EP3841270B1 - Verfahren zur zuführung von injektionsflüssigkeit an einer unterwasseranlage - Google Patents

Verfahren zur zuführung von injektionsflüssigkeit an einer unterwasseranlage Download PDF

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Publication number
EP3841270B1
EP3841270B1 EP19749338.0A EP19749338A EP3841270B1 EP 3841270 B1 EP3841270 B1 EP 3841270B1 EP 19749338 A EP19749338 A EP 19749338A EP 3841270 B1 EP3841270 B1 EP 3841270B1
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EP
European Patent Office
Prior art keywords
storage container
location
subsea
injection fluid
injection
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Active
Application number
EP19749338.0A
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English (en)
French (fr)
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EP3841270A1 (de
Inventor
Julie LUND
Marius BJØRN
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NOV Process and Flow Technologies AS
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NOV Process and Flow Technologies AS
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B27/00—Containers for collecting or depositing substances in boreholes or wells, e.g. bailers, baskets or buckets for collecting mud or sand; Drill bits with means for collecting substances, e.g. valve drill bits
    • E21B27/02—Dump bailers, i.e. containers for depositing substances, e.g. cement or acids
    • 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
    • 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
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/12—Underwater drilling

Definitions

  • injection fluids such as mud or chemicals at or near the seabed.
  • injection fluids such as mud or chemicals at or near the seabed.
  • hoses, tubes or pipes bundled into "umbilicals" to supply the injection fluid from nearby surface facilities e.g. from a vessel to the respective points of injection.
  • Longer offsets, remote locations and deep-water subsea facilities contribute to make this umbilical solution undesirable, difficult and expensive.
  • Subsea installed storage containers offer great potential benefits both for continuous and intermittent injection.
  • US2014/00332269 discloses a method for delivery of drilling fluid to a seafloor drilling assembly.
  • the method comprising the steps of filling at least one container located adjacent the surface with drilling fluid; lowering the container through a body of water to adjacent a seafloor drilling assembly; connecting the container to the seafloor drilling assembly to deliver drilling fluid to the seafloor drilling assembly.
  • the invention at least partially alleviates at least one of the above-discussed problems.
  • the invention mitigates the problems related to large dead volumes in the hose.
  • the invention provides a method of supplying an injection fluid to a subsea facility, where the filling and/or refilling of the storage container(s) is relatively simple with low risk of damaging equipment even where the storage container is relatively large.
  • the invention relates to subsea filing and/or refilling of a storage container with injection fluid. Due to the subsea use of the storage container it is designed as a closed container to which the admission to the interior parts is operated by valves and the like.
  • bed is generally used to denote the subsea floor.
  • the splash is a zone between the sea surface to a distance below the sea surface where waves, tidal movements and other movements in the sea causes a relatively uneasily environment.
  • the splash zone is defined in the British Standard and European Norm BS EN 61400-3 2009, terms and definitions 3.43.
  • the first subsea location is a subsea location below the splash zone, such as at least about 2.5 m below the splash zone, such as at least about 5 m below the splash zone, such as at least about 20 m below the splash zone, such as at least about 50 m below the splash zone.
  • the first subsea location is a subsea location from about 10 m to about 100 m below the water surface, such as from about 20 m to about 75 m below the water surface.
  • the distance between the first subsea location and the second subsea location may vary significant.
  • the distance between first subsea location and the second subsea location in substantially vertical direction may in fact vary in a rather large span: in an embodiment the second subsea location is at least about 100 m below the first subsea location, such as at least about 500 m below the first subsea location, such as at least about 1000 m below the first subsea location, such as at least about 2000 m below the first subsea location, such as at least about 2500 m below the first subsea location.
  • the storage container is adapted for the injection fluid, which is stored in the container.
  • the storage container comprises an inlet and an outlet for injection fluid allowing the container to receive and deliver injection fluid.
  • the inlet and outlet are controlled by valves and may be combined as one unit, i.e. the same pipe and coupling serves as inlet and outlet for the injection fluid.
  • the container is a flexible container where the storage container in the second subsea location is encased in a mechanical protection structure, wherein the storage container in the first subsea location is not enclosed in the mechanical protection structure.
  • the storage container can be filled with injection fluid in the first subsea location and then moved to the second subsea location where it can be stored in the mechanical protective structure.
