjusted by releasing additional lengths of tension line.
SUMMARY OF THE INVENTION
A system and method of establishing an offshore exploration and production system is provided, in which a well casing is disposed in communication with an adjustable buoyancy chamber and a well hole bored into the floor of a body of water.
A lower connecting member joins the well casing and the chamber, and an upper connecting member joins the adjustable buoyancy chamber and a well terminal member. The chamber's adjustable buoyancy enables an operator to vary the height or depth of the well terminal member, and to vary the vertical tension imparted to drilling and production strings throughout exploration and production operations.
Also provided is a system and method of adjusting the height or depth of a wellhead while associated vertical and lateral forces remain approximately constant. A
variety of well isolation members, lateral stabilizers and anchoring means, as well as several methods of practicing the invention, are also disclosed.
Figure 1 is a side view of an offshore exploration and production system in which an adjustable buoyancy chamber is employed to adjust the height or depth of an associated well terminal member.
Figures 2A and 2B are side views of an offshore exploration and production system, in which lateral and vertical forces on an adjustable buoyancy chamber are held approximately constant while the height of an associated well terminal member is adjusted by releasing additional lengths of tension line.
SUMMARY OF THE INVENTION
A system and method of establishing an offshore exploration and production system is provided, in which a well casing is disposed in communication with an adjustable buoyancy chamber and a well hole bored into the floor of a body of water.
A lower connecting member joins the well casing and the chamber, and an upper connecting member joins the adjustable buoyancy chamber and a well terminal member. The chamber's adjustable buoyancy enables an operator to vary the height or depth of the well terminal member, and to vary the vertical tension imparted to drilling and production strings throughout exploration and production operations.
Also provided is a system and method of adjusting the height or depth of a wellhead while associated vertical and lateral forces remain approximately constant. A
variety of well isolation members, lateral stabilizers and anchoring means, as well as several methods of practicing the invention, are also disclosed.
DETAILED DESCRIPTION
Referring now to the specific, non-limiting embodiment of the invention depicted in Figure 1, an offshore exploration and production system is provided, comprising a well casing 2 installed in communication with a submerged well 1 and an adjustable buoyancy chamber 9, wherein a lower connecting member 5 is disposed between the well casing and the adjustable buoyancy chamber. In a presently preferred embodiment, the well 1 is accessed from above by means of a well hole 3 that has been bored into an associated sea floor surface. In a typical embodiment, a well casing 2 is set into the hole in a firm and secure manner, and then cemented into place using known downhole technology. In other embodiments, a well casing is securely set into the well hole 3, and a fluid transport member, such as a smaller-diameter pipe or pipe casing, is inserted into well casing 2. Once a desired fit has been achieved, the outer surface of the fluid transport member is cemented or set with a packer to the inner surface of the well casing. Those of ordinary skill in the art will appreciate that while the embodiment described above refers to but a single well, the offshore exploration and production system disclosed herein can be readily adapted to simultaneously work multiple neighboring wells without departing from the scope or spirit of the invention.
According to a one embodiment, a well isolation member 4 is disposed between well casing 2 and a lower connecting member 5. In some embodiments, well isolation member 4 comprises one or more ball valves, which, if lower connecting member 5 is removed, can be closed so that the well is effectively shut in. In further embodiments, well isolation member 4 comprises a blowout preventer or a shear ram that can be maintained in either an open or closed position in order to provide access to, or to instead shut in, the contents of well 1.
In other embodiments, lower connecting member 5 further comprises one or more receiving members disposed to receive an attachment member disposed on well isolation member 4. In an alternative embodiment, lower connecting member 5 comprises an attachment member for attaching said lower connecting member 5 to a receiving member disposed on well isolation member 4. Methods and means of securely fastening lower connecting member 5 to well isolation member 4 are known to those of ordinary skill in the art, and may comprise one or more of a wide variety of fastening techniques, e.g., hydraulic couplers, various nut and bolt assemblies, welded joints, pressure fittings (either with or without gaskets), swaging, etc., without departing from the scope or spirit of the present invention.
Likewise, lower connecting member 5 may comprise any known connecting means appropriate for the specific application contemplated by operators. For example, in various embodiments, lower connecting member 5 comprises one or more of segments of riser, riser pipe, and/or pipe casing. In some embodiments, lower connecting member 5 comprises a concentric arrangement, for example, a fluid transport member having a smaller outer diameter than the inner diameter of a pipe casing in which the fluid transport member is housed.
In further embodiments, lower connecting member 5 is disposed in communication with one or more lateral stabilizers 6, which, when deployed in conjunction a plurality of tension lines 7, effectively controls horizontal offset of the system. By utilizing the buoyant forces of adjustable buoyancy chamber 9, lower connecting member 5 is drawn taut and held in a stable position.
Referring now to the specific, non-limiting embodiment of the invention depicted in Figure 1, an offshore exploration and production system is provided, comprising a well casing 2 installed in communication with a submerged well 1 and an adjustable buoyancy chamber 9, wherein a lower connecting member 5 is disposed between the well casing and the adjustable buoyancy chamber. In a presently preferred embodiment, the well 1 is accessed from above by means of a well hole 3 that has been bored into an associated sea floor surface. In a typical embodiment, a well casing 2 is set into the hole in a firm and secure manner, and then cemented into place using known downhole technology. In other embodiments, a well casing is securely set into the well hole 3, and a fluid transport member, such as a smaller-diameter pipe or pipe casing, is inserted into well casing 2. Once a desired fit has been achieved, the outer surface of the fluid transport member is cemented or set with a packer to the inner surface of the well casing. Those of ordinary skill in the art will appreciate that while the embodiment described above refers to but a single well, the offshore exploration and production system disclosed herein can be readily adapted to simultaneously work multiple neighboring wells without departing from the scope or spirit of the invention.
