EP1659257B1 - Offshore Forschungs- und produktionssystem mit verstellbaren Auftriebskammer - Google Patents

Offshore Forschungs- und produktionssystem mit verstellbaren Auftriebskammer Download PDF

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Publication number
EP1659257B1
EP1659257B1 EP04030599A EP04030599A EP1659257B1 EP 1659257 B1 EP1659257 B1 EP 1659257B1 EP 04030599 A EP04030599 A EP 04030599A EP 04030599 A EP04030599 A EP 04030599A EP 1659257 B1 EP1659257 B1 EP 1659257B1
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Prior art keywords
disposing
communication
disposed
adjustable
buoyancy chamber
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EP04030599A
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English (en)
French (fr)
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EP1659257A1 (de
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Keith Dr. Millheim
Eric E. Maidla
Charles H. King
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Anadarko Petroleum Corp
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Anadarko Petroleum Corp
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Priority claimed from US10/994,799 external-priority patent/US7458425B2/en
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • 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

Definitions

  • 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.
  • ABS artificial buoyant seabed
  • 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.
  • Atlantis ABS system is deficient, however, in several practical respects.
  • 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 152 m (500 feet) beneath the surface.
  • 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.
  • US 4448266 A discloses an offshore exploration and production system and a method of installing and maintaining an offshore exploration and production system corresponding to the preambles of independent claims 1 and 10.
  • the above mentioned needs are satisfied by a system and method of establishing an offshore exploration and production system according to independent claims 1 and 10.
  • the invention provides such system and method, 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.
  • an offshore exploration and production system 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.
  • the well 1 is accessed from above by means of a well hole 3 that has been bored into an associated sea floor surface.
  • a well casing 2 is set into the hole in a firm and secure manner, and then cemented into place using known downhole technology.
  • 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.
  • a well isolation member 4 is disposed between well casing 2 and a lower connecting member 5.
  • 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.
  • 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.
  • lower connecting member 5 further comprises one or more receiving members disposed to receive an attachment member disposed on well isolation member 4.
  • 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.
  • lower connecting member 5 may comprise any known connecting means appropriate for the specific application contemplated by operators.
  • lower connecting member 5 comprises one or more of segments of riser, riser pipe, and/or pipe casing.
  • 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.
  • 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.
  • lower connecting member 5 is drawn taut and held in a stable position.
  • 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.
  • the vertical tension of lower connecting member 5 is held approximately constant while the height or depth of well terminal member 14 is adjusted.
  • 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.
  • 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.
  • 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.
  • an anchoring member 8 for example, a suction type anchor, or alternatively, a mechanical or conventional deadweight type anchor.
  • 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.
  • adjustable buoyancy chamber 9 further comprises a plurality of inner chambers.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • adjustable buoyancy chamber 9 further comprises a ballast output valve, so that ballast can be discharged from the chamber.
  • ballast output valve so that ballast can be discharged from the chamber.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • the tension lines 10 are individually adjustable, whereas in other embodiments, the tension lines 10 are collectively controlled.
  • the one or more tension lines 10 are both individually and collectively adjustable.
  • adjustable buoyancy chamber 9 is disposed in communication with a vertical tension receiving member 11.
  • 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.
  • a tension measuring means e.g ., a load cell, strain gauge, etc.
  • 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.
  • 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.
  • 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 .)
  • 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 30 to 91 m (100 to 300 feet) beneath the surface.
  • 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 15 to 30 m (50 to 100 feet).
  • well terminal member 14 is disposed at depths of less than 15 m (50 feet), or greater than 91 in (300 feet), depending upon the actual conditions surrounding operations.
  • well terminal member 14 is disposed either at the surface or above the surface of the water, and a blowout preventer or a production tree 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • well terminal member 14 can terminate in a blowout preventer, so that the well will not blow out during drilling operations.
  • well terminal member 14 terminates in a combined production tree and blowout preventer assembly to facilitate simplified well intervention operations.
  • a system and method of establishing a height-variable well terminal member comprising a lower fluid transport pipe 21, an inner well casing 22, an outer well casing 23, and a wellhead 24.
  • a well isolation member 25 is disposed above the wellhead 24, so that the well can be closed off or shut in if desired.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.

