WO2011084164A1 - Systèmes et procédés pour installation et retrait de stockage de gaz sous-marin - Google Patents

Systèmes et procédés pour installation et retrait de stockage de gaz sous-marin Download PDF

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Publication number
WO2011084164A1
WO2011084164A1 PCT/US2010/021445 US2010021445W WO2011084164A1 WO 2011084164 A1 WO2011084164 A1 WO 2011084164A1 US 2010021445 W US2010021445 W US 2010021445W WO 2011084164 A1 WO2011084164 A1 WO 2011084164A1
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WO
WIPO (PCT)
Prior art keywords
gas
gas storage
tank
storage vessel
vessel
Prior art date
Application number
PCT/US2010/021445
Other languages
English (en)
Inventor
James V. Maher
Edward E. Horton, Iii
Lyle D. Finn
Original Assignee
Horton Wison Deepwater, Inc.
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Horton Wison Deepwater, Inc. filed Critical Horton Wison Deepwater, Inc.
Priority to BRPI1008151-8A priority Critical patent/BRPI1008151B1/pt
Priority to US13/144,461 priority patent/US20120260839A1/en
Publication of WO2011084164A1 publication Critical patent/WO2011084164A1/fr

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C3/00—Vessels not under pressure
    • F17C3/005—Underground or underwater containers or vessels
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65D—CONTAINERS FOR STORAGE OR TRANSPORT OF ARTICLES OR MATERIALS, e.g. BAGS, BARRELS, BOTTLES, BOXES, CANS, CARTONS, CRATES, DRUMS, JARS, TANKS, HOPPERS, FORWARDING CONTAINERS; ACCESSORIES, CLOSURES, OR FITTINGS THEREFOR; PACKAGING ELEMENTS; PACKAGES
    • B65D88/00—Large containers
    • B65D88/78—Large containers for use in or under water
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65D—CONTAINERS FOR STORAGE OR TRANSPORT OF ARTICLES OR MATERIALS, e.g. BAGS, BARRELS, BOTTLES, BOXES, CANS, CARTONS, CRATES, DRUMS, JARS, TANKS, HOPPERS, FORWARDING CONTAINERS; ACCESSORIES, CLOSURES, OR FITTINGS THEREFOR; PACKAGING ELEMENTS; PACKAGES
    • B65D90/00—Component parts, details or accessories for large containers
    • B65D90/02—Wall construction
    • B65D90/04—Linings
    • B65D90/046—Flexible liners, e.g. loosely positioned in the container
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65D—CONTAINERS FOR STORAGE OR TRANSPORT OF ARTICLES OR MATERIALS, e.g. BAGS, BARRELS, BOTTLES, BOXES, CANS, CARTONS, CRATES, DRUMS, JARS, TANKS, HOPPERS, FORWARDING CONTAINERS; ACCESSORIES, CLOSURES, OR FITTINGS THEREFOR; PACKAGING ELEMENTS; PACKAGES
    • B65D2590/00—Component parts, details or accessories for large containers
    • B65D2590/02—Wall construction
    • B65D2590/04—Linings
    • B65D2590/043—Flexible liners
    • B65D2590/046—Bladders
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65D—CONTAINERS FOR STORAGE OR TRANSPORT OF ARTICLES OR MATERIALS, e.g. BAGS, BARRELS, BOTTLES, BOXES, CANS, CARTONS, CRATES, DRUMS, JARS, TANKS, HOPPERS, FORWARDING CONTAINERS; ACCESSORIES, CLOSURES, OR FITTINGS THEREFOR; PACKAGING ELEMENTS; PACKAGES
    • B65D88/00—Large containers
    • B65D88/02—Large containers rigid
    • B65D88/06—Large containers rigid cylindrical
    • B65D88/08—Large containers rigid cylindrical with a vertical axis
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/01—Shape
    • F17C2201/0104—Shape cylindrical
    • F17C2201/0109—Shape cylindrical with exteriorly curved end-piece
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/01—Shape
    • F17C2201/0104—Shape cylindrical
    • F17C2201/0119—Shape cylindrical with flat end-piece
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/01—Shape
    • F17C2201/0147—Shape complex
    • F17C2201/0166—Shape complex divided in several chambers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/01—Shape
    • F17C2201/0176—Shape variable
    • F17C2201/018—Shape variable with bladders
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/01—Shape
    • F17C2201/0176—Shape variable
    • F17C2201/0185—Shape variable with separating membrane
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/03—Orientation
    • F17C2201/032—Orientation with substantially vertical main axis
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/05—Size
    • F17C2201/054—Size medium (>1 m3)
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2203/00—Vessel construction, in particular walls or details thereof
    • F17C2203/01—Reinforcing or suspension means
    • F17C2203/011—Reinforcing means
    • F17C2203/012—Reinforcing means on or in the wall, e.g. ribs
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2203/00—Vessel construction, in particular walls or details thereof
    • F17C2203/01—Reinforcing or suspension means
    • F17C2203/011—Reinforcing means
    • F17C2203/013—Reinforcing means in the vessel, e.g. columns
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2203/00—Vessel construction, in particular walls or details thereof
    • F17C2203/06—Materials for walls or layers thereof; Properties or structures of walls or their materials
    • F17C2203/0634—Materials for walls or layers thereof
    • F17C2203/0636—Metals
    • F17C2203/0639—Steels
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2203/00—Vessel construction, in particular walls or details thereof
    • F17C2203/06—Materials for walls or layers thereof; Properties or structures of walls or their materials
    • F17C2203/0634—Materials for walls or layers thereof
    • F17C2203/0658—Synthetics
    • F17C2203/0663—Synthetics in form of fibers or filaments
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2205/00—Vessel construction, in particular mounting arrangements, attachments or identifications means
    • F17C2205/01—Mounting arrangements
    • F17C2205/0123—Mounting arrangements characterised by number of vessels
    • F17C2205/013—Two or more vessels
    • F17C2205/0134—Two or more vessels characterised by the presence of fluid connection between vessels
    • F17C2205/0142—Two or more vessels characterised by the presence of fluid connection between vessels bundled in parallel
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2205/00—Vessel construction, in particular mounting arrangements, attachments or identifications means
    • F17C2205/01—Mounting arrangements
    • F17C2205/0153—Details of mounting arrangements
    • F17C2205/0184—Attachments to the ground, e.g. mooring or anchoring
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0107—Single phase
    • F17C2223/0123—Single phase gaseous, e.g. CNG, GNC
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/01—Propulsion of the fluid
    • F17C2227/0192—Propulsion of the fluid by using a working fluid
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/03—Control means
    • F17C2250/032—Control means using computers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/04—Reducing risks and environmental impact
    • F17C2260/042—Reducing risk of explosion
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0118—Offshore
    • F17C2270/0128—Storage in depth

Definitions

  • the invention relates generally to subsea gas storage systems. More particularly, the invention relates to the deployment and removal of subsea gas storage systems.
  • Oil at standard temperature and pressure conditions is a relatively dense liquid, and thus, is suitable for transportation in tankers and storage in tanks, thereby enabling a global market for oil.
  • natural gas is a gas at stp, it is less suited to transportation in tankers and storage in tanks. Consequently, most natural gas is transported through pipelines, which rely on a local source or supply, thereby limiting natural gas to a generally local market
  • a primary challenge in the development of a global natural gas industry is that natural gas, at stp, is extremely diffuse, and thus, has relatively little economic value for a given volume as compared to oil (a difference of three orders of magnitude at $7/MCF for natural gas and $50/BBL for oil). Due to this difference in economic value for a given volume of natural gas vs. oil and the gaseous state of natural gas at stp, transport of natural gas at stp over long distances is not economically feasible.
  • Various methods for achieving more favorable ratios of gas value for a given volume such as compressing or liquefying the natural gas, are commonly used to make the transmission and storage of natural gas more economically attractive.
  • Compression is the most commonly used method employed for the transportation of natural gas in pipeline systems.