According to a one embodiment, a well isolation member 4 is disposed between well casing 2 and a lower connecting member 5. In some embodiments, well isolation member 4 comprises one or more ball valves, which, if lower connecting member 5 is removed, can be closed so that the well is effectively shut in. In further embodiments, well isolation member 4 comprises a blowout preventer or a shear ram that can be maintained in either an open or closed position in order to provide access to, or to instead shut in, the contents of well 1.
In other embodiments, lower connecting member 5 further comprises one or more receiving members disposed to receive an attachment member disposed on well isolation member 4. In an alternative embodiment, lower connecting member 5 comprises an attachment member for attaching said lower connecting member 5 to a receiving member disposed on well isolation member 4. Methods and means of securely fastening lower connecting member 5 to well isolation member 4 are known to those of ordinary skill in the art, and may comprise one or more of a wide variety of fastening techniques, e.g., hydraulic couplers, various nut and bolt assemblies, welded joints, pressure fittings (either with or without gaskets), swaging, etc., without departing from the scope or spirit of the present invention.
Likewise, lower connecting member 5 may comprise any known connecting means appropriate for the specific application contemplated by operators. For example, in various embodiments, lower connecting member 5 comprises one or more of segments of riser, riser pipe, and/or pipe casing. In some embodiments, lower connecting member 5 comprises a concentric arrangement, for example, a fluid transport member having a smaller outer diameter than the inner diameter of a pipe casing in which the fluid transport member is housed.
In further embodiments, lower connecting member 5 is disposed in communication with one or more lateral stabilizers 6, which, when deployed in conjunction a plurality of tension lines 7, effectively controls horizontal offset of the system. By utilizing the buoyant forces of adjustable buoyancy chamber 9, lower connecting member 5 is drawn taut and held in a stable position.
In an alternative embodiment, one or more stabilizers 6 control horizontal offset of lower connecting member 5, and the height or depth of an associated well terminal member 14 is adjusted by varying the length of upper connecting member 12. In some embodiments, the vertical tension of lower connecting member 5 is held approximately constant while the height or depth of well terminal member 14 is adjusted. In further embodiments, the height or depth of well terminal member 14 is held approximately constant, while the vertical tension imparted by adjustable buoyancy chamber 9 on lower connecting member 5 is adjusted. In still further embodiments, the height or depth of well terminal member 14 and the vertical tension applied to lower connecting member 5 are held approximately constant, while lateral adjustments are performed using lateral stabilizer 6 and one or more of tension lines 7.
In certain embodiments, one or more lateral tension lines 7 are individually adjustable, whereas in other embodiments, the tension lines 7 are collectively adjustable. In further embodiments, one or more tension lines 7 are both individually and collectively adjustable. In still further embodiments, the one or more lateral stabilizers 6 are disposed in communication with a tension measuring means, so that a fixed or predetermined amount of lateral tension can be applied to lower connecting member 5 in order to better control system offset. In some embodiments, the tension lines 7 are anchored to the sea floor by means of an anchoring member 8, for example, a suction type anchor, or alternatively, a mechanical or conventional deadweight type anchor.
In a presently preferred embodiment, adjustable buoyancy chamber 9 is approximately annular in shape, so that lower connecting member 5 can be passed through a void longitudinally disposed in a central portion of the device. In further embodiments, adjustable buoyancy chamber 9 further comprises a plurality of inner chambers. In still further embodiments, each of the chambers is independently operable, and different amounts of air or gas (or another fluid) are disposed in the chambers to provide greater adjustable buoyancy control. In one example embodiment, adjustable buoyancy chamber 9 further comprises a fluid ballast that can be ejected from the chamber, thereby achieving greater chamber buoyancy and lending additional vertical tension to lower connecting member 5. Those of ordinary skill in the art will appreciate that many appropriate fluid ballast can be used to increase or retard buoyancy; for example, compressed air is an appropriate fluid that is both inexpensive and readily available.
In some embodiments, adjustable buoyancy chamber 9 further comprises a ballast input valve, so that a fluid ballast can be injected into the chamber from an external source, for example, through an umbilical line run to the surface or a remote operated vehicle, so that an operator can deliver a supply of compressed gas to the chamber via the umbilical, thereby adjusting buoyancy characteristics as desired. In other embodiments, the fluid input valve is disposed in communication with one or more pumps or compressors, so that the fluid ballast is delivered to the chamber under greater pressure, thereby effecting the desired change in buoyancy more quickly and reliably.
In other embodiments, adjustable buoyancy chamber 9 further comprises a ballast output valve, so that ballast can be discharged from the chamber. In instances where air or another light fluid is injected into the chamber while water or another heavy liquid is discharged, the chamber will become more buoyant and increase vertical tension on lower connecting member 5. Conversely, if water or another heavy liquid is injected into the chamber while air is bled out, the chamber will lose buoyancy, thereby lessening vertical tension on lower connecting member 5.
In alternative embodiments, the ballast output valve is disposed in communication with one or more pumps or compressors, so that ballast is ejected from the chamber in a more reliable and controlled manner. In some embodiments, the ballast output valve is disposed in communication with an umbilical, so that ballast ejected from the chamber can be recovered or recycled at the surface.
In any event, a principle advantage of the present invention is that adjustments to the chamber's buoyancy and tensioning properties, and the ability to control the height of the well terminal member 14, can be performed at any time during either exploration or production, due to the various ballast input and output control means disposed about the body of the chamber.