  • the mechanical protection structure can e.g. be a frame, such as a metal frame or it can be a more box-like structure. Both a frame and a box are capable of serving as a mechanical protective structure.
  • the method according to the invention includes moving the flexible storage container from the first location to the second location, comprising encasing the flexible storage container in the mechanical protection structure at the second subsea location.
  • the mechanical protection structure should be able to protect the storage container from any impact, which may appear in the second subsea location, and in an embodiment, the mechanical protection structure is a rigid mechanical protection structure, such as a rigid external container.
  • the rigid external container can e.g. be made from metal or polymer material.
  • the method also provides an embodiment where the storage container, encased in the mechanical protection structure, in the second position is arranged directly on the seabed.
  • the method also includes an embodiment where the storage container is arranged at a foundation structure, such as a foundation and rack structure, preferably the foundation and rack structure is adapted for holding two or more storage containers.
  • the foundation and rack structure are preferably made from metal, such as stainless steel.
  • the foundation and rack structure may comprise one or more locking mechanisms, which can lock and secure the storage containers to the foundation and rack structure.
  • the entire rack structure comprising several storage containers is adapted to be moved between the first subsea location and the second subsea location and visa versa.
  • the entire rack structure comprising several storage containers is adapted to be moved between the first subsea location and the second subsea location and visa versa.
  • the storage container may have desired size and storage capacity, such as a storage capacity from 1 or 2 m 3 , such as about 35 m 3 or about 40 m 3 , and up to several cubic meters.
  • the method according to the invention is also suitable for filling containers with large capacity and in an embodiment of the method the storage container has a storage capacity of at least about 500 m 3 , such as at least about 1000 m 3 , such as at least about 2000 m 3 , such as at least about 4000 m 3 , such as at least about 6000 m 3 , such as at least about 8000 m 3 .
  • the storage container has a capacity to contain injection fluid for about half a year's consumption of injection fluid.
  • the storage container can be replenished every six months.
  • the storage container When the storage container is in the first subsea location, the storage container can be held in the location by lines connected to a surface facility, such as a platform or ship. One or more cranes on the surface facility may serve to keep the storage container in the first subsea location.
  • a tube or hose for filling injection fluid into the storage container can be led from the surface facility to the storage container where it can be coupled to the inlet of the container e.g. by a use of a ROV (remote operated vehicle).
  • ROV remote operated vehicle
  • the surface facility comprises a floating unit such as a platform or a vessel.
  • the surface facility may be a floating production storage and offloading (FPSO) or a floating production vessel.
  • FPSO floating production storage and offloading
  • the method comprises launching the storage container from the surface facility prior to arranging the storage container at the first subsea location, wherein the storage container is preferably substantially empty at the launching, preferably the storage container is passing through a splash zone to reach the first location, the storage container preferably being substantially empty during the passage through the splash zone.
  • the storage container is transported to the place of operation by a vessel or ship. This vessel or ship may also be the surface facility from which the storage container is launched.
  • the storage container can be transferred from the vessel or ship to e.g. a production platform or FPSO, which then serves as the surface facility.
  • the method comprises coupling an injection pipe to the storage container for supplying the injection fluid from the storage container to the subsea facility after having located the storage container at the second location.
  • This operation may also be accomplished by using a ROV.
  • this coupling can also be performed as a fully automated process controlled from e.g. the surface facility.
  • the coupling and decoupling of pipes can also be achieved by mounting coupling devices (such as inlets and outlets) on the underside, i.e. the side facing the seabed, of the storage container.
  • coupling devices such as inlets and outlets
  • Such a solution may enable automated coupling of the reservoir to the injection pipes in the second seabed location.
  • the injection fluid may be any fluid suitable for use in extracting carbonouos fluid, such as oil and gas from a well and for drilling in a well and an embodiment the injection fluid is selected from inhibitors, dispensing agents, descalers, biocides, demulsifiers, buoyant and non-buoyant chemicals, MEG, methanol or any combinations comprising one or more of these.