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  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Mechanical Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
  • Geophysics And Detection Of Objects (AREA)
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Claims (16)

  1. Ein ablandiges Untersuchungs- und Produktionssystem, wobei das System aufweist:
    a) Ein Bohrlochgehäuse (2, 22), angeordnet in Kommunikation mit einem ablandigen Bohrloch (1);
    b) zumindest einen Schwimmer (9, 30);
    c) ein unteres Verbindungselement (5, 26), angeordnet zwischen dem Bohrlochgehäuse (2, 22) und dem Schwimmer (9, 30); und wobei
    d) der zumindest eine Schwimmer (9, 30) in Kommunikation mit zumindest einer Spannungsleitung (10, 31), die bereitgestellt ist, den zumindest einen Schwimmer (9, 30) auf den Meeresgrund zu verankern, angeordnet ist; dadurch gekennzeichnet dass
    e) der zumindest eine Schwimmer (9, 30) anpassbar durch das Variieren der Länge der zumindest einen Spannungsleitung (10, 31) ist.
  2. Das System gemäß Anspruch 1, weiterhin aufweisend:
    a) Eine oder mehrere anpassbare Schwimmer (9); oder
    b) ein Bohrlochgehäuse (2), das in Kommunikation mit einem Loch (3), das in der dazugehörigen Meeresgrundoberfläche gebohrt ist, angeordnet ist; oder
    c) ein Bohrlochisolationselement (4), das zwischen dem angleichbaren Schwimmer (9) und dem unteren Verbindungselement (5) angeordnet ist, wobei
    i. das Bohrlochisolationselement (4) weiterhin vorzugsweise eine oder mehrere Kugelventile oder einen Bohrlochschieber, der vorzugsweise einen Schubstampfer enthält, aufweist; oder
    ii. das untere Befestigungselement (5) weiterhin vorzugsweise ein Aufnahmeelement für das Aufnehmen eines Anbringungselements aufweist, das an dem Isolationselement (4) oder an einem Anbringungselement für das Anbringen des unteren Verbindungselement (5) an ein Aufnahmeelement, das an dem Isolationselement (4) angeordnet ist, angebracht ist.
  3. Das System gemäß Anspruch 1, wobei das untere Verbindungselement (5) weiterhin aufweist:
    a) Eine Steigleitung; oder
    b) eine Steigrohrleitung; oder
    c) ein Gehäuse; oder
    d) ein Flüssigkeitstransportelement, das innerhalb eines inneren Anteils des unteren Verbindungselements angeordnet ist, wobei das Flüssigkeitstransportelement vorzugsweise höhenanpassbar ist in Reaktion auf einen Auftrieb, der durch den anpassbaren Schwimmer (9) vermittelt wird.
  4. Das System gemäß Anspruch 1, wobei das untere Verbindungselement (5) in Kommunikation mit einem oder mehreren lateralen Stabilisatoren (6) angeordnet ist, wobei
    a) weiterhin der eine oder mehrere laterale Stabilisatoren (6) vorzugsweise einen oder mehrere anpassbare laterale Stabilisatoren aufweist; oder
    b) wobei vorzugsweise der eine oder die mehreren lateralen Stabilisatoren (6) in Kommunikation mit einer oder mehreren Spannungsleitungen (7) angeordnet sind,
    i. wobei die eine oder mehrere Spannungsleitungen (7) weiterhin eine oder mehrere individuell anpassbare Spannungsleitungen aufweisen; oder
    ii. wobei vorzugsweise die eine oder mehrere Spannungsleitungen (7) in Kommunikation mit einem oder mehreren Befestigungselementen (8) angeordnet sind.
  5. Das System gemäß Anspruch 2, wobei der eine oder die mehreren anpassbaren Schwimmer (9) weiterhin eine oder mehrere ungefähr ringförmig anpassbare Schwimmer aufweisen, wobei das untere Verbindungselement (5) vorzugsweise longitudinal durch einen Hohlraum, der in dem einen oder mehreren ungefähr ringförmig angepassten Schwimmern geformt ist, angeordnet ist.
  6. Das System gemäß Anspruch 2, wobei eine oder mehrere des einen oder der mehreren anpassbaren Schwimmer (9) weiterhin eine Vielzahl von inneren Kammern aufweisen.
  7. Das System gemäß Anspruch 1, wobei der anpassbare Schwimmer weiterhin aufweist:
    a) Einen Flüssigkeitsballast, der vorzugsweise eine Einspeisung von komprimiertem Gas aufweist; oder
    b) ein Ballasteingangsventil,
    i. wobei vorzugsweise das Ballasteingangsventil in Kommunikation mit einem oder mehreren Versorgungs- oder entfernt operierenden Fahrzeugen steht; oder
    ii. wobei das Ballasteingangsventil vorzugsweise in Kommunikation mit einer Pumpe angeordnet ist; oder
    iii. wobei vorzugsweise das Ballasteingangsventil in Kommunikation mit einem Kompressor angeordnet ist; oder
    iv. wobei das Ballasteingangsventil vorzugsweise in Kommunikation mit einem Kompressor angeordnet ist; oder
    c) ein Ballastausgangsventil,
    i. wobei das Ballastausgangsventil vorzugsweise in Kommunikation mit einem oder mehreren Versorgungs- oder entfernt operierenden Fahrzeugen steht; oder
    ii. wobei das Ballastausgangsventil vorzugsweise in Kommunikation mit einer Pumpe angeordnet ist; oder
    iii. wobei vorzugsweise das Ballastausgangsventil in Kommunikation mit einem Kompressor angeordnet ist;
  8. Das System gemäß Anspruch 1, wobei der anpassbare Schwimmer:
    a) In Kommunikation mit einer oder mehreren Spannungsleitungen (10) angeordnet ist,
    i. wobei die eine oder mehreren Spannungsleitungen (10) vorzugsweise weiterhin eine oder mehrere individuell anpassbare Spannungsleitungen aufweisen; oder
    ii. wobei vorzugsweise eine oder mehrere Spannungsleitungen (10) in Kommunikation mit einer oder mehreren Befestigungselementen verankert ist; oder
    b) in Kommunikation mit einem vertikalen Spannungsaufnahmeelement (11) angeordnet ist, wobei das Spannungsaufnahmeelement vorzugsweise in Kommunikation mit einem Spannungsmessmittel, das vorzugsweise eine Auflagezelle aufweist, angeordnet ist; oder
    c) untergetaucht ist in einem Wasserkörper bei einer Tiefe zwischen ungefähr 30 Metern und ungefähr 91 Metern; oder
    d) untergetaucht ist in einem Wasserkörper bei einer Tiefe von weniger als ungefähr 30 Metern; oder
    e) untergetaucht ist in einem Wasserkörper bei einer Tiefe größer als ungefähr 91 Meter; oder
    f) in Kommunikation mit einem oberen Bohrlochisolationsmittel angeordnet ist,
    i. vorzugsweise ein Kugelventil aufweisend; oder
    ii. vorzugsweise einen Bohrlochschieber, der vorzugsweise einen Schubstampfer aufweist, aufweisend; oder
    g) in Kommunikation mit einem oberen Verbindungselement (12) angeordnet ist, wobei vorzugsweise das obere Verbindungselement (12) in Kommunikation mit einem Bohrlochanschlusselement (14) angeordnet ist, vorzugsweise aufweisend:
    i. einen Produktionsbaum; oder
    ii. einen Bohrlochschieber; oder
    iii. eine kombinierte Produktionsbaum- und Bohrlochschiebersvorrichtung.
  9. Das System gemäß Anspruch 1, wobei ein Bohrlochanschlusselement (14), das oberhalb des anpassbaren Schwimmers (9) angeordnet ist, oberhalb einer Oberfläche des Wasserkörpers angeordnet ist.
  10. Ein Verfahren für das Installieren und Aufrechterhalten eines ablandigen Untersuchungs- und Produktionssystems, wobei das Verfahren die Schritte des
    a) Anordnens eines Bohrlochgehäuses (2, 22) in Kommunikation mit einem ablandigen Bohrloch aufweist;
    b) Anordnens eines unteren Verbindungselements (5) zwischen dem Bohrlochgehäuse (2) und einem oder mehreren Schwimmern (9, 30) aufweist;
    c) Anordnens von zumindest einem Schwimmer (9, 30) in Kommunikation mit zumindest einer Spannungsleitung (10, 31) und das Verankern des zumindest einen Schwimmers (9, 30) auf dem Meeresgrund aufweist, charakterisiert durch den weiteren Schritt des
    e) Anpassens des zumindest einen Schwimmers (9, 30) durch das Variieren der Länge der zumindest einen Spannungsleitung (10, 31).
  11. Das Verfahren gemäß Anspruch 10, weiterhin aufweisend die Schritte des