In further embodiments, adjustable buoyancy chamber 9 is further disposed in communication with one or more tension lines 10 provided to anchor the adjustable buoyancy chamber to the sea floor. As before, tension lines 10 are anchored to the sea floor using known anchoring technology, for example, suction anchors or dead weight type anchors, etc. The one or more tension lines 10 can also provide additional lateral stability for the system, especially during operations in which more than one well is being worked. In one embodiment, the one or more tension lines 10 are run from the adjustable buoyancy chamber 9 to the surface, and then moored to other buoys or a surface vessel, etc., so that even greater lateral tension and system stability are achieved. In further embodiments, the tension lines 10 are individually adjustable, whereas in other embodiments, the tension lines 10 are collectively controlled. In still further embodiments, the one or more tension lines 10 are both individually and collectively adjustable.
In one example embodiment, adjustable buoyancy chamber 9 is disposed in communication with a vertical tension receiving member 11. In another embodiment, the vertical tension receiving member 11 is equipped with a tension measuring means (e.g., a load cell, strain gauge, etc.), so that vertical tension applied to lower connecting member 5 is imparted in a more controlled and efficient manner. In another embodiment, the buoyant force applied to tension receiving member 11 is adjusted by varying the lengths of tension lines 10, while the buoyancy of adjustable buoyancy chamber 9 is held approximately constant. In a further embodiment, the buoyancy of adjustable buoyancy chamber 9 is controlled by means of one or more individually selectable ballast exhaust ports disposed about the body of the chamber, which vent excess ballast fluid to the surrounding sea. In still further embodiments, the open or closed state of the ballast exhaust ports are individually controlled using port controllers known to those of ordinary skill in the art (e.g., plugs, seacocks, etc.) In a presently preferred embodiment, the system is disposed so that a well terminal member 14 installed above buoyancy chamber 9 is submerged to a depth at which maintenance and testing can be carried out by SCUBA divers using lightweight, flexible diving equipment, for example, at a depth of about 100 to 300 feet beneath the surface. In some embodiments, the well terminal member 14 is submerged only to the minimum depth necessary to provide topside access to the hulls of various surface vessels servicing the well, meaning that well terminal member 14 could also be disposed at a much shallower depth, for example, a depth of about 50 to 100 feet. In alternative embodiments, well terminal member 14 is disposed at depths of less than 50 feet, or greater than 300 feet, depending upon the actual conditions surrounding operations. In still further embodiments, well terminal member 14 is disposed either at the surface or above the surface of the water, and a blowout preventer or a production nee is installed by workers operating aboard a service platform or surface vessel. This "damp tree" model avoids the need to assemble long subsurface riser stacks, as would generally be required during deepwater operations. Moreover, disposing the well terminal member at or near the surface also permits testing and maintenance to be carried out by SCUBA divers or surface crews, without the need for expensive and time-consuming remote operated vehicle operations.
In some embodiments, well terminal member 14 further comprises either a blowout preventer or a production tree. In a presently preferred embodiment, however, well terminal member 14 further comprises a combined blowout preventer and production tree assembly configured so as to facilitate simplified well intervention operations.
In some embodiments, lower connecting member 5 terminates within the void formed in a center portion of the annular chamber 9, at which point an upper connecting member 12 becomes the means by which fluids are transported up to the wellhead. In other embodiments, lower connecting member 5 does not terminate within the void formed in a center portion of the annular chamber, but instead runs through the void and is subsequently employed as an upper connecting member 12 disposed between the chamber and the wellhead. In other embodiments, a vertical tension receiving member 11 is disposed between the buoyancy chamber 9 and upper connecting member 12, so that the chamber's buoyant forces are transferred to the vertical tension receiving means 11, thereby applying vertical tension to the drilling or production string extended below the chamber.
In further embodiments, upper connecting member 12 further comprises a well isolation member 13, e.g., one or more ball valves or blowout preventers, used to halt fluid flow in the event that well terminal member 14 is either removed or disabled, for example, during testing and maintenance operations. Those of ordinary skill in the art will appreciate that the precise types and exact locations of isolation valves employed in the system are variable and flexible, the only real requirement being that the valves are capable of allowing or preventing fluid flow from the well 1 during periods in which testing or maintenance, or even an emergency safety condition, are present.
For example, well terminal member 14 can be equipped with a production tree so that a production hose disposed on a surface vessel can be attached to the system and production can commence. Alternatively, well terminal member 14 can terminate in a blowout preventer, so that the well will not blow out during drilling operations.
In other embodiments, well terminal member 14 terminates in a combined production tree and blowout preventer assembly to facilitate simplified well intervention operations.
Turning now to the specific, non-limiting embodiments of the invention depicted in Figures 2A and 2B, a system and method of establishing a height-variable well terminal member is provided, comprising a lower fluid transport pipe 21, an inner well casing 22, an outer well casing 23, and a wellhead 24. In some embodiments, a well isolation member 25 is disposed above the wellhead 24, so that the well can be closed off or shut in if desired.
In the example embodiment depicted in Figure 2A, well isolation member 25 further comprises one or more ball valves that can be adjustably opened or closed as desired by an operator. A lower connecting member 26 having one or more interior seals 27 and an interior polished bore 28 houses a fluid transport member 29 such that the height of fluid transport member 29 is variably adjustable within a body portion of lower connecting member 26 in response to vertical lifting forces imparted by adjustable buoyancy chamber 30. Various lengths of pipe define the height of an upper connecting member disposed between the buoyancy chamber 30 and a well terminal member 36. In some embodiments, an upper well isolation member 35, such as a ball valve or a blowout preventer, is disposed in communication with the upper connecting member between buoyancy chamber 30 and well terminal member 36.