  • liquefaction is used to create Liquified Natural Gas (LNG)
  • compression is used to create Compressed Natural Gas (CNG).
  • LNG Liquified Natural Gas
  • CNG Compressed Natural Gas
  • the LNG and CNG undergo some processing to conform the natural gas to conditions (e.g., pressure, temperature, etc.) suitable for standard pipeline systems.
  • Natural gas at stp is commonly stored in relatively large underground natural caverns. In such cases, the storage of the natural gas is dependent on the location and availability of such underground storage caverns (e.g., underground natural salt caverns). Further, there have been many accidents related to these caverns, including fires and explosions. LNG and CNG also present storage complications. Typically, LNG is stored onshore in pressurized or cryogenic containment tanks, both of which are relatively expensive and dangerous. Due to the risks and dangers of onshore LNG storage, it has become increasingly difficult too locate LNG regassification units despite large market demands. CNG has not been used for natural gas storage to date, possibly due to the lack of availability of efficient storage means.
  • the method comprises (a) coupling an upper end of the gas storage vessel to a deployment apparatus positioned at the surface of the water.
  • the gas storage vessel has a total dry weight and a lower end opposite the upper end.
  • the gas storage vessel also includes a storage tank defining an inner region inside the tank and an exterior region outside the tank.
  • the method comprises (b) lowering the gas storage vessel below the surface of the water with the deployment apparatus.
  • the method comprise (c) pumping a buoyancy control gas into the inner region of the tank during (b). The buoyancy control gas in the inner region of the tank generates a buoyancy force acting on the gas storage vessel during (b).
  • the method comprises (a) disposing a gas storage vessel on the sea floor.
  • the gas storage vessel has an upper end distal the sea floor and a lower end engaging the sea floor and includes a gas storage tank defining an inner region inside the tank and an exterior region outside the tank.
  • the gas storage tank also includes a first inlet in fluid communication with the inner region, a first valve that controls the flow of fluid through the first inlet, and a port in fluid communication with the inner region and the exterior region.
  • the method comprises (b) pumping a buoyancy control gas through the first valve and first inlet into the inner region to generate a buoyancy force acting on the gas storage vessel.
  • the method comprises displacing water in the inner region with the buoyancy control gas.
  • the method comprises (d) flowing water through the port from the inner region to the outer region.
  • the method comprises moving the gas storage vessel from the sea floor toward the surface.
  • the system comprises a subsea gas storage vessel.
  • the storage vessel includes a gas storage tank defining an inner region inside the tank and an exterior region outside the tank.
  • the tank has an upper end and a lower end opposite the upper end.
  • the gas storage tank also includes a gas inlet adapted to flow the gas into the inner region, an air inlet adapted to flow air into the inner region, a port in fluid communication with the inner region and the outer region.
  • the gas storage tank includes a valve adapted to control the flow of gas through the gas inlet.
  • the gas storage tank includes a valve adapted to control the flow of air through the air inlet.
  • Figure 1 is a schematic cross-sectional view of an embodiment of a subsea gas storage vessel
  • Figure 2 is a schematic cross-sectional view of the subsea gas storage vessel of Figure 1 during deployment subsea;
  • Figure 3 is a schematic cross-sectional view of the subsea gas storage vessel of Figure 1 during anchoring to the sea floor
  • Figure 4 is a schematic cross-sectional view of the subsea gas storage vessel of Figure 1 anchored to the sea floor for subsea gas storage operations;
  • Figure 5 is a schematic cross-sectional view of the subsea gas storage vessel of Figure 1 during the sea floor disengagement phase of removal and/or relocation operations;
  • Figure 6 is a schematic cross-sectional view of the subsea gas storage vessel of Figure 1 during the lifting phase of removal and/or relocation operations;
  • Figure 7 is a schematic cross-sectional view of the subsea gas storage vessel of Figure 4 illustrating the hydrostatic pressure of the sea water and the pressure of the stored gas;
  • Figure 8 is a schematic view of a system for supplying gas to and pulling gas from the subsea gas storage vessel of Figure 4;
  • Figure 9 is a schematic cross-sectional view of an embodiment of a subsea gas storage vessel anchored to the sea floor for subsea gas storage operations;
  • Figure 10 is a schematic cross-sectional view of an embodiment of a subsea gas storage vessel anchored to the sea floor for subsea gas storage operations;
  • Figure 11 is an embodiment of a combine water/air pumping system for deploying the subsea gas storage vessel of Figure 1;
  • Figure 12 is a front view of an embodiment of a compartmentalized subsea gas storage vessel
  • Figure 13 is a top schematic view of the subsea gas storage vessel of Figure 11;
  • Figure 14 is a schematic cross-sectional view of the subsea gas storage vessel of Figure 11 ;
  • Figures 15 and 16 are schematic views of deployment system for deploying, removing, lifting, and relocating a subsea gas storage vessel.
  • the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to... .”
  • the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection, or through an indirect connection via other devices, components, and connections.
  • the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis.
  • Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior apparatus, systems, and methods.
  • embodiments described herein provide subsea gas storage installation and removal apparatus, systems, and methods that offer the potential for improved deployment, relocation, and hydrate prevention/overtopping control as compared to conventional apparatus, systems, and methods.
  • FIG 1-6 an embodiment of a subsea gas storage apparatus or vessel 10 is schematically shown.
  • vessel 10 is shown at the sea surface before being submerged subsea; in Figure 2, vessel 10 is shown being lowered in sea water 3 for subsea deployment; in Figure 3, vessel 10 is shown being anchored to the sea floor 4; in Figure 4, vessel 10 is shown anchored to sea floor 4 during subsea gas storage operations; in Figure 5, vessel 10 is shown disengaging sea floor 4 during removal and/or relocation operations; and in Figure 6, vessel 10 is shown being lifted from sea floor 4 after disengagement from sea floor 4 for during removal and/or relocation operations.
  • Vessel 10 has a central or longitudinal axis 15 and extends between an upper end 10a and a lower end 10b.
  • vessel 10 includes a rigid, thin- walled storage tank 20, a mud skirt 30 at lower end 10b, and a ballast chamber 40 containing ballast 41 proximal lower end 10b between tank 20 and skirt 30.
  • Vessel 10 is designed to be deployed and positioned subsea in a vertical orientation with axis 15 generally perpendicular to the sea floor and upper end 10a positioned above lower end 10b.
  • the design of vessel 10 including ballast chamber 40 and associated ballast 41 below tank 20 enhances the stability of vessel 10 since the center of gravity of vessel 10 is positioned below the center of buoyancy of vessel 10.
  • the relatively thin- walled tank 20 functions as a gas storage tank.
  • Tank 20 comprises rigid walls preferably made of steel or composite material.
  • the wall thickness would depend primarily on the anticipated pressure differentials experienced by tank 20.
  • the wall thickness will range from about 0.5 in. to about 1.5 in.
  • the walls may include reinforcing ribs (not shown) to assist in strengthening the walls.
  • the reinforcing ribs can be either inside the tank or outside, with a preference for outside due to its ease of construction and inspection.
  • tank 20 placement of reinforcing ribs on the outside of the tank (e.g., tank 20) prevents the ribs from interfering with gas storage hardware disposed within the tank such as gas storage bag 50 described in more detail below.
  • the top of tank 20 can be formed of either a hemispherical or elliptical head typical of pressure vessel fabrication. It can alternately be stiffened panel construction with a flat top surface.
  • Storage tank 20 defines an inner region or chamber 21 within tank 20 and an exterior region 22 outside tank 20.
  • a flexible gas storage bag 50 is disposed within inner chamber 21, thereby dividing chamber 21 into a first region 21a inside chamber 21 and bag 50, and a second region 21b inside chamber 21 but outside bag 50.
  • gas storage bag 50 includes a stored gas port 51. It should be appreciated that when bag 50 is collapsed (i.e., empty), the volume of second region 21b is close to zero.
  • Storage tank 20 also includes a buoyancy control gas outlet 23 and a buoyancy control gas inlet 24, each in fluid communication with second region 21b.