    a) Anordnens eines oder mehreren anpassbaren Schwimmer (9) in Kommunikation mit dem Bohrlochgehäuse (2), wobei das Verfahren vorzugsweise weiterhin das Zementieren des Bohrlochgehäuses (2) in ein Loch (3), das in die Meeresgrundoberfläche gebohrt wird, aufweist; oder
    b) Anordnens eines Bohrlochisolationselements zwischen dem angleichbaren Schwimmer (9) und dem unteren Verbindungselement (5), vorzugsweise weiterhin aufweisend;
    i. Anordnen eines Bohrlochisolationselements (4), das eine oder mehrere Kugelventile aufweist; oder
    ii. Anordnen eines Bohrlochisolationselements (4), das einen Bohrlochschieber aufweist, wobei das Anordnen einer Bohrlochschieber weiterhin vorzugsweise das Anordnen einer Bohrlochschiebers mit einem Schubstampfer aufweist; oder
    iii. Anordnen eines Bohrlochisolationselements (4), das ein Anbringungselement für das Anbringen des Bohrlochisolationselements an einem Empfangselement, das an dem unteren Verbindungselement angebracht ist, aufweist; oder
    iv. Anbringen eines Bohrlochisolationselements (4), das ein Empfangselement für das Empfangen eines Anbringungselements, das an dem unteren Verbindungselement (5) angebracht ist, aufweist.
  12. Das Verfahren gemäß Anspruch 10, wobei das Anordnen eines unteren Verbindungselements (5) weiterhin die Schritte des
    a) Anordnens einer Steigleitung; oder
    b) Anordnens einer Steigrohrleitung; oder
    c) Anordnens eines Gehäuses; oder
    d) Anordnens eines Flüssigkeitstransportselements, das innerhalb eines inneren Anteils des unteren Verbindungselements beherbergt ist aufweist, wobei das Verfahren vorzugsweise weiterhin das Anpassen der Länge von einer oder mehreren zugeordneten Spannungsleitungen umfasst, sodass die Höhe des Flüssigkeitstransportelements variierbar anpassbar ist; oder
    e) Anordnens eines unteren Verbindungselements in Kommunikation mit einem oder mehreren lateralen Stabilisatoren (6), wobei das Verfahren vorzugsweise weiterhin die Schritte des
    i. Anordnens eines unteren Verbindungselements (5) in Kommunikation mit einem oder mehreren angleichbaren lateralen Stabilisatoren oder
    ii. Anordnens des einen oder mehreren lateralen Stabilisatoren in Kommunikation mit einer oder mehreren Spannungsleitungen (7) aufweist, wobei weiterhin vorzugsweise das Verfahren das Anordnen von einem oder mehreren lateralen Stabilisatoren (6) in Kommunikation mit einer oder mehreren anpassbaren Spannungsleitungen aufweist oder das Verfahren vorzugsweise weiterhin das Anordnen der einen oder mehreren Spannungsleitungen (7) in Kommunikation mit einem oder mehreren Verankerungselementen (8) aufweist.
  13. Das Verfahren gemäß Anspruch 11, weiterhin aufweisend die Schritte des
    a) Anordnens eines oder mehrerer ungefähr ringförmigen anpassbaren Schwimmer (9), wobei das Verfahren vorzugsweise weiterhin das Anordnen des unteren Verbindungselements (5) longitudinal durch einen Hohlraum, der in einem oder mehreren ungefähr ringförmigen anpassbaren Schwimmer geformt ist, aufweist; oder
    b) Anordnens einer oder mehrerer anpassbarer Schwimmer (9), die eine Vielzahl von inneren Kammern aufweisen.
  14. Das Verfahren gemäß Anspruch 10, weiterhin aufweisend das Anordnen eines angleichbaren Schwimmers (9), der
    a) einen Flüssigkeitsballast hat, wobei das Anordnen des anpassbaren Schwimmers (9), der einen Flüssigkeitsballast hat, weiterhin vorzugsweise das Anordnen eines anpassbaren Schwimmers (9), der eine Versorgung zu kompressiblem Gas hat, aufweist; oder
    b) ein Flüssigkeitseinlassventil aufweist, wobei das Verfahren weiterhin vorzugsweise aufweist:
    i. Das Anordnen des Flüssigkeitseinlassventils in Kommunikation mit einem oder mehreren Versorgungs- oder entfernt operierenden Fahrzeugen; oder