In some embodiments, the system is moored to the sea floor using one or more mooring lines 31 connected to a first vertical tension receiving means 32a, while buoyancy chamber 30 is raised or lowered by either spooling-out or reeling-in lengths of one or more tension lines 37 disposed between a second vertical tension receiving means 32b and a chamber height adjustment means 33. As adjustable buoyancy chamber 30 rises, vertical tension is applied to vertical tension receiving member 34, which in turn lifts well terminal member 36 up toward the surface.
As seen in the example embodiment depicted in Figure 2B, the height of both the well terminal member 36 and fluid transport member 29 are vertically adjusted by increasing the length of tension lines 37 using chamber height adjustment means 33, even as vertical and lateral tension on mooring lines 31 and tension lines 37 remains approximately constant. In one embodiment, vertical tension on lower connecting member 26 is also kept approximately constant during this process, since fluid transport member 29 is moved vertically within a body portion of lower connecting member 26. In another embodiment, a second, lower adjustable buoyancy chamber is added to the system to maintain tension on lower connecting member 26, while the height of the well terminal member is adjusted as described above.
The foregoing specification is provided for illustrative purposes only, and is not intended to describe all possible aspects of the present invention.
Moreover, while the invention has been shown and described in detail with respect to several exemplary embodiments, those of ordinary skill in the pertinent arts will appreciate that minor changes to the description, and various other modifications, omissions and additions may also be made without departing from either the spirit or scope thereof.
In certain embodiments, one or more lateral tension lines 7 are individually adjustable, whereas in other embodiments, the tension lines 7 are collectively adjustable. In further embodiments, one or more tension lines 7 are both individually and collectively adjustable. In still further embodiments, the one or more lateral stabilizers 6 are disposed in communication with a tension measuring means, so that a fixed or predetermined amount of lateral tension can be applied to lower connecting member 5 in order to better control system offset. In some embodiments, the tension lines 7 are anchored to the sea floor by means of an anchoring member 8, for example, a suction type anchor, or alternatively, a mechanical or conventional deadweight type anchor.
In a presently preferred embodiment, adjustable buoyancy chamber 9 is approximately annular in shape, so that lower connecting member 5 can be passed through a void longitudinally disposed in a central portion of the device. In further embodiments, adjustable buoyancy chamber 9 further comprises a plurality of inner chambers. In still further embodiments, each of the chambers is independently operable, and different amounts of air or gas (or another fluid) are disposed in the chambers to provide greater adjustable buoyancy control. In one example embodiment, adjustable buoyancy chamber 9 further comprises a fluid ballast that can be ejected from the chamber, thereby achieving greater chamber buoyancy and lending additional vertical tension to lower connecting member 5. Those of ordinary skill in the art will appreciate that many appropriate fluid ballast can be used to increase or retard buoyancy; for example, compressed air is an appropriate fluid that is both inexpensive and readily available.
In some embodiments, adjustable buoyancy chamber 9 further comprises a ballast input valve, so that a fluid ballast can be injected into the chamber from an external source, for example, through an umbilical line run to the surface or a remote operated vehicle, so that an operator can deliver a supply of compressed gas to the chamber via the umbilical, thereby adjusting buoyancy characteristics as desired. In other embodiments, the fluid input valve is disposed in communication with one or more pumps or compressors, so that the fluid ballast is delivered to the chamber under greater pressure, thereby effecting the desired change in buoyancy more quickly and reliably.
In other embodiments, adjustable buoyancy chamber 9 further comprises a ballast output valve, so that ballast can be discharged from the chamber. In instances where air or another light fluid is injected into the chamber while water or another heavy liquid is discharged, the chamber will become more buoyant and increase vertical tension on lower connecting member 5. Conversely, if water or another heavy liquid is injected into the chamber while air is bled out, the chamber will lose buoyancy, thereby lessening vertical tension on lower connecting member 5.
In alternative embodiments, the ballast output valve is disposed in communication with one or more pumps or compressors, so that ballast is ejected from the chamber in a more reliable and controlled manner. In some embodiments, the ballast output valve is disposed in communication with an umbilical, so that ballast ejected from the chamber can be recovered or recycled at the surface.
In any event, a principle advantage of the present invention is that adjustments to the chamber's buoyancy and tensioning properties, and the ability to control the height of the well terminal member 14, can be performed at any time during either exploration or production, due to the various ballast input and output control means disposed about the body of the chamber.
In further embodiments, adjustable buoyancy chamber 9 is further disposed in communication with one or more tension lines 10 provided to anchor the adjustable buoyancy chamber to the sea floor. As before, tension lines 10 are anchored to the sea floor using known anchoring technology, for example, suction anchors or dead weight type anchors, etc. The one or more tension lines 10 can also provide additional lateral stability for the system, especially during operations in which more than one well is being worked. In one embodiment, the one or more tension lines 10 are run from the adjustable buoyancy chamber 9 to the surface, and then moored to other buoys or a surface vessel, etc., so that even greater lateral tension and system stability are achieved. In further embodiments, the tension lines 10 are individually adjustable, whereas in other embodiments, the tension lines 10 are collectively controlled. In still further embodiments, the one or more tension lines 10 are both individually and collectively adjustable.