  • buoyancy control gas outlet 23 is at upper end 10a
  • buoyancy control gas inlet 24 is positioned distal upper end 10a and proximal ballast chamber 40.
  • the flow of a air 6 out of and into second region 21b through outlet 23 and inlet 24, respectively, is controlled by an outlet valve 23a and inlet valve 24a, respectively.
  • buoyancy control gas 6 may comprise any suitable gas, in embodiments described herein, buoyancy control gas 6 is air, and thus, buoyancy control gas 6 may also be referred to as air 6.
  • storage tank 20 also includes a stored gas conduit 25 in fluid communication stored gas port 51 in gas storage bag 50.
  • stored gas conduit 25 and gas port 51 are positioned at upper end 10a, however, in other embodiments, the stored gas conduit (e.g., stored gas conduit 25) and the gas port (e.g., gas port 51) may be disposed at other suitable locations.
  • the flow of a stored gas 5 into and out of gas storage bag 50 through conduit 25 and gas port 51 is controlled by a valve 25a.
  • one conduit 25, port 51 and valve 25 a are used to flow the stored gas 5 into and out of storage tank 20.
  • conduit 25 more than one conduit (e.g., conduit 25), gas port (e.g., gas port 51), and valve (e.g., valve 25) may be used for the flow of storage gas into the tank (e.g., tank 20).
  • a control system (not shown) may be used to control each valve 23, 24, 25 from the surface.
  • Storage tank 20 further includes a through port 26 distal upper end 10a and generally proximal ballast chamber 40.
  • Port 26 is essentially a through hole or opening in the lower portion of storage tank 20 that allows fluid communication between outer region 22 and second region 21b. It should be appreciated that flow through port 26 is not controlled by a valve or other flow control device. Thus, port 26 permits the free flow of fluid between regions 21b, 22. Without being limited by this or any particular theory, the flow of fluid through port 26 will depend on the depth of vessel 10 and associated hydrostatic pressure of water 5, the pressure of stored gas 5 in first region 21b (if any), and the pressure of buoyancy control gas in storage second region 21b (if any).
  • sea water 3 may flow through port 26 into or out of tank 20 and second region 21b; during anchoring operations (Figure 3), sea water 3 flows through port 26 into tank 20 and second region 21b; during disengagement of vessel 10 from sea floor 4 (Figure 5), sea water 3 flows through port 26 out of tank 20 and second region 21b; and during lifting operations (Figure 6), air 6 flow out of tank and second region 21b.
  • tank 20 and vessel 10 may have any suitable geometry including, without limitation, rectangular, cylindrical, spherical, etc., and any suitable size.
  • the size of tank 20 and vessel 10 will depend, at least in part, on the desired volume within tank 20 for gas storage.
  • vessel 10 and tank 20 are cylindrical.
  • tank 20 and vessel 10 may have any suitable size.
  • the size of tank 20 and vessel 10 will depend, at least in part, on the desired volume within tank 20 for gas storage.
  • Vessel 10 has a total axial length L 10 measured between ends 10a, b, and tank 20 has a total axial length L 2 o measured between upper end 10a and ballast chamber 40.
  • vessel 10 has a maximum outer diameter D 10 and tank 20 has a maximum outer diameter D 2 o.
  • diameter D 10 and diameter D 2 o are the same.
  • vessel 10 and tank 20 may have any suitable lengths L 10 , L 20 and diameters D 10 , D 20 .
  • length L 10 is preferably at least 50 ft
  • length L 20 is preferably at least 40 ft.
  • diameters D 10 , D 2 o are preferably each at least 20 ft.
  • lengths L 10 is about 50 ft
  • L 20 is about 40 ft
  • diameters D 10 , D 20 are each about 26 ft.
  • the primary design considerations in determining lengths L 10 , L 20 and diameter D 10 , D 20 are total gas storage volume and dry weight of vessel 10.
  • the tank diameter e.g., diameter D 20
  • the tank length e.g., length L 20
  • the tank design pressure requirements decrease (i.e., the maximum pressure differential the tank must be designed to withstand decreases).
  • the tank diameter or width may be increased and the tank length or height may be decreased.
  • a larger tank diameter may also enhance anchoring capabilities for a given tank gas storage volume.
  • Flexible gas storage bag 50 is designed to expand when the pressure in first region 21a is greater than the pressure in second region 21b, and contract when the pressure in first region 21a is less than the pressure in second region 21b. Further, when first region 21a is substantially empty, flexible storage bag 50 assumes a generally collapsed configuration.
  • first region 21a is substantially empty and bag 50 is collapsed.
  • first region 21a is at least partially filled with a stored gas 5 and bag 50 is at least partially expanded.
  • second region 21b comprises sea water 3 and a air 6; and as shown in Figure 4, during subsea gas storage operations, second region 21b comprises sea water 3.
  • embodiments described herein are generally directed to the subsea storage of natural gas, in which case stored gas 5 is natural gas.
  • the stored gas e.g., stored gas 5
  • the stored gas may be any gas for which subsea storage is desired (e.g., C0 2 ).
  • bag 50 provides physical separation of stored gas 5 in first region 21a and sea water 3 in second region 21b, thereby reducing and/or eliminating the potential for the undesirable formation of hydrates and undesirable methane releases.
  • bag 50 may comprise any flexible, pliable, and expandable bag suitable for gas storage.
  • a variety of gas storage bags currently on the market may be used for bag 50.
  • One example of a bag that may be employed for bag 50 is Large Fuel Bladder manufactured and sold by Interstate Products of Sarasota, Florida.
  • Most conventional bags for gas storage are made from a flexible, pliable, and expandable vinyl, polyester, or polymeric material.
  • conventional gas storage bags may be unsuitable (e.g., not capable of handling the desired gas storage volume and/or pressures) and/or cost prohibitive to design and build.
  • each bag must be placed in fluid communication with the stored gas conduit so that stored gas may be flowed into or out of each bag or compartment.
  • Such designs may enable the use of conventional of gas storage bags or cost effective design of new bags. Further, such designs may provide some advantages in terms of minimizing the environmental impacts should one relatively small bag or compartment rupture as compared to the rupture of a single large bag.
  • the hydrostatic pressure 61 and associated forces of sea water 3 in outer region 22, the pressure 62 and associated forces of sea water 3 in second region 21b within tank 20, and the pressure 63 and associated forces of stored gas 5 in bag 50 are schematically shown during subsea gas storage operations.
  • the hydrostatic pressure 61 of sea water 3 outside tank 20 increases with depth, and since port 26 allows the free movement of sea water 3 into and out of tank 20, the pressure 62 of sea water 3 within tank 20 also varies with depth and corresponds to the hydrostatic pressure 61 of sea water 3 in outer region 22 at the equivalent depth.
  • the pressure 63 of stored gas 5 within bag 5 may vary over time (e.g., as gas 5 is pumped into or removed from bag 50), the pressure 63 of stored gas 5 within bag 50 and first region 21a is substantially uniform at all locations within bag 50.
  • the gas pressure gradient is relatively small compared to the water pressure gradient, and therefore the gas pressure differential over the height of the bag (e.g., bag 50) is negligible.
  • bag 50 During subsea gas storage operations, if the pressure 63 of stored gas 5 in bag 50 is less than the pressure 62 of sea water 3 in second region 21b at a region along the interface 27 between bag 50 and sea water 3 in tank 20, then bag 50 will be compressed at that region and sea water 3 will flow into tank 20 through port 26. However, if the pressure 63 of stored gas 5 in bag 50 is greater than the pressure 62 of sea water at a region along interface 27, then bag 50 will expand at that region and sea water 3 will flow out of tank 20 through port 26. Thus, bag 50 and stored gas 5 within bag 50 will compress and expand based on any pressure differential across bag 50 along interface 27. Since the pressure 62 of any sea water 3 within tank 20 decreases as depth decreases, any pressure differential between gas pressure 63 and water pressure 62 within tank 20 will tend to be greatest proximal upper end 10a.