  • the installation of the rack 1 comprises two vessels 4, 5 floating on the sea surface 6. Each vessel is connected to the rack 1 via lines. By means of the lines shown as 7a and 7b (there may several more lines connecting the rack and the vessels), the rack 1 is lowered from the sea surface 6 to the seabed 3. At the seabed 3 the storage containers 2 are coupled with injection pipes which can deliver injection fluid to the subsea facility.
  • the opposite procedure may take place in a similar manner.
  • the storage containers are decoupled from the injection pipes, e.g. by means of a ROV, and the rack 1 is connected to lines illustrated by 7a and 7b, which connect the rack 1 with the vessels 4, 5.
  • the rack 1 and the vessels are safely connected the rack 1 can be lifted upwards towards the sea surface 6 from the seabed 3 by means of the lines 7a, 7b co-acting with a crane or other lifting means.
  • the rack 1 When the rack 1 has reached the sea surface 6 it can loaded aboard one of the vessels 4, 5 for replenishing the storage containers 2 with injection fluid.
  • the rack may be replaced with another rack with filled storage containers and the rack retrieved from the seabed can be brought ashore for replenishment of the storage containers.
  • FIG. 3 shows the rack 11 in more details.
  • the rack comprise a frame 21 which divide the rack 11 into five compartments 22a, 22b, 22c, 22d, and 22e.
  • the first compartment 22a is mounted four storage containers 12a.
  • the three following compartments 22b, 22c and 22d houses a storage container 12b each.
  • the fifth compartment 22e houses two storage containers 12a.
  • the storage containers 12a and 12b have different capacities and contains different volumes of injection fluid.
  • the storage containers 12a and 12b are selected depending on the consumption of the specific injection fluid.
  • the storage containers 12a are selected for injection fluids, which are consumed in less amounts and the storage containers 12b are selected for injection fluid, which are consumed in larger amounts.
  • the buoyant injection fluid 31 is stored inside the flexible container 41 and in fluid communication with the tube 39 and the perforated tube 40.
  • the coupling device 38 can be coupled to an injection pipe or a refilling hose respectively. When the coupling device is coupled to a refilling hose injection fluid can enter the flexible container 41 via the tube 39 and fill the flexible container 41 so it substantially fill out the interior of the rigid shell.
  • the buoyant injection fluid 31 When the buoyant injection fluid 31 is to be retrieved for use for e.g. injection into a well an injection pipe is coupled to the coupling device 38 and the injection fluid can be retrieved via the tube 39.
  • the flexible container 41 As the flexible container 41 is emptied it will be compressed by sea water entering via the opening 36. Due to the fact, that the injection fluid is buoyant it will seek towards the top part 35 of the storage container 12 and the flexible container 41 will be compressed around the pipe 39 towards the top part 35.
  • the perforated tube 40 surrounding the tube 39 will ensure that there always is fluid communication between the injection fluid 31 in the flexible container 41 and the lower inlet 42 of the tube 39.
  • the external pressure serves to facilitate emptying the flexible container 41.
  • FIG. 5 illustrates the situation when a storage container 12 is storing non-buoyant injection fluid 32.
  • the storage container 12 also comprises an outer rigid shell comprising sidewalls 33, a bottom part 34 and a top part 35.
  • the bottom part 34 comprises an opening 36, which allows the interior of the rigid shell to be in fluid communication with the environment, i.e. the seawater.
  • the top part 35 comprises and opening 37 in which a coupling device 38 is mounted.
  • a tube 39 is mounted to the coupling device and extends into the storage container 12 towards the bottom part 34.
  • a perforated tube 40 is mounted to the coupling device 38 and extends down in the storage container 12 towards the bottom part 34 outside the tube 39.
  • a flexible container 41 is also attached to the coupling device 38 and enclosing the tube 39 and the perforated tube 40.
  • the flexible container 41 may or may not be attached to the bottom part 34 of the rigid shell.
  • the non-buoyant injection fluid 32 is stored inside the flexible container 41 and in fluid communication with the tube 39 and the perforated tube 40.
  • the coupling device 38 can be coupled to an injection pipe or a refilling hose respectively. When the coupling device is coupled to a refilling hose non-buoyant injection fluid can enter the flexible container 41 via the tube 39 and fill the flexible container 41 so it substantially fill out the interior of the rigid shell.
  • the storage container 12 is brought in the first subsea position when the storage container needs to be replenished.
  • the injection fluid is retrieved from the storage container 12 for use in e.g. a well the storage container is in the second subsea position.
  • the storage containers for storing buoyant and non-buoyant injection fluid shown in figure 4 and 5 are only examples and other configurations may be used.
  • the tube 39 need not be mounted in the central part of the container.
  • the tube may be mounted closer to the sidewalls. In other embodiments the tube may be mounted in the sidewall or in the bottom part of the storage container.
  • the perforated tube 40 may be omitted.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
  • Earth Drilling (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)