In one example embodiment, adjustable buoyancy chamber 9 is disposed in communication with a vertical tension receiving member 11. In another embodiment, the vertical tension receiving member 11 is equipped with a tension measuring means (e.g., a load cell, strain gauge, etc.), so that vertical tension applied to lower connecting member 5 is imparted in a more controlled and efficient manner. In another embodiment, the buoyant force applied to tension receiving member 11 is adjusted by varying the lengths of tension lines 10, while the buoyancy of adjustable buoyancy chamber 9 is held approximately constant. In a further embodiment, the buoyancy of adjustable buoyancy chamber 9 is controlled by means of one or more individually selectable ballast exhaust ports disposed about the body of the chamber, which vent excess ballast fluid to the surrounding sea. In still further embodiments, the open or closed state of the ballast exhaust ports are individually controlled using port controllers known to those of ordinary skill in the art (e.g., plugs, seacocks, etc.) In a presently preferred embodiment, the system is disposed so that a well terminal member 14 installed above buoyancy chamber 9 is submerged to a depth at which maintenance and testing can be carried out by SCUBA divers using lightweight, flexible diving equipment, for example, at a depth of about 100 to 300 feet beneath the surface. In some embodiments, the well terminal member 14 is submerged only to the minimum depth necessary to provide topside access to the hulls of various surface vessels servicing the well, meaning that well terminal member 14 could also be disposed at a much shallower depth, for example, a depth of about 50 to 100 feet. In alternative embodiments, well terminal member 14 is disposed at depths of less than 50 feet, or greater than 300 feet, depending upon the actual conditions surrounding operations. In still further embodiments, well terminal member 14 is disposed either at the surface or above the surface of the water, and a blowout preventer or a production nee is installed by workers operating aboard a service platform or surface vessel. This "damp tree" model avoids the need to assemble long subsurface riser stacks, as would generally be required during deepwater operations. Moreover, disposing the well terminal member at or near the surface also permits testing and maintenance to be carried out by SCUBA divers or surface crews, without the need for expensive and time-consuming remote operated vehicle operations.
In some embodiments, well terminal member 14 further comprises either a blowout preventer or a production tree. In a presently preferred embodiment, however, well terminal member 14 further comprises a combined blowout preventer and production tree assembly configured so as to facilitate simplified well intervention operations.
In some embodiments, lower connecting member 5 terminates within the void formed in a center portion of the annular chamber 9, at which point an upper connecting member 12 becomes the means by which fluids are transported up to the wellhead. In other embodiments, lower connecting member 5 does not terminate within the void formed in a center portion of the annular chamber, but instead runs through the void and is subsequently employed as an upper connecting member 12 disposed between the chamber and the wellhead. In other embodiments, a vertical tension receiving member 11 is disposed between the buoyancy chamber 9 and upper connecting member 12, so that the chamber's buoyant forces are transferred to the vertical tension receiving means 11, thereby applying vertical tension to the drilling or production string extended below the chamber.
In further embodiments, upper connecting member 12 further comprises a well isolation member 13, e.g., one or more ball valves or blowout preventers, used to halt fluid flow in the event that well terminal member 14 is either removed or disabled, for example, during testing and maintenance operations. Those of ordinary skill in the art will appreciate that the precise types and exact locations of isolation valves employed in the system are variable and flexible, the only real requirement being that the valves are capable of allowing or preventing fluid flow from the well 1 during periods in which testing or maintenance, or even an emergency safety condition, are present.
For example, well terminal member 14 can be equipped with a production tree so that a production hose disposed on a surface vessel can be attached to the system and production can commence. Alternatively, well terminal member 14 can terminate in a blowout preventer, so that the well will not blow out during drilling operations.
In other embodiments, well terminal member 14 terminates in a combined production tree and blowout preventer assembly to facilitate simplified well intervention operations.
Turning now to the specific, non-limiting embodiments of the invention depicted in Figures 2A and 2B, a system and method of establishing a height-variable well terminal member is provided, comprising a lower fluid transport pipe 21, an inner well casing 22, an outer well casing 23, and a wellhead 24. In some embodiments, a well isolation member 25 is disposed above the wellhead 24, so that the well can be closed off or shut in if desired.
In the example embodiment depicted in Figure 2A, well isolation member 25 further comprises one or more ball valves that can be adjustably opened or closed as desired by an operator. A lower connecting member 26 having one or more interior seals 27 and an interior polished bore 28 houses a fluid transport member 29 such that the height of fluid transport member 29 is variably adjustable within a body portion of lower connecting member 26 in response to vertical lifting forces imparted by adjustable buoyancy chamber 30. Various lengths of pipe define the height of an upper connecting member disposed between the buoyancy chamber 30 and a well terminal member 36. In some embodiments, an upper well isolation member 35, such as a ball valve or a blowout preventer, is disposed in communication with the upper connecting member between buoyancy chamber 30 and well terminal member 36.
In some embodiments, the system is moored to the sea floor using one or more mooring lines 31 connected to a first vertical tension receiving means 32a, while buoyancy chamber 30 is raised or lowered by either spooling-out or reeling-in lengths of one or more tension lines 37 disposed between a second vertical tension receiving means 32b and a chamber height adjustment means 33. As adjustable buoyancy chamber 30 rises, vertical tension is applied to vertical tension receiving member 34, which in turn lifts well terminal member 36 up toward the surface.
As seen in the example embodiment depicted in Figure 2B, the height of both the well terminal member 36 and fluid transport member 29 are vertically adjusted by increasing the length of tension lines 37 using chamber height adjustment means 33, even as vertical and lateral tension on mooring lines 31 and tension lines 37 remains approximately constant. In one embodiment, vertical tension on lower connecting member 26 is also kept approximately constant during this process, since fluid transport member 29 is moved vertically within a body portion of lower connecting member 26. In another embodiment, a second, lower adjustable buoyancy chamber is added to the system to maintain tension on lower connecting member 26, while the height of the well terminal member is adjusted as described above.