  • Flexible bags for gas storage may rupture or burst if the pressure inside the bag is sufficiently greater than the pressure outside the bag.
  • flexible bags for gas storage are typically designed and rated to withstand a maximum pressure differential, which may be referred to as the "burst" or “rupture” pressure differential.
  • the pressure differential During radial expansion of bag 50 (i.e., before bag 50 engages the wall of tank 20), bag 50 is subject to the pressure differential between stored gas 5 in bag 50 and sea water 3 radially positioned between bag 50 and tank 20 in second region 21b.
  • the maximum pressure differential experienced by bag 50 during radial expansion is the pressure differential proximal upper end 10a.
  • Bag 50 is preferably designed to withstand the maximum anticipated pressure differential proximal upper end 10a during radial expansion, and designed and sized to expand radially outward into engagement with the walls of tank 20 before the maximum pressure differential proximal upper end 10a reaches the "burst" pressure differential of bag 50.
  • the upper portion of the bag e.g., bag 50
  • the rigid walls of tank 20 (as opposed to bag 50) support the maximum pressure differential.
  • tank 20 is preferably designed to withstand, at a minimum, the maximum anticipated pressure differential between hydrostatic pressure 61 and pressure 63 proximal upper end 10a.
  • skirt 30 functions to positively engage the sea floor 4 and restrict and/or prevent the lateral movement of vessel 10 once positioned at the sea floor 4 for gas storage operations.
  • Skirt 30 extends axially downward from ballast chamber 40 and circumferentially around the entire periphery of vessel 10, thereby defining a recess 31 at lower end 10b.
  • vessel 10 is urged downward and skirt 30 is pushed into sea floor 4.
  • skirt 30 penetrates the sea floor 4 and recess 31 is filled with mud.
  • the lateral movement of vessel 10 is restricted by the mud engaging both the inside and outside of skirt 30 as well as suction that may arise within recess 31 between vessel 10 and the sea floor 4.
  • vessel 10 includes a suction control apparatus 34 that can increase or decrease the suction forces in recess 31.
  • Suction control apparatus 34 comprises a fluid conduit 35 extending to recess 31 and a valve 36.
  • Fluid conduit 35 is in fluid communication with recess 31 and valve 36 controls fluid flow into and out of recess 31 - when valve 36 is in a closed position, flow through conduit 34 is restricted and/or prevented, and when valve 36 is in an opened position, flow through conduit 34 is permitted.
  • Suction control apparatus 34 is controllably operated to increase or decrease the suction forces within recess 31 as desired. As shown in Figure 3, during anchoring of vessel 10 to the sea floor 4, suction control apparatus 34 may be used to generate and/or increase suction forces in recess 31 to pull vessel 10 into engagement with sea floor 4 and urge skirt 30 into sea floor 4. Suction forces in recess 31 may also be generated and/or increased by suction control apparatus 34 during subsea gas storage operations ( Figure 4) to ensure vessel 10 is properly seated on sea floor 4 in the desired orientation.
  • Suction forces within recess 31 are generated and/or increased with suction control apparatus 34 by opening valve 36 (if not already opened) and pumping a mixture of mud and sea water (designated by reference numeral 7) out of recess 31 through conduit 35 and valve 36.
  • control apparatus 34 may be used to reduce suction forces in recess 31.
  • suction forces within recess 31 are decreased with suction control apparatus 34 by opening valve 36 (if not already opened) and pumping sea water 3 through conduit 35 and valve 36 into recess 31.
  • ballast 41 is contained within ballast chamber 40.
  • ballast 41 may comprise any type of ballast.
  • ballast 41 may comprise permanent solid ballast (e.g., concrete ballast), removable solid ballast (e.g., hematite, magnetite, etc.), sea water 5, or combinations thereof.
  • ballast 41 is preferably a relatively dense solid ballast such as hematite or magnetite.
  • Ballast 41 may be installed in ballast chamber 40 at the surface or at depth. Installing ballast 41 at the surface is usually easier since it is more easily monitored and controlled. However, installation of ballast 41 at the surface may increase the demands on the crane (or other device at the surface) that controllably deploys vessel 10 from the surface.
  • ballast 41 counteracts the upward vertical buoyancy forces resulting from the stored gas 5 and/or air 6 in tank 20.
  • the quantity and weight of ballast 41 is chosen to achieve the desired total dry weight of vessel 10.
  • the dry weight of vessel 10 is preferably greater than the total buoyant forces acting on vessel during all operational phases of vessel 10 (e.g., deployment, anchoring, gas storage, disengaging, removal, and relocation of vessel 10).
  • the difference between the dry weight of vessel 10 and the buoyancy forces acting on vessel 10 enables the submersion and lowering of vessel 10 subsea; during gas storage operations (Figure 4), the difference between the dry weight of vessel 10 and the buoyancy forces acting on vessel 10 restrict movement of vessel 10 and maintains the position of vessel 10 at the sea floor 4; during disengagement of vessel 10 from the sea floor ( Figure 5) and lifting of vessel 10 ( Figure 6) for removal and/or relocation, the difference between the dry weight of vessel 10 and the buoyancy forces acting on vessel 10 allows for a controlled, managed lift as will be described in more detail below.
  • buoyancy control gas or air 6 is used to reduce the static load of vessel 10.
  • vessel 10 is connected at upper end 10a to a deployment apparatus at the surface such as a crane.
  • the dry weight of vessel 10 is preferably greater than the maximum buoyancy forces acting on vessel 10 during deployment, and thus, vessel 10 naturally wants to begin sinking. It should be appreciated that the maximum possible buoyant forces resulting from air 6 in tank 20 during deployment occurs when second region 21b is completely filled with air 6 from upper end 10a to port 26. No greater buoyant force can be achieved during deployment since any additional air volume will simply exit tank 20 through port 26.
  • the deployment apparatus connected to upper end 10a applies an upward, vertical lifting force to upper end 10a and vessel 10 to manage and control the rate at which vessel 10 submerges subsea.
  • the vertical lifting force exerted by the deployment apparatus may also be referred to as the hook load.
  • the lifting force applied at upper end 10a and the design of vessel 10 having its center of buoyancy above its center of gravity maintain the substantially vertical orientation of vessel 10 during deployment.
  • the buoyancy forces acting on vessel 10 decrease.
  • This effect tends to be greatest proximal the sea surface because the initial pressure of the air 6 in second region 21b is relatively low and a small increase in water depth can drastically reduce buoyancy of vessel 10.
  • the change in the pressure of the air 6 in second region 21b for a given depth change is constant (linear with density of water), however, the initial pressure of air 6 is relatively high, and thus, the volume of the air 6 in second region 21b is much slower.
  • valve 24a is opened and air 6 is pumped through valve 24a and inlet 24 into second region 21b of tank 20 during the deployment process to maintain a sufficient buoyant force.
  • the total weight of vessel 10 minus the buoyant force is preferably greater than zero (to prevent an uncontrolled ascent of vessel 10) and less than the maximum hook load capacity of the deployment apparatus (to ensure the maximum hook load capacity is not exceeded).
  • skirt 30 begins to engage and penetrate the sea fioor 4.
  • valve 24a is closed and pumping of air 6 through inlet 24 into second region 21b is ceased, and valve 23 a is opened to allow any air 6 in second region 21b to exit inner region 21b.
  • sea water 3 flows through port 26 and fills the remainder of second region 21b, thereby reducing and/or eliminating buoyant forces acting on vessel 10.
  • skirt 30 penetrates further into sea floor 4 under the weight of vessel 10.
  • suction control apparatus 34 may be employed as previously described to increase suction forces in recess 31 and pull vessel 10 further into sea floor 4.
  • valve 23 a may be closed, the deployment apparatus may be decoupled from vessel 10, a gas supply may be coupled to conduit 25, and valve 25a may be opened to allow for the flow of gas 5 into gas storage bag 50.
