WO2010116489A1 - Method for transporting liquefied natural gas produced in sea area - Google Patents

Method for transporting liquefied natural gas produced in sea area Download PDF

Info

Publication number
WO2010116489A1
WO2010116489A1 PCT/JP2009/057104 JP2009057104W WO2010116489A1 WO 2010116489 A1 WO2010116489 A1 WO 2010116489A1 JP 2009057104 W JP2009057104 W JP 2009057104W WO 2010116489 A1 WO2010116489 A1 WO 2010116489A1
Authority
WO
WIPO (PCT)
Prior art keywords
ship
natural gas
storage
transport
modified
Prior art date
Application number
PCT/JP2009/057104
Other languages
French (fr)
Japanese (ja)
Inventor
雅樹 川瀬
Original Assignee
三井海洋開発株式会社
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 三井海洋開発株式会社 filed Critical 三井海洋開発株式会社
Priority to PCT/JP2009/057104 priority Critical patent/WO2010116489A1/en
Publication of WO2010116489A1 publication Critical patent/WO2010116489A1/en

Links

Images

Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B27/00—Arrangement of ship-based loading or unloading equipment for cargo or passengers
    • B63B27/24—Arrangement of ship-based loading or unloading equipment for cargo or passengers of pipe-lines

Definitions

  • the present invention relates to a method for transporting liquefied natural gas produced in the sea area, and more particularly, to a method for transporting liquefied natural gas using a large floating production storage shipping system.
  • a technology using a pipeline has been mainly used as a technology for transporting from a gas field to a demand point.
  • the transportation technology using such a pipeline can be applied only to a geographically limited region such as a region relatively close to the gas field.
  • a technology has been proposed in which a facility for cooling and liquefying natural gas, which is a gas, is constructed near the gas field, and liquefied natural gas (hereinafter referred to as “LNG”) is produced and transported by an LNG tanker. ing.
  • LNG liquefied natural gas
  • the LNG production facility (hereinafter referred to as “plant”) is constructed on land close to the gas field.
  • Gas fields often exist in the ocean, and the gas from the gas field is transported to the plant by a submarine pipeline, but if the gas field is far from the land, the plant may be constructed in the sea area near the gas field. desirable.
  • the cost of constructing fixed facilities in the sea area is very high, and the construction of the plant is difficult at a water depth of 300 m or more.
  • Large floating production storage and shipping systems (Floating Production, Storage and Offloading System. Hereinafter referred to as “FPSO”) have been proposed (see, for example, Patent Documents 1 and 2 and Non-Patent Document 1). ).
  • FPSO for LNG needs to be equipped with a liquefaction plant for liquefying the obtained gas components and a dedicated special tank for storing LNG.
  • LNG is a fluid having a cryogenic temperature of ⁇ 162 ° C.
  • facilities for handling the fluid need to be kept at a cryogenic temperature, the facilities need to be heat-insulated. Therefore, a FPSO for LNG requires a floating facility that is very large, complex, and has sufficient strength. Therefore, the construction of a new floating facility that satisfies these conditions has a problem that it takes enormous cost, material, and construction time as compared with the case of building a floating facility for petroleum FPSO. Also, shipyards that can be built are limited.
  • the purpose is to provide an efficient method with a certain degree of security.
  • the above-mentioned problem is a method for producing liquefied natural gas in the sea area and transporting the liquefied natural gas.
  • the process of remodeling into a production ship, the process of mooring the modified large floating production ship near the gas field, and collecting, separating, refining, and liquefying natural gas from the seabed in the modified large floating production ship A step of remodeling an existing ship into a storage ship equipped with a storage facility for liquefied natural gas, and arranging the remodeled storage ship in the vicinity of the remodeled large floating production ship.
  • the existing ship is modified to a large floating production ship. Separate production equipment and transportation equipment.
  • FPSO in the method of transporting LNG produced in the sea area
  • constructing a new large-scale floating production facility with a built-in LNG storage tank is a huge cost, material and construction It takes time. Therefore, separating the functions of production and storage, remodeling a large ship that does not have an existing LNG tank, using the remodeled ship as a large floating production facility that does not have an LNG tank in the LNG FPSO, By remodeling the existing LNG carrier with a storage vessel, significant cost and material savings can be achieved.
  • the technology for remodeling existing ships can greatly reduce the design time and construction time of large floating production facilities and storage vessels, so it is possible to start operations earlier than when newly building ships.