The foregoing specification is provided for illustrative purposes only, and is not intended to describe all possible aspects of the present invention.
Moreover, while the invention has been shown and described in detail with respect to several exemplary embodiments, those of ordinary skill in the pertinent arts will appreciate that minor changes to the description, and various other modifications, omissions and additions may also be made without departing from either the spirit or scope thereof.
Claims (15)
1. A method of transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water to a fluid retention vessel disposed nearer the surface of said body of water, said method comprising:
buoyantly supporting a well control system within said body of water;
positioning said well control system through said subsurface wellhead;
initiating a fluid flow from said subsurface wellhead;
receiving said fluid flow from said subsurface wellhead using a fluid flow receiving means;
transferring said fluid flow from said fluid flow receiving means to said well control system; and transferring said fluid flow from said well control system to said fluid retention vessel.
buoyantly supporting a well control system within said body of water;
positioning said well control system through said subsurface wellhead;
initiating a fluid flow from said subsurface wellhead;
receiving said fluid flow from said subsurface wellhead using a fluid flow receiving means;
transferring said fluid flow from said fluid flow receiving means to said well control system; and transferring said fluid flow from said well control system to said fluid retention vessel.
2. The method of transferring fluid flow initiated from a subsurface wellhead of claim 1, wherein said method further comprises:
buoyantly supporting said well control system within said body of water using a buoyancy chamber.
buoyantly supporting said well control system within said body of water using a buoyancy chamber.
3. The method of transferring fluid flow initiated from a subsurface wellhead of claim 1, wherein said method further comprises:
positioning said well control system through said subsurface wellhead using a stress joint.
positioning said well control system through said subsurface wellhead using a stress joint.
4. The method of transferring fluid flow initiated from a subsurface wellhead of claim 3, wherein said method further comprises:
receiving said fluid flow from said subsurface wellhead using said stress joint.
receiving said fluid flow from said subsurface wellhead using said stress joint.
5. The method of transferring fluid flow initiated from a subsurface wellhead of claim 1, wherein said method further comprises:
transferring said fluid flow from said fluid flow receiving means to said well control system using production casing.
transferring said fluid flow from said fluid flow receiving means to said well control system using production casing.
6. The method of transferring fluid flow initiated from a subsurface wellhead of claim 1, wherein said method further comprises:
transferring said fluid flow from said well control system to said fluid retention vessel using at least one of a production tree, a blowout preventer, and a wellhead disposed nearer the surface of said body of water than said subsurface wellhead.
transferring said fluid flow from said well control system to said fluid retention vessel using at least one of a production tree, a blowout preventer, and a wellhead disposed nearer the surface of said body of water than said subsurface wellhead.
7. A means for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water to a fluid retention vessel disposed nearer the surface of said body of water, said means comprising:
means for buoyantly supporting a well control system within said body of water; means for positioning said well control system through said subsurface wellhead;
means for initiating a fluid flow from said subsurface wellhead;
means for receiving said fluid flow from said subsurface wellhead;
means for transferring said fluid flow from said subsurface wellhead to said well control system; and means for transferring said fluid flow from said well control system to said fluid retention vessel.
means for buoyantly supporting a well control system within said body of water; means for positioning said well control system through said subsurface wellhead;
means for initiating a fluid flow from said subsurface wellhead;
means for receiving said fluid flow from said subsurface wellhead;
means for transferring said fluid flow from said subsurface wellhead to said well control system; and means for transferring said fluid flow from said well control system to said fluid retention vessel.
8. The means for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water of claim 7, wherein said means further comprises:
a buoyancy chamber for supporting said well control system within said body of water.
a buoyancy chamber for supporting said well control system within said body of water.
9. The means for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water of claim 7, wherein said means further comprises:
a stress joint for positioning said well control system through said subsurface wellhead.
a stress joint for positioning said well control system through said subsurface wellhead.
10. The means for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water of claim 9, wherein said stress joint is also used for receiving said fluid flow from said subsurface wellhead.
11. The means for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water of claim 7, wherein said means further comprises:
a length of production casing for transferring said fluid flow from said subsurface wellhead to said well control system.
a length of production casing for transferring said fluid flow from said subsurface wellhead to said well control system.
12. The means for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water of claim 7, wherein said means further comprises:
at least one of a production tree, a blowout preventer, and a wellhead disposed nearer the surface than said subsurface wellhead used for transferring said fluid flow from said well control system to said fluid retention vessel.
at least one of a production tree, a blowout preventer, and a wellhead disposed nearer the surface than said subsurface wellhead used for transferring said fluid flow from said well control system to said fluid retention vessel.
13. A system for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water to a fluid retention vessel disposed nearer the surface of said body of water, said system comprising:
a buoyancy chamber for buoyantly supporting a well control system within said body of water;
a means for positioning said well control system through said subsurface wellhead;
a means for initiating a fluid flow from said subsurface wellhead;
a fluid flow receiving means for receiving said fluid flow from said subsurface wellhead;
a length of production casing for transferring said fluid flow from said fluid flow receiving means to said well control system; and at least one of a production tree, a blowout preventer and a wellhead disposed nearer the surface of said body of water used for transferring said fluid flow from said well control system to said fluid retention vessel.
a buoyancy chamber for buoyantly supporting a well control system within said body of water;
a means for positioning said well control system through said subsurface wellhead;
a means for initiating a fluid flow from said subsurface wellhead;
a fluid flow receiving means for receiving said fluid flow from said subsurface wellhead;
a length of production casing for transferring said fluid flow from said fluid flow receiving means to said well control system; and at least one of a production tree, a blowout preventer and a wellhead disposed nearer the surface of said body of water used for transferring said fluid flow from said well control system to said fluid retention vessel.