  • ballast 41 is fixed ballast that provides a sufficient load to anchor vessel 10 to the sea floor 4.
  • alternative means of anchoring may be used to secure the subsea gas storage vessel (e.g., vessel 10) to the sea floor.
  • piles may be used to anchor the vessel to the sea floor. The piles may be driven, suction, jetted, or combinations thereof.
  • gravity anchoring is generally more suited to relocation operations in which vessel 10 is lifted from location on the sea floor 4 and move to a different location on the sea floor 4. In such cases, the use of gravity anchoring eliminates the need to deploy additional piles subsea and drive the new piles into he sea floor 4 to anchor vessel 10 at its new location.
  • valve 25a is opened and valves 23a, 24a are closed.
  • the buoyancy forces resulting therefore also increase.
  • the amount and weight of ballast 41 is set such that the total weight of vessel 10 is greater than the maximum possible buoyancy forces resulting from stored gas 5. Consequently, vessel 10 remains anchored to the sea floor 4 as the volume of gas 5 in tank 20 increases during storage operations.
  • vessel 10 is first be disengaged from the sea floor 4 ( Figure 5), and then lifted and moved to the desired location ( Figure 6).
  • Figure 5 in this embodiment, to initiate disengagement of vessel 10 from the sea floor 4, stored gas 5 is emptied from bag 50, valve 25a is closed, and valve 23a is closed (if not already closed).
  • the deployment apparatus is coupled to upper end 10a of vessel 10 and applies an upward lifting force to vessel 10, valve 24a is opened, and air 6 is pumped through valve 24a and inlet 24 into second region 21b of tank 20.
  • suction control apparatus 34 may be employed as previously described to decrease suction in recess 31 and aid in the initial lifting of vessel 10 from sea floor 4.
  • valves 23a and 25a are maintained in the closed positions, and valve 36 is closed.
  • the deployment apparatus continues to apply a vertical lifting force to vessel 10 and air 6 continues to be pumped through valve 24a and inlet 24 into second region 21b.
  • the hydrostatic pressure of sea water 3 decreases and the air 6 in second region 21b expands.
  • the expansion of air 6 in second region 21b and the continued pumping of air 6 into second region 21b continues to increase the buoyant forces acting on vessel 10.
  • the buoyant forces acting on vessel 10 cannot exceed a predetermined maximum buoyant force defined by the location of port 26.
  • the maximum buoyant force acting on vessel 10 due to air 6 in tank 20 occurs when second region 21b is completely filled with air 6 from upper end 10a to port 26. Any additional volume of air 6 will simply exit tank 20 and second region 21b through port 26.
  • the location of port 26 defines the maximum possible buoyant force acting on vessel 10 - the closer port 26 is to upper end 10a, the lower the maximum possible buoyant force due to air 6, and the closer the port 26 to lower end 10b, the greater the maximum possible buoyant force due to air 6.
  • the axial position of port 26 along tank 20 is preferably set such that the maximum possible buoyancy force from air 6 is less than or equal to the total weight of vessel 10, and such that the total weight of vessel 10 minus the maximum possible buoyancy force from air 6 is greater than zero and less than the maximum hook load capacity of the deployment apparatus.
  • vessel 10 may be controllably lifted by the deployment apparatus without exceeding the maximum hook load capacity, and without uncontrollably accelerating to the surface under a continuously increasing buoyancy force as the air continues to expand as depth decreases.
  • gas 5 may be supplied to or pulled from gas storage vessel 10.
  • gas conduit 25 of subsea gas storage vessel 10 is placed in fluid communication with a buoy 80 moored in place by mooring lines 81, 82 connected to anchors 83, 84 at sea floor 4.
  • Buoy 80 may be connected to a CNG tanker 90 and/or placed in fluid communication with a seafloor gas pipeline 91.
  • Gas 5 may be provided to vessel 10 from pipeline 91, buoy 80, and/or tanker 90, or offloaded from vessel 10 to pipeline 91, buoy 80, and/or tanker 92 as desired.
  • Figure 8 illustrates one exemplary subsea configuration, however, a variety of other subsea configurations employing embodiments of subsea gas storage vessel described herein are possible.
  • valve 25a is closed, and valve 23a is closed (if not already closed).
  • the deployment apparatus is coupled to upper end 10a of vessel 10 and applies an upward lifting force to vessel 10, valve 24a is opened, and air 6 is pumped through valve 24a and inlet 24 into second region 21b of tank 20.
  • the deployment apparatus continues to apply a vertical lifting force to vessel 10 and air 6 continues to be pumped through valve 24a and inlet 24 into second region 21b.
  • buoyancy provided by the stored gas 5 stored in the gas storage tank 20 may be leveraged during disengagement, removal, relocation, or combinations thereof. For example, to initiate disengagement of the gas storage vessel 10 from the sea floor 4, all of the stored gas 5 in tank 20 may not be unloaded from the tank 20, but rather, some stored gas 5 may be left within tank 20 or additional stored gas 5 may be added to tank 20. Once the desired amount of stored gas 5 is in tank 20, valve 25a is closed, and valve 23a is closed (if not already closed).
  • the deployment apparatus is coupled to upper end 10a of vessel 10 and applies an upward lifting force to vessel 10.
  • valve 24a is opened and air 6 is pumped through valve 24a and inlet 24 into second region 21b of tank 20.
  • air 6 is pumped into tank 20
  • it naturally rises to the top of second region 21b and displaces water 3 within second region 21b.
  • Water 3 within tank 20 is free to flow through port 26 to outer region 22 as the volume of air 6 within tank 20 increases.
  • the removal and relocation process is similar to that previously described with reference to Figures 5 and 6. Namely, to continue lifting vessel 10, the deployment apparatus continues to apply a vertical lifting force to vessel 10 and air 6 continues to be pumped through valve 24a and inlet 24 into second region 21b. Thus, in this embodiment, the buoyancy of air 6 and stored gas 5 within tank 20 are leveraged during the disengagement and removal processes.
  • a flexible gas storage bag 50 is employed to store gas 5 and to maintain physical separation of stored gas 5 and sea water 3 within tank 20 to prevent hydrate formation.
  • alternative means may be employed to separate gas 5 and sea water 3 within the tank (e.g., tank 20).
  • FIG 9 an embodiment of a subsea gas storage vessel 100 is schematically shown disposed at sea floor 4 for subsea gas storage operations.
  • Vessel 100 is substantially the same as vessel 10 previously described, except that vessel 100 employs a floating diaphragm system 110 to physically separate stored gas 5 from sea water 3 within tank 20 as opposed to a flexible gas storage bag (e.g., bag 50).
  • floating diaphragm system 110 comprises a rigid plate or diaphragm 111 that is supported by air bubble 112, which may be added during the deployment process and prior to storage of gas 5 in tank 20.
  • the air bubble 112 allows diaphragm 111 to float on top of sea water 3 within tank 20 although diaphragm 111 may have a density greater than sea water 3.
  • the density of diaphragm 111 is greater than the density of gas 5 within tank 20, and thus, diaphragm 111 remains positioned below gas 5.
  • a dynamic sliding seal 113 is formed between diaphragm 111 and tank 20.
  • Seal 113 extends annularly around the entire circumference of diaphragm 111 and restricts and/or prevents the axial flow of sea water 3 and gas 5 across diaphragm 111, and thus, restricts and/or prevents gas 5 from contacting sea water 3.
  • Seal 113 may be formed by any suitable means including, without limitation, a lubricated bag assembly that extends radially from diaphragm 111 to tank 20.
  • a liquid hydrate inhibitor 115 that inhibits the formation of hydrates is disposed in tank 20 between gas 5 and diaphragm 111.
  • Hydrate inhibitor 115 may be injected into tank 20 through gas conduit 25 and valve 25a or other inlet positioned above diaphragm 111 (e.g., a dedicated chemical injection inlet). Hydrate inhibitor 115 has a density greater than gas 5, and thus, hydrate inhibitor 115 naturally flows downward in tank 20 until it is positioned atop diaphragm 111. In general, hydrate inhibitor 115 may be any suitable known hydrate inhibitor.