Claims (16)

  1. Verfahren zum Zuführen von Injektionsflüssigkeit an einer Unterwasseranlage, wobei das Verfahren umfasst
    • Anordnen eines flexiblen Lagerbehälters an einem ersten Unterwasserstandort,
    • Versorgen des Lagerbehälters mit Injektionsflüssigkeit aus einer Meeresoberflächenanlage,
    • Bewegen des Lagerbehälters zu einem zweiten Unterwasserstandort, umfassend ein Einhüllen des flexiblen Lagerbehälters in eine mechanische Schutzstruktur an dem zweiten Unterwasserstandort, und
    • Zuführen der Injektionsflüssigkeit aus dem Lagerbehälter an dem zweiten Unterwasserstandort zu der Unterwasseranlage,
    wobei der zweite Unterwasserstandort näher am Meeresboden liegt als der erste Unterwasserstandort, wobei vorzugsweise der Lagerbehälter an dem zweiten Unterwasserstandort vom Meeresboden gestützt ist.
  2. Verfahren nach Anspruch 1, wobei der erste Unterwasserstandort ein Unterwasserstandort unterhalb der Spritzzone ist, wie beispielsweise mindestens etwa 2,5 m unterhalb der Spritzzone, wie beispielsweise mindestens etwa 5 m unterhalb der Spritzzone, wie beispielsweise mindestens etwa 20 m unterhalb der Spritzzone, wie beispielsweise mindestens etwa 50 m unterhalb der Spritzzone, wobei die Spritzzone wie in der britischen Norm und der europäischen Norm BS EN 61400-3 2009, Begriffe und Definitionen 3.43, definiert ist.
  3. Verfahren nach Anspruch 1 oder Anspruch 2, wobei der erste Unterwasserstandort ein Unterwasserstandort von etwa 10 m bis etwa 100 m unterhalb der Wasseroberfläche ist, wie beispielsweise von etwa 20 m bis etwa 75 m unterhalb der Wasseroberfläche,
    und wobei der zweite Unterwasserstandort mindestens etwa 100 m unterhalb des ersten Unterwasserstandorts liegt, wie beispielsweise mindestens etwa 500 m unterhalb des ersten Unterwasserstandorts, wie beispielsweise mindestens etwa 1000 m unterhalb des ersten Unterwasserstandorts, wie beispielsweise mindestens etwa 2000 m unterhalb des ersten Unterwasserstandorts, wie beispielsweise mindestens etwa 2500 m unterhalb des ersten Unterwasserstandorts.
  4. Verfahren nach einem der vorstehenden Ansprüche, wobei die mechanische Schutzstruktur eine starre mechanische Schutzstruktur ist, wie beispielsweise ein starrer Außenbehälter.
  5. Verfahren nach einem der vorstehenden Ansprüche, wobei der in der zweiten Position in der mechanischen Schutzstruktur eingehüllte Lagerbehälter direkt am Meeresboden angeordnet ist.
  6. Verfahren nach einem der vorstehenden Ansprüche, wobei der Lagerbehälter an einer Fundamentstruktur, wie beispielsweise einer Fundament- und Gestellstruktur, angeordnet ist, wobei vorzugsweise die Fundament- und Gestellstruktur zum Aufnehmen von zwei oder mehr Lagerbehältern angepasst ist.
  7. Verfahren nach einem der vorstehenden Ansprüche, wobei der Lagerbehälter eine Lagerkapazität von mindestens etwa 500 m3, wie beispielsweise mindestens etwa 1000 m3, wie beispielsweise mindestens etwa 2000 m3, wie beispielsweise mindestens etwa 4000 m3, wie beispielsweise mindestens etwa 6000 m3, wie beispielsweise mindestens etwa 8000 m3, aufweist.
  8. Verfahren nach einem der vorstehenden Ansprüche, wobei der Lagerbehälter während dem Versorgen des Lagerbehälters mit Injektionsflüssigkeit von der Meeresoberflächenanlage im Wesentlichen an dem ersten Standort gehalten wird, wobei der Lagerbehälter vorzugsweise unter Verwendung einer oder mehrerer Leitungen an dem ersten Standort gehalten wird, wie beispielsweise einer oder mehrerer Förderleitungen; einer oder mehrerer Auftriebsanordnungen und/oder einer oder mehrerer Ballastanordnungen.