  • the existing ship since the existing ship is used, the time required for the operator to acquire the driving technique can be shortened compared to the case where the new ship is used, and as a result, LNG can be transported efficiently.
  • the modified large floating production ship in the modified large floating production ship, it is obtained by a step of recovering a fluid containing natural gas from the seabed, a step of separating and purifying the fluid, and a step of separating.
  • the liquefied natural gas is liquefied to be liquefied and cooled to obtain liquefied natural gas; the liquefied natural gas is transported to a buffer storage facility; and the buffer storage facility is connected to the modified storage ship. And a step of transporting liquefied natural gas to the first transport facility.
  • the liquefaction process of natural gas can be performed and LNG can be stored in the buffer storage facility.
  • LNG can be stored in the buffer storage facility.
  • the storage ship cannot be moored near the large floating production ship due to bad weather Even so, it is possible to produce LNG continuously, and to produce and transport LNG efficiently.
  • the collected natural gas can be transported without waste by performing the LNG storage step, the vaporized gas reliquefaction step, and the reliquefied LNG recycle step in the storage vessel.
  • the production process of LNG is handled by a large floating production ship and the storage process is handled by a storage ship, each process can be carried out at different facilities, so if an accident occurs, damage should be minimized. LNG transport with high safety is possible.
  • a relatively inexpensive alternative ship can be used as an alternative storage ship, it is not necessary to stop the entire system, and efficient production and transportation of LNG becomes possible.
  • the above-described problem is a method for producing liquefied natural gas in the sea area and transporting the liquefied natural gas.
  • a modified storage ship takes charge of the process of liquefying natural gas.
  • the size of an existing ship suitable for remodeling is not enough and a large floating production ship cannot be installed up to the liquefaction facility, by installing the liquefaction facility on the storage ship, A degree of freedom can be secured.
  • building a large floating production ship, which is the core requires enormous costs, materials, and construction time. Therefore, by reducing the equipment, it is possible to reduce the cost required for the construction of a large floating production ship.
  • the method includes a storing step and a step of transporting the liquefied natural gas to the second transport facility connected to the transport ship.
  • the natural gas can be transported from the large floating production ship to the storage ship in a gaseous state. Accordingly, the range for handling LNG may be only storage vessels and transport vessels, and the cost for construction and maintenance of low-temperature facilities can be minimized.
  • the method for transporting LNG produced in the sea area of claim 1 of the present invention it is possible to construct a large floating production ship and a storage ship by modifying an existing ship. Time can be reduced, and further, the time required for operation and the like can be shortened, and LNG can be transported efficiently.
  • LNG can be continuously produced, and efficient production and transportation of LNG becomes possible. Further, since the number of modified parts of the storage ship can be minimized, the cost and the time required for construction can be reduced.
  • the recovered natural gas can be transported without waste by providing a process for recycling the vaporized natural gas. Since the production process and the storage process are performed in different facilities, highly safe production of LNG is possible.
  • the range for handling LNG may be only a storage ship and a transport ship, and the cost for constructing and maintaining a low-temperature facility can be reduced. Can do.
  • the LNG transportation can be performed while the transport ship is continuously operated and the LNG is produced, the LNG transportation is efficiently performed without wasting time. be able to.
  • FIG. (A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 1.
  • FIG. (B) It is a top view of the large floating production ship and storage ship which concern on Embodiment 1.
  • FIG. (A) It is a side view of the large floating production ship, storage ship, and transport ship which concern on Embodiment 1-1.
  • (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 1-1.
  • A) It is a side view of the large floating production ship, storage ship, and transport ship which concern on Embodiment 1-2.
  • (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 1-2.
  • FIG. (A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 2.
  • FIG. (B) It is a top view of the large-sized floating production ship and storage ship which concern on Embodiment 2.