  • a barrier fluid may be employed to separate to separate gas 5 and sea water 3 within the tank (e.g., tank 20).
  • a subsea gas storage vessel 150 is schematically shown disposed at sea floor 4 for subsea gas storage operations.
  • Vessel 150 is substantially the same as vessel 10 previously described, except that vessel 150 employs a barrier fluid system 160 to physically separate stored gas 5 from sea water 3 within tank 20 as opposed to a flexible gas storage bag (e.g., bag 50).
  • barrier fluid system 160 comprises a barrier fluid 161 axially disposed between gas 5 and sea water 3.
  • Barrier fluid 161 has a density less than sea water 3 and greater than gas 5.
  • Barrier fluid 161 is preferably immiscible to both sea water 3 and gas 5.
  • An example of a barrier fluid is described in U.S. Patent Application Publication Nos. 2008/0041291 and 2009/0010717, each of which is hereby incorporated herein by reference in its entirety for all purposes. Those systems describe a perfectly immiscible fluid to both water and gas. In practice, fluids of this type are difficult to find. The method that is disclosed here offers the potential to utilize a much broader range of available and environmentally acceptable fluids.
  • a liquid hydrate inhibitor 162 that inhibits the formation of hydrates is disposed in tank 20 between gas 5 and barrier fluid 161.
  • Hydrate inhibitor 162 and/or barrier fluid 161 may be injected into tank 20 through gas conduit 25 and valve 25a or other inlet. Hydrate inhibitor 162 has a density greater than gas 5 and less than barrier fluid 161. In general, hydrate inhibitor 115 may be any suitable known hydrate inhibitor. Various sensors may be employed in vessel 150 to provide warn of potential overtopping, release of gas, release of barrier fluid 161, or combinations thereof to the surrounding environment.
  • a dead oil fluid which is somewhat miscible to both sea water 3 and gas 5 may be used as the barrier fluid (e.g., barrier fluid 161). Hydrates may form as gas 5 or sea water 3 moves through the dead oil barrier and contacts the other. Consequently, the hydrate formation is relatively slow. Further, by injecting sufficient hydrate inhibitors (e.g., methanol) prior to unloading or discharging gas 5, the hydrate effects can be minimized while still allowing standard, environmentally friendly materials to be used.
  • sufficient hydrate inhibitors e.g., methanol
  • System 180 comprises a fluid conduit 181 extending to valve 24a and inlet 24, an air inlet line 182 coupled to conduit 181, a water inlet line 183 coupled to conduit 181 above air inlet line 181. Water 3 is pumped through water inlet line 183 and into conduit 181, and air 6 is pumped through air inlet line 182 into conduit 181.
  • the water 3 is preferably pumped at a sufficient volumetric flow rate to push and convey air 6 down conduit 181 to inlet 24 and tank 20. Accordingly, the drag load imposed on air 6 within conduit 181 by water 3 in conduit 181 must always be greater than the buoyancy of the bubbles of air 6 in conduit 181. As the bubbles of air 6 move down, they decrease in size according to the ideal gas law. Thus, system 180 must be designed such that the flow rate of water 3 down conduit 181 is sufficiently high to achieve conveyance of air 6 to the installation depth. [0068] Combined air- water pumping system 180 offers the potential to eliminate high compression requirements at the surface as the hydrostatic water head accomplishes that function. Consequently, standard equipment may be used to perform the pumping operations, which are inherently safe because high pressures are achieved at depth without necessitating high pressure components at the surface near the workers.
  • Embodiments of subsea gas storage vessels 10, 100, 150 described above included a single tank (e.g., tank 20) and a single chamber or volume for gas storage (e.g., first region 21a, inner region 21) for gas storage.
  • the subsea gas storage vessel or system may include multiple gas storage tanks.
  • Such embodiments may be referred as compartmentalized subsea gas storage vessels or systems since the total gas stored is divided among multiple subsea gas storage tanks.
  • Compartmentalized subsea gas storage vessels offer the potential to reduce quantities of gas leaks subsea by spreading the volume of stored gas across multiple tanks. Further, compartmentalization offers the potential to reduce manufacturing costs as smaller flexible bags are typically easier to design and build.
  • Vessel 200 has a central axis 250 and extends between an upper end 200a and a lower end 200b.
  • vessel 200 includes a plurality of rigid, thin- walled storage tanks 220 and a base 260 positioned below tanks 220.
  • Vessel 200 is designed to be deployed and positioned subsea with tanks 220 in a vertical orientation with upper end 200a positioned above lower end 200b.
  • each tank 220 is substantially the same as tank 20 previously described. Namely, each tank 220 comprises rigid walls preferably made of steel or composite material. In addition, each storage tank 220 defines an inner region or chamber 221 and an exterior region 222. A flexible gas storage bag 250 as previously described is disposed within inner chamber 221 of each tank 220, thereby dividing chamber 221 into a first region 221a inside chamber 221 and bag 250, and a second region 221b inside chamber 221 but outside bag 250. Each gas storage bag 250 includes a stored gas port 251. As best shown in Figure 12, the walls of each tank 220 include external reinforcing ribs to assist in strengthening the walls.
  • each buoyancy control gas outlet 223 and a buoyancy control gas inlet 224 is provided on each storage tank 220.
  • each buoyancy control gas outlet 223 is in fluid communication with a header pipe or conduit 223b
  • each buoyancy control gas inlet 224 is in fluid communication with a header pipe or conduit 224b.
  • Outlet valve 223a controls the flow of buoyancy control gas or air 6 through outlets 223 and header pipe 223b
  • inlet valve 224a controls the flow of buoyancy control gas or air 6 through header pipe 224b and gas inlets 224.
  • one outlet valve 223a controls the exhaust of air 6 from every tank 220
  • one inlet valve 224a controls the flow of air 6 into every tank 220.
  • each tank e.g., each tank 220
  • each tank 220 may have its own independently controlled buoyancy control gas inlet valve and/or buoyancy control gas outlet valve.
  • the flow of buoyancy control gas into and out of each tank may be independently controlled to vary the buoyancy forces acting on different tanks.
  • each storage tank 220 also includes a stored gas conduit 225 in fluid communication with gas port 251 of its associated gas storage bag 250.
  • each stored gas conduit 225 is in fluid communication with a gas header pipe or conduit 225b.
  • the flow of a stored gas 5 into and out of each gas storage bag 250 through header pipe 225b, each conduit 225, and each gas port 251 is controlled by a gas valve 225a.
  • one gas valve 225a controls the flow of stored gas 5 into and out of every bag 250.
  • each tank e.g., each tank 220
  • each tank 220 may have its own independently controlled gas valve such that the flow of gas into or out of each bag (e.g., each bag 250) can varied.
  • each storage tank 220 includes a through port 226 positioned proximal the lower end of its associated tank 220.
  • each tank 220 may have any suitable size and geometry.
  • each tank 220 has the same size and cylindrical geometry.
  • the size of each tank 220, and hence the overall size of vessel 200 will depend, at least in part, on the desired volume for subsea gas storage.
  • a given volume of gas may be stored in a single relatively large tank or stored in multiple smaller gas tanks of a compartmentalized subsea gas storage vessel.
  • smaller gas storage tanks are simpler and less expensive to construct as compared to large gas storage tanks. Consequently, a compartmentalized subsea gas storage vessel, such as vessel 200, may be more cost effective to manufacture than a subsea gas storage vessel that employs one relatively large tank to store the same total gas volume.
  • compartmentalized subsea gas storage vessels are better suited to deployment methods previously described that employ temporary buoyancy. For example, it may be desirable to use only some of the buoyancy when lowering the system and compartmentalization makes this process simpler and more robust.
  • base 260 of vessel 200 includes a ballast chamber 240 containing ballast 241 and a plurality of mud skirts 230 at lower end 200b.
  • Ballast chamber 240 is positioned axially between tanks 220 and skirts 230.