14. The system for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water of claim 13, wherein said means for positioning said well control system through said subsurface wellhead further comprises a stress joint.
15. The system for transferring fluid flow initiated from a subsurface wellhead disposed beneath the surface of a body of water of claim 14, wherein said stress joint is also used to receive said fluid flow from said subsurface wellhead.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US11/387,378 US20060162933A1 (en) | 2004-09-01 | 2006-03-23 | System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber |
| US11/387,378 | 2006-03-23 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2544362A1 true CA2544362A1 (en) | 2006-10-27 |
Family
ID=37193951
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002544362A Abandoned CA2544362A1 (en) | 2006-03-23 | 2006-04-20 | System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber |
Country Status (8)
| Country | Link |
|---|---|
| US (1) | US20060162933A1 (en) |
| EP (1) | EP1837482A1 (en) |
| AP (1) | AP2006003682A0 (en) |
| AR (1) | AR056001A1 (en) |
| AU (1) | AU2006202945A1 (en) |
| BR (1) | BRPI0603800A (en) |
| CA (1) | CA2544362A1 (en) |
| WO (1) | WO2007108823A1 (en) |
Families Citing this family (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA2801389A1 (en) * | 2010-05-03 | 2011-11-10 | Keith K. Millheim | Safety system for deep water drilling units using a dual blow out preventer system |
| NO331978B1 (en) * | 2010-06-22 | 2012-05-14 | Neodrill As | Apparatus and method for stabilizing a wellhead, and using a suction foundation to support a wellhead |
| US8657012B2 (en) | 2010-11-01 | 2014-02-25 | Vetco Gray Inc. | Efficient open water riser deployment |
| US9879396B2 (en) * | 2013-06-24 | 2018-01-30 | Trendsetter Vulcan Offshore, Inc. | Systems and methods for tethering subsea structure mounted on a wellhead |
| WO2014210026A2 (en) * | 2013-06-24 | 2014-12-31 | Bp Corporation North America, Inc. | Systems and methods for tethering subsea blowout preventers to enhance the strength and fatigue resistance of subsea wellheads and primary conductors |
| US20150096760A1 (en) * | 2013-10-03 | 2015-04-09 | Atlantis Offshore Holding Ltd. | Modular Exploration and Production System Including an Extended Well Testing Service Vessel |
| NO340947B1 (en) | 2014-11-27 | 2017-07-24 | Neodrill As | Device at wellhead |
| NO344358B1 (en) * | 2017-05-31 | 2019-11-18 | Neodrill As | Device at wellhead |
| GB201719678D0 (en) * | 2017-11-27 | 2018-01-10 | Underwater Novel Tech Limited | Method and appratus for supporting a wellhead |
| EP3597854A1 (en) | 2018-07-20 | 2020-01-22 | Neodrill AS | Arrangement for supporting a wellhead |
| NO344892B1 (en) * | 2019-10-04 | 2020-06-15 | Neodrill As | Device at wellhead |
Family Cites Families (36)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3017934A (en) * | 1955-09-30 | 1962-01-23 | Shell Oil Co | Casing support |
| GB1172558A (en) * | 1967-04-27 | 1969-12-03 | Cammell Laird & Company Shipbu | Improvements in or relating to Buoyant Well-Head Structures for Offshores Wells |
| US3602174A (en) * | 1969-06-27 | 1971-08-31 | North American Rockwell | Transfer riser system for deep suboceanic oilfields |
| GB1245740A (en) * | 1970-06-17 | 1971-09-08 | Shell Int Research | Equipment for a well penetrating a formation located below a body of water |
| US3722584A (en) * | 1970-08-13 | 1973-03-27 | A Nelson | Apparatus and method for drilling underwater |
| US3778854A (en) * | 1971-03-16 | 1973-12-18 | Santa Fe Int Corp | Mooring and oil transfer apparatus |
| GB1519203A (en) * | 1974-10-02 | 1978-07-26 | Chevron Res | Marine risers in offshore drilling |
| US4216834A (en) * | 1976-10-28 | 1980-08-12 | Brown Oil Tools, Inc. | Connecting assembly and method |
| US4098333A (en) * | 1977-02-24 | 1978-07-04 | Compagnie Francaise Des Petroles | Marine production riser system |
| GB2069647B (en) * | 1980-02-14 | 1983-10-05 | Brown John Constr | Guides for forming underwater connections |
| NL181640C (en) * | 1980-09-12 | 1987-10-01 | Single Buoy Moorings | MOORING SYSTEM. |
| US4448266A (en) * | 1980-11-14 | 1984-05-15 | Potts Harold L | Deep water riser system for offshore drilling |
| US4637335A (en) * | 1982-11-01 | 1987-01-20 | Amtel, Inc. | Offshore hydrocarbon production system |
| US4832126A (en) * | 1984-01-10 | 1989-05-23 | Hydril Company | Diverter system and blowout preventer |
| US4735267A (en) * | 1985-03-11 | 1988-04-05 | Shell Oil Company | Flexible production riser assembly and installation method |
| US4617998A (en) * | 1985-04-08 | 1986-10-21 | Shell Oil Company | Drilling riser braking apparatus and method |
| US4646840A (en) * | 1985-05-02 | 1987-03-03 | Cameron Iron Works, Inc. | Flotation riser |