  • FIG. (A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-1.
  • (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-1.
  • A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-2.
  • Embodiment 2-2 It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-2.
  • FIG. (A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 3.
  • FIG. (B) It is a top view of the large-sized floating production ship and storage ship which concern on Embodiment 3.
  • FIG. (A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 3-1.
  • (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 3-1.
  • A) It is a side view of the large floating production ship, storage ship, and transport ship which concern on Embodiment 3-2.
  • (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 3-2.
  • FIG. (A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 4.
  • FIG. (B) It is a top view of the large-sized floating production ship and storage ship which concern on Embodiment 4.
  • FIG. (A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-1.
  • (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-1.
  • A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-2.
  • Embodiment 4-2 It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-2.
  • FIG. 1 It is a flowchart figure which shows the transportation method of LNG which concerns on embodiment of this invention. It is a flowchart figure which shows the LNG production process which concerns on Embodiment 1. FIG. It is a flowchart figure which shows the LNG production process which concerns on Embodiment 2. FIG.
  • FIGS. 1 to 3 show a connection form of a large floating production ship, a storage ship and a transport ship according to Embodiment 1
  • FIGS. 1 (a) and 1 (b) are side views of the large floating production ship and the storage ship, respectively.
  • FIGS. 2 (a) and 2 (b) are side views and FIG. 3 (a) and FIG. 3 (b) are side views and FIG.
  • FIGS. 4 to 6 show the connection form of the large floating production ship, storage ship and transport ship according to the second embodiment, and FIGS.
  • FIGS. 5A and 5B are a side view and a plan view of a storage ship
  • FIGS. 5A and 5B are connections including the transport ship of Embodiment 2-1
  • FIGS. FIGS. 7 to 9 show a connection form of a large floating production ship, a storage ship and a transport ship according to the third embodiment
  • FIG. b) is a side view and a plan view of a large floating production ship and a storage ship, respectively.
  • FIGS. 8 (a) and 8 (b) are Embodiment 3-1
  • FIGS. 9 (a) and 9 (b) are Embodiment 3.
  • FIGS. 10 is a side view and a plan view of a connected state including a transport ship of FIG. 2, and FIGS. 10 to 12 show a connection form of a large floating production ship, a storage ship and a transport ship according to the fourth embodiment.
  • FIGS. 11A and 11B are a side view and a plan view of a large floating production ship and a storage ship, respectively, and FIGS. 11A and 11B are Embodiments 4-1, FIGS. ) Is a side view and a plan view of the connected state including the transport ship of Embodiment 4-2,
  • FIG. 13 is a flowchart showing the LNG transport method according to the embodiment of the present invention, and FIG. FIG. 15 is a flowchart showing the LNG production process according to the second embodiment. It is an over door view.
  • the existing ship for modification to be used for the large floating production ship 1 can be an LNG tanker, an oil tanker, an oil FPSO ship, or the like. Among them, it is preferable to use a ship having a hull size of 200,000 to 350,000 tons.
  • the modified hull includes a mooring line 12 (FIGS. 1 to 3 and FIGS. 7 to 9) grounded to the seabed 5 or a mooring line 12 and an external turret 17 (FIGS. 4 to 6 and FIGS. 10 to 12).
  • Storage equipment for storing fluids for storing fluids, production equipment such as oil treatment equipment, gas treatment equipment, water treatment equipment, power generation equipment, control systems, boilers, utility equipment such as various pumps, and fire extinguishing equipment And a lifeboat, a helicopter deck, a deck crane, a ballast tank, and at least one residence facility for workers.
  • the large floating production ship 1 may be provided with an LNG buffer storage facility.
  • the LNG buffer storage facility is installed to buffer and store LNG when the LNG transport to the storage ship 2 is interrupted in the short term or in the long term.
  • the volume of the buffer storage facility is preferably 5,000 m 3 to 10,000 m 3 .
  • the large floating production ship 1 and a natural gas liquefaction facility may be provided.
  • this liquefaction facility a cascade process, a mixed refrigerant process, an expander process, or the like can be used.
  • An LNG tanker can be used for the existing ship for modification to be used for the storage ship 2.
  • the modified hull includes an LNG storage facility 22 and a second transport facility LNG transport facility (natural gas transport facility) 23 (FIGS. 2, 5, 8 and 11) or LNG transport facility (natural gas transport facility) 27. (Figs. 3, 6, 9, and 12), at least one LNG transport pump, power generation equipment, fire extinguishing device, lifeboat, deck crane, ballast tank, and housing facilities for workers. It shall be provided.