  • one mud skirt 230 is provided for each tank 220.
  • one or more mud skirts may be provided.
  • Mud skirts 230 functions to positively engage the sea floor 4 and restrict and/or prevent the lateral movement of vessel 200 once positioned at the sea floor 4 for gas storage operations.
  • Each skirt 230 is substantially the same as skirt 30 previously described.
  • vessel 200 is urged downward and each skirt 230 is pushed into sea floor 4.
  • a suction control apparatus similar to suction control apparatus 34 previously described maybe provided for one or more of skirts 230 to control suction forces within skirts 230 during anchoring and removal operations.
  • a suction control apparatus e.g., suction control apparatus 34
  • differential suctioning may be provided among skirts 230 to vary the suction forces acting on different portions of vessel 200.
  • ballast 241 is contained within ballast chamber 240.
  • a single ballast chamber 240 extends beneath each tank 220.
  • each tank e.g., each tank 220
  • ballast 241 counteracts the upward vertical buoyancy forces resulting from the stored gas 5 and/or air 6 in tanks 220.
  • the quantity and weight of ballast 241 is chosen to achieve the desired total dry weight of vessel 200.
  • the dry weight of vessel 200 is preferably greater than the total buoyant forces acting on vessel 200 during all operational phases of vessel 200 (e.g., deployment, anchoring, gas storage, disengaging, removal, and relocation of vessel 200).
  • the total weight of vessel 200 minus the buoyant forces acting on vessel 200 is preferably greater than zero (to prevent the uncontrolled ascent of vessel 200) and less than the maximum hook load capacity of the deployment apparatus (to ensure the maximum hook load capacity is not exceeded).
  • each tank 220 includes a gas storage bag 250 and is adapted to store gas 5 in order to maximize the gas storage volume or capacity of vessel 200.
  • one or more of the tanks of a compartmentalized subsea gas storage vessel may serve as a dedicated ballasting cell that may be used to provide buoyancy during installation and then flooded during anchoring.
  • Vessel 200 is operated in a similar fashion as vessel 10 previously described. Specifically, during deployment subsea, vessel 200 is connected by a releasable coupling 270 at upper end 200a to a deployment apparatus at the surface (e.g., a crane on a surface vessel).
  • the dry weight of vessel 200 is preferably greater than the maximum buoyancy forces acting on vessel 200 during deployment, and thus, vessel 200 naturally wants to sink.
  • the maximum possible buoyant forces resulting from air 6 in tanks 220 during deployment occurs when second region 221b of each tank 220 is completely filled with air 6 from upper end 200a to its respective port 226. No greater buoyant force can be achieved while vessel 200 is subsea since any additional air volume in any tank 220 will simply exit through port 226. Accordingly, the maximum possible buoyant force of each tank 220 can be adjusted by varying the axial position or height of port 226.
  • the deployment apparatus connected to coupling 270 applies an upward, vertical lifting force to vessel 200 to manage and control the rate at which vessel 200 submerges subsea.
  • sea water 3 in outer region 222 flows through ports 226 of tanks 220.
  • valve 223a closed, sea water 3 continues to flow into second region 221b, the air 6 in second region 221b is compressed, and the buoyancy provided by tanks 220 decreases.
  • valve 224a is opened and air 6 is pumped through valve 224a, header pipe 224b, and inlets 224 into second region 221b of each tank 220 to maintain a sufficient buoyant force.
  • the total weight of vessel 10 minus the buoyant force is preferably greater than zero (to prevent an uncontrolled ascent of vessel 10) and less than the maximum hook load capacity of the deployment apparatus (to ensure the maximum hook load capacity is not exceeded).
  • skirts 230 begin to engage and penetrate the sea floor 4.
  • valve 224a is closed and pumping of air 6 through header pipe 224b and inlets 224 is ceased, and valve 223a is opened to allow any air 6 in second region 221b of each tank 220 to exit.
  • sea water 3 flows through ports 226 and fills the remainder of second region 221b of each tank 220, thereby reducing and/or eliminating the buoyancy of tanks 220.
  • skirts 230 penetrate further into sea floor 4 under the weight of vessel 200.
  • a suction control apparatus may be employed as previously described.
  • valve 223a may be closed, coupling 270 may be released to disconnect the deployment apparatus from vessel 200, a gas supply may be coupled to header pipe 225b, and valve 225a may be opened to allow for the flow of gas 5 through header pipe 225b and valve 225a into gas storage bags 250.
  • valve 225a is opened and valves 223a, 224a are closed.
  • the buoyancy of each tank 220 increases.
  • the amount and weight of ballast 241 is set such that the total weight of vessel 200 is greater than the maximum possible buoyancy forces resulting from stored gas 5. Consequently, vessel 200 remains anchored to the sea floor 4 as the volume of gas 5 in each tank 220 increases.
  • vessel 200 To remove and/or relocate vessel 200, vessel 200 must first be disengaged from the sea floor 4, and then lifted and moved to the desired location. To initiate disengagement of vessel 200 from the sea floor 4, stored gas 5 is emptied from each bag 250, valve 225a is closed, and valve 223a is closed (if not already closed).
  • the surface deployment apparatus is coupled to vessel 200 via coupling 270, an upward lifting force is applied to vessel 200 by the deployment apparatus, valve 224a is opened, and air 6 is pumped through valve 224a, header pipe 224b, and inlets 224 into second region 21b of each tank 220.
  • a suction control apparatus may be employed as previously described to decrease suction forces between vessel 200 and the sea floor.
  • vessel 200 Once vessel 200 is disengaged from sea floor 4, it may be lifted to the surface or lifted and relocated to a different subsea location. To continue lifting vessel 200, valves 223a and 225a are maintained in the closed positions. Further, the deployment apparatus continues to apply a vertical lifting force to vessel 200 and air 6 continues to be pumped through valve 224a, header pipe 224b, and inlets 24 into each tank 220. As the depth of tank 20 decreases, the hydrostatic pressure of sea water 3 decreases and the air 6 in each tank 220 expands. The expansion of air 6 in each tank 220 and the continued pumping of air 6 into each tank 220 continues to increase the buoyancy of each tank 220 and vessel 200.
  • vessel 200 is deployed subsea as a single structure or unit. However, in some applications, it may be desirable to deploy vessel 200 in separate parts, and then assembly vessel 200 subsea.
  • base 260 may be deployed and anchored to the sea floor, and then tanks 220 may be deployed and coupled to the top of the previously anchored base 260. Upon removal and relocation, the base 260 may be left in place or removed along with tanks 220. In this way, the overall weight and complexity of the lift may be minimized, although there may be some additional complication involved in coupling the tanks 220 and base 260 at depth.
  • the total weight of the gas storage vessel minus the buoyancy of the vessel is preferably greater than zero and less than the maximum hook load capacity of the deployment apparatus at the surface.
  • the static load of the gas storage vessel is sufficiently small to enable controlled deployment with conventional surface deployment equipment such as cranes mounted to surface vessels.
  • dynamic loads must also be taken into account because the total entrapped mass and added mass above and below the vessel are substantial. The total system mass combined with the fact that the floating deployment apparatus may be moving dynamically with wave excitations can create significant dynamic loads.
  • System 300 includes a floating surface vessel 310 and a pipestring 320.
  • Surface vessel 310 includes a derrick 311 that supports pipestring 320 and vessel 200 coupled to the lower end of pipestring 320 with releasable coupling 270.
  • pipestring 310 extends from floating surface vessel 310 to gas storage vessel 200.
  • surface vessel 310 also includes a crane 312.
  • a buoyancy control gas supply line 330 also extends from floating surface vessel 310 to gas storage vessel 200.
  • Supply line 330 is in fluid communication with valve 224a and header pipe 224b, and supplies buoyancy control gas or air 6 during deployment, removal and relocation of vessel 200.
  • the combined air/water solution may be delivered to the subsea tanks with supply line 330.
  • pipestring 320 includes an in-line damping device 325 that absorbs and dissipates dynamic loads.