    ii. Anordnens des Flüssigkeitseinlassventils in Kommunikation mit einer Pumpe; oder
    iii. Anordnens des Flüssigkeitseinlassventils in Kommunikation mit einem Kompressor; oder
    c) ein Flüssigkeitsauslassventil hat, wobei das Verfahren weiterhin vorzugsweise die Schritte des
    i. Anordnens des Flüssigkeitsauslassventils in Kommunikation mit einem oder mehreren Versorgungs- oder entfernt operierenden Fahrzeugen aufweist; oder
    ii. Anordnens des Flüssigkeitsauslassventils in Kommunikation mit einer Pumpe aufweist; oder
    iii. Anordnens des Flüssigkeitsauslassventils in Kommunikation mit einem Kompressor aufweist.
  15. Das Verfahren gemäß Anspruch 10, weiterhin aufweisend das Anordnen eines anpassbaren Schwimmers in Verbindung mit
    a) einer oder mehreren anpassbaren Spannungsleitungen (10), wobei das Verfahren vorzugsweise weiterhin die Schritte des
    i. Anordnens eines anpassbaren Schwimmers (9) in Kommunikation mit einer oder mehreren individuell anpassbaren Spannungsleitungen aufweist; oder
    ii. Anordnens eines oder mehrerer Spannungsleitungen (10) in Kommunikation mit einem oder mehreren Verankerungselementen aufweist; oder
    b) ein Spannungsempfangselement (11), wobei das Verfahren weiterhin vorzugsweise das Anordnen des Spannungsempfangselements (11) in Kommunikation mit einem Spannungsmessmittel aufweist, wobei das Anordnen des Spannungsempfangsmittels (11) in Kommunikation mit einem Spannungsmessmittel vorzugsweise weiterhin das Anordnen des Spannungsempfangselements in Kommunikation mit einer Ladungszelle aufweist; oder
    c) dem Untertauchen eines anpassbaren Schwimmers in einem Wasserkörper auf eine Tiefe zwischen 30 Meter und ungefähr 91 Meter; oder
    d) dem Untertauchen eines anpassbaren Schwimmers in einem Wasserkörper auf eine Tiefe weniger als ungefähr 30 Meter; oder
    e) dem Untertauchen eines anpassbaren Schwimmers in einem Wasserkörper auf eine Tiefe größer als ungefähr 91 Meter; oder
    f) dem Anordnen eines Bohrlochanschlusselements (14) oberhalb des anpassbaren Schwimmers (9) in einer Weise, sodass das Bohrlochanschlusselement (14) oberhalb einer Oberfläche des Wasserkörpers angeordnet ist; oder
    g) dem Anordnen eines anpassbaren Schwimmers (9) in Kommunikation mit einem Bohrlochisolationsmittel (4), wobei das Verfahren weiterhin das
    i. Anordnen eines anpassbaren Schwimmers in Kommunikation mit einem Bohrlochisolationsmittel (4), das ein Kugelventil aufweist, aufweist; oder
    ii. Anordnen eines anpassbaren Schwimmers in Kommunikation mit einem Bohrlochisolationsmittel (4), das einen Bohrlochschieber aufweist, wobei das Verfahren weiterhin vorzugsweise das Anordnen eines anpassbaren Schwimmers (9) in Kommunikation mit einem Bohrlochschieber, der einen Schubstampfer aufweist, aufweist; oder
    h) Anordnen eines anpassbaren Schwimmers (9) in Kommunikation mit einem oberen Verbindungselement (12), wobei das Verfahren weiterhin vorzugsweise das Anordnen des oberen Verbindungselements (12) in Kommunikation mit einem Bohrlochanschlusselement (14) aufweist, wobei das Verfahren weiterhin vorzugsweise das
    i. Anordnen des oberen Verbindungselements (12) in Kommunikation mit einer Bohrlochschieber aufweist; oder
    ii. das Anordnen des oberen Verbindungselements (12) in Kommunikation mit einem Produktionsbaum aufweist; oder
    iii. Anordnen des oberen Verbindungselements (12) in Kommunikation mit einem kombinierten Produktionsbaum und Bohrlochschiebersvorrichtung aufweist.
  16. Die Verwendung eines ablandigen Untersuchungs- und Produktionssystems gemäß der Ansprüche 1 bis 9, wobei die Verwendung des Systems für die Untersuchung und Produktion von Öl und Gas dient.
EP04030599A 2004-11-22 2004-12-23 Offshore Forschungs- und produktionssystem mit verstellbaren Auftriebskammer Expired - Lifetime EP1659257B1 (de)