  9. Verfahren nach einem der vorstehenden Ansprüche, wobei die Unterwasseranlage eine Unterwasseranlage umfasst, die ausgewählt ist aus einer Bohranlage oder einer Produktionsanlage, wobei vorzugsweise die Injektionsflüssigkeit aus dem Lagerbehälter an dem zweiten Unterwasserstandort einem Injektionspunkt der Unterwasseranlage zugeführt wird, wie beispielsweise einem Injektionspunkt, umfassend ein Schrägloch mit Injektionspunkt, einem Verteiler mit Injektionspunkt, einer Strömungsleitung mit Injektionspunkt oder einem Eruptionskreuz mit Injektionspunkt, wobei vorzugsweise der Injektionspunkt in der Nähe des Meeresbodens liegt, wie beispielsweise vom Meeresbodens bis etwa 50 m oberhalb oder unterhalb des Meeresbodens in vertikaler Richtung.
  10. Verfahren nach einem der vorstehenden Ansprüche, wobei die Meeresoberflächenanlage eine schwimmende Einheit umfasst, wie beispielsweise eine Plattform oder einen Behälter.
  11. Verfahren nach einem der vorstehenden Ansprüche, wobei das Verfahren ein Zu-Wasser-Bringen des Lagerbehälters von der Oberflächenanlage vor Anordnen des Lagerbehälters an dem ersten Unterwasserstandort umfasst, wobei der Lagerbehälter beim Zu-Wasser-Bringen vorzugsweise im Wesentlichen leer ist, wobei der Lagerbehälter vorzugsweise eine Spritzzone durchläuft, um den ersten Standort zu erreichen, wobei der Lagerbehälter während des Durchgangs durch die Spritzzone vorzugsweise im Wesentlichen leer ist.
  12. Verfahren nach einem der vorstehenden Ansprüche 1-10, wobei das Verfahren ein Anheben des Lagerbehälters von seinem zweiten Standort vor Anordnen des Lagerbehälters an dem ersten Unterwasserstandort umfasst, wobei der Lagerbehälter vor dem Anheben von dem zweiten Standort vorzugsweise im Wesentlichen leer ist, und wobei das Zuführen der Injektionsflüssigkeit zu dem Lagerbehälter an dem ersten Standort ein Nachfüllen von Injektionsflüssigkeit ist, wobei das Verfahren den weiteren Schritt des Waschens und/oder Spülens des Lagerbehälters vor dem Nachfüllen von Injektionsflüssigkeit umfasst.
  13. Verfahren nach Anspruch 12, wobei das Verfahren ein Entkoppeln eines Injektionsrohrs vom Lagerbehälter vor dem Anheben des Lagerbehälters von dem zweiten Standort umfasst.
  14. Verfahren nach einem der vorstehenden Ansprüche, wobei das Verfahren ein Ankoppeln eines Injektionsrohrs an den Lagerbehälter umfasst, um die Injektionsflüssigkeit aus dem Lagerbehälter der Unterwasseranlage zuzuführen, nachdem der Lagerbehälter an dem zweiten Standort lokalisiert wurde.
  15. Verfahren nach einem der vorstehenden Ansprüche, wobei das Verfahren ein Ankoppeln eines Zufuhrrohrs an den Lagerbehälter zum Versorgen des Lagerbehälters mit Injektionsflüssigkeit von der Oberflächenanlage und ein Entkoppeln des Zufuhrrohrs vom Lagerbehälter vor Bewegen des Lagerbehälters von dem ersten Standort zu dem zweiten Standort umfasst, wobei das Ankopplen des Zufuhrrohrs an den Lagerbehälter vorzugsweise an dem ersten Standort durchgeführt wird.
  16. Verfahren nach einem der vorstehenden Ansprüche, wobei die Injektionsflüssigkeit ausgewählt ist aus Inhibitoren, Dispergiermitteln, Entkalkungsmitteln, Bioziden, Demulgatoren, schwimmfähigen und nicht schwimmfähigen Chemikalien, MEG, Methanol oder beliebigen Kombinationen, die eines oder mehrere davon umfassen.
EP19749338.0A 2018-08-20 2019-08-02 Verfahren zur zuführung von injektionsflüssigkeit an einer unterwasseranlage Active EP3841270B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
DKPA201870534 2018-08-20
PCT/EP2019/070864 WO2020038703A1 (en) 2018-08-20 2019-08-02 A method of supplying injection fluid to a subsea facility