  • Embodiments of system 300 provide several potential advantages over conventional winch wire deployment systems. As compared to winch wires, drilling pipes and pipestrings offer the potential for improved load capacities. In addition, since the pipestring (e.g., pipestring 320) is rigid, its rotation can be controlled at the surface with conventional equipment associated with the derrick (e.g., derrick 311) such as a top drive or rotary table. As a result, twisting of any supply lines (e.g., supply line 330) around the pipestring can be reduced and/or completely eliminated.
  • conventional equipment associated with the derrick e.g., derrick 3111
  • the load capacities of most drilling derricks (e.g., derrick 311) is substantially greater than the load capacities of most cranes, and thus, deployment with a pipestring and drilling derrick offers the potential to improve safety and enhance control over the subsea gas storage vessel.
  • most conventional drilling derricks offer the potential for improved heave compensation.
  • the traveling block provides some heave compensation when it supports the pipestring (e.g., pipestring 320). When the pipestring is set down off the traveling block in slips, heave compensation may be provided by the damping device (e.g., damping device 325) in-line with the pipestring.
  • embodiments described herein include a single gas storage tank (e.g., vessel 10) or multiple gas storage tanks that are coupled together to form a single structure (e.g., vessel 200), it should be appreciated that a plurality of separate gas storage vessels can be grouped together subsea to form a larger subsea gas storage assembly or farm. In joining the storage vessels together, standard subsea architectures can be used.
  • Embodiments disclosed herein may serve in a variety of applications.
  • embodiments described herein may be used to store natural gas produced during a offshore well testing operation where the operator does not want to commit to building a pipeline for gas export before the reservoir has been producing for long enough to evaluate its characteristics and condition.
  • embodiments described herein may be used to store natural gas at locations close to a pipeline network independent of the prior existence of naturally occurring caverns. Accordingly, embodiments described herein offer the potential to reduce dependency on the availability of natural caverns for gas storage.
  • embodiments described herein may be used to store gas in locations remote from human life and property, thereby offering the potential to reduce risks associated with gas storage.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

L'invention concerne un procédé de déploiement d'un récipient de stockage de gaz sous la surface de l'eau, lequel consiste à coupler l'extrémité supérieure du récipient de stockage de gaz à un appareil de déploiement placé à la surface de l'eau. Le récipient de stockage de gaz possède un poids sec total et comprend une extrémité inférieure opposée à l'extrémité supérieure. Le récipient de stockage de gaz comprend également un réservoir de stockage définissant une région interne dans le réservoir et une région externe à l'extérieur du réservoir. Le procédé consiste en outre à abaisser le récipient de stockage de gaz en dessous de la surface de l'eau à l'aide de l'appareil de déploiement. Le procédé consiste en outre à pomper un gaz de contrôle de flottabilité dans la région interne du réservoir. Le gaz de contrôle de flottabilité dans la région interne du réservoir génère une force de flottabilité agissant sur le récipient de stockage de gaz.
PCT/US2010/021445 2010-01-05 2010-01-20 Systèmes et procédés pour installation et retrait de stockage de gaz sous-marin WO2011084164A1 (fr)

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BRPI1008151-8A BRPI1008151B1 (pt) 2010-01-05 2010-01-20 método para implementar um recipiente de armazenamento de gás abaixo da superfície da água e sistema para armazenar um gás submarino
US13/144,461 US20120260839A1 (en) 2010-01-05 2010-01-20 Systems and methods for subsea gas storage installation and removal

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US29227410P 2010-01-05 2010-01-05
US61/292,274 2010-01-05

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WO2014061837A1 (fr) 2012-10-18 2014-04-24 Korea Advanced Institute Of Science And Technology Réservoir de stockage sous-marin à grande échelle et procédé de construction et d'installation de celui-ci
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IT201800020059A1 (it) * 2018-12-18 2020-06-18 Saipem Spa Sistema di stoccaggio subacqueo
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KR101199348B1 (ko) 2011-04-25 2012-11-09 한국해양연구원 관입용 선단 슈가 설치된 석션파일
WO2013068577A1 (fr) * 2011-11-11 2013-05-16 Roentdek-Handels Gmbh Installation de stockage d'énergie par pompage
US9797366B2 (en) 2011-11-11 2017-10-24 Roentdek-Handels Pumped-storage power plant
WO2014061837A1 (fr) 2012-10-18 2014-04-24 Korea Advanced Institute Of Science And Technology Réservoir de stockage sous-marin à grande échelle et procédé de construction et d'installation de celui-ci
EP2909111A4 (fr) * 2012-10-18 2016-06-15 Korea Advanced Inst Sci & Tech Réservoir de stockage sous-marin à grande échelle et procédé de construction et d'installation de celui-ci
WO2014077820A1 (fr) * 2012-11-15 2014-05-22 Fluor Technologies Corporation Système de stockage de fluide sous-marin et procédés s'y rapportant
US8905677B2 (en) 2012-11-15 2014-12-09 Fluor Technologies Corporation Subsea fluid storage system and methods therefor
WO2014158202A1 (fr) * 2013-03-14 2014-10-02 Sanko Tekstil Isletmeleri Sanayi Ve Ticaret A.S. Procédés de stockage de fluides énergétiques sous-marins à grande échelle à niveau d'énergie de volume actif et appareil pour la production d'énergie et l'intégration de sources d'énergies renouvelables
US9045209B2 (en) 2013-03-14 2015-06-02 Sanko Tekstil Isletmeleri Sanayi Ve Ticaret A.S. Active volume energy level large scale sub-sea energy fluids storage methods and apparatus for power generation and integration of renewable energy sources
US20150375829A1 (en) * 2013-04-06 2015-12-31 Safe Marine Transfer, LLC Large subsea package deployment methods and devices
US9878761B2 (en) * 2013-04-06 2018-01-30 Safe Marine Transfer, LLC Large subsea package deployment methods and devices
CN103216724A (zh) * 2013-05-03 2013-07-24 邓允河 一种海底储存高压气体的系统及方法
EP3094575A4 (fr) * 2014-01-15 2017-11-29 Bright Energy Storage Technologies, LLP Système de stockage d'énergie submergé utilisant un fluide comprimé
CN105899442A (zh) * 2014-01-15 2016-08-24 布莱特能源存储科技有限责任公司 使用压缩流体的水下能量储存
EP3172151A4 (fr) * 2014-07-24 2018-09-05 Oceaneering International Inc. Système de stockage de fluide sous-marin
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
WO2016179371A1 (fr) * 2015-05-05 2016-11-10 Safe Marine Transfer, LLC Réservoir de stockage sous-marin, procédé d'installation et de récupération d'un tel réservoir, système, procédé de rattrapage d'un réservoir de stockage et procédé de remplissage d'un réservoir de stockage sous-marin
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
CN105523305A (zh) * 2016-01-28 2016-04-27 山东南海气囊工程有限公司 柔性水下储罐
IT201800020059A1 (it) * 2018-12-18 2020-06-18 Saipem Spa Sistema di stoccaggio subacqueo
WO2020128890A1 (fr) * 2018-12-18 2020-06-25 Saipem S.P.A. Système de stockage sous-marin
WO2020226507A1 (fr) * 2019-05-07 2020-11-12 Equinor Energy As Stockage immergé de fluides hydrocarbures
NO20201074A1 (no) * 2019-11-11 2021-05-12 Ole Arthur Vaage Anordning ved flytende lagertank
NO346196B1 (no) * 2019-11-11 2022-04-19 Ole Arthur Vaage Anordning ved flytende lagertank
NO346807B1 (no) * 2019-11-11 2023-01-16 Ole Arthur Vaage En flytende lagertank og fremgangsmåte for drift av denne
GB2607617A (en) * 2021-06-09 2022-12-14 Equinor Energy As Subsea chemical storage system and method
GB2607617B (en) * 2021-06-09 2023-10-11 Equinor Energy As Subsea chemical storage system and method

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