| US4702321A (en) * | 1985-09-20 | 1987-10-27 | Horton Edward E | Drilling, production and oil storage caisson for deep water |
| US4702320A (en) * | 1986-07-31 | 1987-10-27 | Otis Engineering Corporation | Method and system for attaching and removing equipment from a wellhead |
| US4762180A (en) * | 1987-02-05 | 1988-08-09 | Conoco Inc. | Modular near-surface completion system |
| US5379844A (en) * | 1993-02-04 | 1995-01-10 | Exxon Production Research Company | Offshore platform well system |
| NO305138B1 (en) * | 1994-10-31 | 1999-04-06 | Mercur Slimhole Drilling And I | Device for use in drilling oil / gas wells |
| US5524710A (en) * | 1994-12-21 | 1996-06-11 | Cooper Cameron Corporation | Hanger assembly |
| NO303028B1 (en) * | 1996-03-12 | 1998-05-18 | Terje Magnussen | The subsea installation |
| US5860840A (en) * | 1996-08-02 | 1999-01-19 | Fmc Corporation | Disconnectable turret mooring system utilizing a spider buoy |
| US6244785B1 (en) * | 1996-11-12 | 2001-06-12 | H. B. Zachry Company | Precast, modular spar system |
| AU730041B2 (en) * | 1996-12-10 | 2001-02-22 | Wirth Maschinen- Und Bohrgerate-Fabrik Gmbh | Method of, and apparatus for, sinking bore holes, in particular exploratory and extraction bore holes, in the sea bed |
| US5794700A (en) * | 1997-01-27 | 1998-08-18 | Imodco, Inc. | CAM fluid transfer system |
| FR2768457B1 (en) * | 1997-09-12 | 2000-05-05 | Stolt Comex Seaway | DEVICE FOR UNDERWATER TRANSPORT OF PETROLEUM PRODUCTS WITH A COLUMN |
| US6210075B1 (en) * | 1998-02-12 | 2001-04-03 | Imodco, Inc. | Spar system |
| DE69836261D1 (en) * | 1998-03-27 | 2006-12-07 | Cooper Cameron Corp | Method and device for drilling multiple subsea wells |
| EP0952301B1 (en) * | 1998-03-27 | 2006-05-17 | Cooper Cameron Corporation | Method and apparatus for drilling an offshore underwater well |
| US6155748A (en) * | 1999-03-11 | 2000-12-05 | Riser Systems Technologies | Deep water riser flotation apparatus |
| US6672390B2 (en) * | 2001-06-15 | 2004-01-06 | Shell Oil Company | Systems and methods for constructing subsea production wells |
| US7063158B2 (en) * | 2003-06-16 | 2006-06-20 | Deepwater Technologies, Inc. | Bottom tensioned offshore oil well production riser |
| US7458425B2 (en) * | 2004-09-01 | 2008-12-02 | Anadarko Petroleum Corporation | System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber |
-
2006
- 2006-03-23 US US11/387,378 patent/US20060162933A1/en not_active Abandoned
- 2006-04-20 CA CA002544362A patent/CA2544362A1/en not_active Abandoned
- 2006-07-10 AP AP2006003682A patent/AP2006003682A0/en unknown
- 2006-07-10 AU AU2006202945A patent/AU2006202945A1/en not_active Abandoned
- 2006-07-26 AR ARP060103227A patent/AR056001A1/en unknown
- 2006-08-28 WO PCT/US2006/033708 patent/WO2007108823A1/en active Application Filing
- 2006-09-12 EP EP06019039A patent/EP1837482A1/en not_active Withdrawn
- 2006-09-14 BR BRPI0603800-0A patent/BRPI0603800A/en not_active IP Right Cessation
Also Published As
| Publication number | Publication date |
|---|---|
| EP1837482A1 (en) | 2007-09-26 |
| AR056001A1 (en) | 2007-09-12 |
| BRPI0603800A (en) | 2007-01-23 |
| AP2006003682A0 (en) | 2006-08-31 |
| US20060162933A1 (en) | 2006-07-27 |
| WO2007108823A1 (en) | 2007-09-27 |
| AU2006202945A1 (en) | 2007-10-11 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US7458425B2 (en) | System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber | |
| EP1837482A1 (en) | System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber | |
| US6692194B2 (en) | Method for installing a conductor casing through a suction substructure | |
| US8047297B2 (en) | System for and method of restraining a subsurface exploration and production system | |
| US8573891B2 (en) | Tension buoyant tower | |
| EA007215B1 (en) | Anchor installation system | |
| US20140338918A1 (en) | Self-Standing Riser with Artificial Lift System | |
| US8657012B2 (en) | Efficient open water riser deployment | |
| WO2002088516A1 (en) | Subsea drilling riser disconnect system and method | |
| OA13023A (en) | System and method of installing and maintaining anoffshore exploration and production system having an adjustable buoyancy chamber. | |
| US6715962B2 (en) | Assembly and floatation method for drilling drivepipe | |
| US20010027878A1 (en) | Assembly and floatation method for drilling drivepipe and jarring system | |
| US9593540B2 (en) | Safety system for deep water drilling units using a dual blow out preventer system | |
| WO2023219516A1 (en) | Subsea well interventions | |
| Burkhardt | A progress report test of submerged production system | |
| KR20150108549A (en) | Test Apparatus and Method for Drilling Equipment | |
| KR20150108548A (en) | Supply Barge for Installing BOP Test Apparatus |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| FZDE | Discontinued |