Applications Claiming Priority (1)

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US10/994,799 US7458425B2 (en) 2004-09-01 2004-11-22 System and method of installing and maintaining an offshore exploration and production system having an adjustable buoyancy chamber

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EP1659257B1 true EP1659257B1 (de) 2010-01-27

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AR (1) AR050592A1 (de)
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CN107288585B (zh) * 2017-07-26 2023-09-05 北京探矿工程研究所 一种用于深水勘查的基座系统及其使用方法

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OA13023A (en) 2006-11-10
EA006866B1 (ru) 2006-04-28
WO2006057646A2 (en) 2006-06-01
AP2005003228A0 (en) 2005-03-31
BRPI0500381A (pt) 2006-07-18
AU2004317502A1 (en) 2006-06-08
DK1659257T3 (da) 2010-05-03
AR050592A1 (es) 2006-11-08
ATE456727T1 (de) 2010-02-15
EP1659257A1 (de) 2006-05-24
AU2004317502B2 (en) 2008-05-29
WO2006057646A3 (en) 2007-03-01
ES2338651T3 (es) 2010-05-11
BRPI0500381B1 (pt) 2016-02-16
CA2491273A1 (en) 2006-05-22
DE602004025356D1 (de) 2010-03-18
AP2054A (en) 2009-10-09
EA200500308A1 (ru) 2006-04-28

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