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EP3841270A1 EP3841270A1 (de) 2021-06-30
EP3841270B1 true EP3841270B1 (de) 2023-12-13

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US (1) US20210310324A1 (de)
EP (1) EP3841270B1 (de)
AU (1) AU2019324447A1 (de)
BR (1) BR112021003148A8 (de)
CA (1) CA3107074A1 (de)
WO (1) WO2020038703A1 (de)

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KR20230156119A (ko) 2021-03-12 2023-11-13 마카이 오션 엔지니어링, 인크. 해저 앵커리지 설치 시스템

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FR2852917B1 (fr) * 2003-03-26 2005-06-24 Saipem Sa Receptacle a compartiments etanches et procede de mise en place pour recuperer des effluents polluants d'une epave
AU2012357694A1 (en) * 2011-12-19 2014-05-22 Eda Kopa (Solwara) Limited A delivery method and system
US9156609B2 (en) 2013-04-06 2015-10-13 Safe Marine Transfer, LLC Large subsea package deployment methods and devices
AU2016258009B2 (en) * 2015-05-05 2020-04-16 Safe Marine Transfer, LLC Subsea storage tank, method of installing and recovering such a tank, system, method to retrofit a storage tank and method of refilling a subsea storage tank
US9470365B1 (en) * 2015-07-13 2016-10-18 Chevron U.S.A. Inc. Apparatus, methods, and systems for storing and managing liquids in an offshore environment

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EP3841270A1 (de) 2021-06-30
CA3107074A1 (en) 2020-02-27
WO2020038703A1 (en) 2020-02-27
AU2019324447A1 (en) 2021-02-18
US20210310324A1 (en) 2021-10-07
BR112021003148A8 (pt) 2022-11-08
BR112021003148A2 (pt) 2021-05-11

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