  • a natural gas liquefaction facility or a vaporized gas reliquefaction facility may be provided, and the liquefaction process may be a cascade process, a mixed refrigerant process, an expander process, or the like as described above.
  • the transport ship 3 can use a general LNG tanker and is provided with an LNG storage facility 31.
  • a moss type, an independent square shape, an independent cylindrical shape, a membrane type, or the like can be used.
  • the hull structure of large floating production ship 1, storage ship 2 and transport ship 3 is in accordance with the requirements of the classification society.
  • a multipoint mooring type (FIGS. 1 to 3 and FIGS. 7 to 9) and a single point mooring type (FIGS. 4 to 6 and FIGS. 10 to 12) can be used.
  • the multi-point mooring method requires less cost and the one-point mooring method has the advantage that it can be used in a wide range.
  • the storage ship 2 is provided with a mooring line 21.
  • an internal turret with the turret located inside the hull, a disconnectable disconnectable turret, an external turret with the turret outside the bow, and a tower yoke can be used.
  • An optimal system can be selected.
  • the external turrets 17 of FIGS. 4 to 6 and FIGS. 10 to 12 are used in areas where the sea conditions are relatively strict and the water depth is deep.
  • each ship can be a tandem type in which the large floating production ship 1 and the storage ship 2 are connected in series, or a horizontal type in which they are connected in parallel.
  • the tandem type has advantages such that the side of the hull is less damaged at the time of connection and can be used in a wider sea area, and the horizontal type has a short LNG transport route and can easily move personnel.
  • a tandem type or a horizontal type can be used. These arrangements are selected according to sea conditions using FPSO.
  • connection equipment of each ship when the arrangement of each ship is a horizontal type, the jointed fender support frames 14 (FIGS. 1 to 6) and 25 (FIGS. 2, 5, 8 and 11) having a joint structure are used.
  • Rigid connection means, or elastic connection means such as mooring lines 13 (FIGS. 1-6) and 24 (FIGS. 2, 5, 8 and 11) can be selected as appropriate, and both means can be used simultaneously. Can be used.
  • joints are provided in the connection means so as to allow relative movement of each ship, and buoyancy bodies 15 (FIGS. 1 to 6) and 26 (FIGS. 2, 5, 8 and 11) are provided. There is a need.
  • elastic connection means such as mooring lines 7 (FIGS. 7 to 12) and 28 (FIGS. 3, 6, 9, and 12) are preferable.
  • the LNG transport facility (natural gas transport facility) 6, 16, 23 and 27 between the ships can use a loading arm and a loading hose.
  • the return gas loading arm that returns the natural gas vaporized in the storage ship 2 to the large floating production ship 1 for re-liquefaction. It is necessary to have a gas loading hose.
  • the LNG is transported (shipping), if the relative displacement (swing) of the ship is large, it is preferable to use a flexible loading hose and a return gas loading hose.
  • the loading hose and the return gas loading hose are arranged so as to maintain a sufficient height from the sea surface 4 and are in a position not affected by the wave at the interface.
  • FIG. 13 is a flowchart showing a method for transporting LNG according to an embodiment of the present invention, and the following embodiment will more specifically describe this flowchart.
  • the LNG production process S1 shows a process of liquefying natural gas in the large floating production ship 1, and can optionally include a process of reliquefying the natural gas vaporized in the storage ship 2. .
  • the LNG production process S1 will be described in detail with reference to the first embodiment and FIG.
  • the LNG production process S2 shows a process of liquefying natural gas in the storage ship 2.
  • the LNG production process S2 will be described in detail with reference to the second embodiment and FIG.
  • Embodiment 1 shows an example of a form suitable for an area where the sea conditions are mild.
  • 1 to 3 are a plan view and a side view showing the configuration of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the first embodiment.
  • the large floating production ship 1 and the storage ship 2 are connected in parallel.
  • mold used is shown.
  • FIG. 1 shows only a large floating production ship 1 and a storage ship 2
  • FIG. 2 illustrates an embodiment 1-1 in which a transport ship 3 is connected in parallel to the storage ship 2 and is a horizontal type.
  • FIG. 3 illustrates an embodiment 1-2 in which the transport ship 3 is connected in series to the storage ship 2 to be a tandem type.
  • a reliquefaction device is mounted on an LNG tanker having an LNG tank with a capacity of 125,000 m 3 , and modified to be reused as a storage facility to form a storage ship 2 (FIG. 13, step 201)
  • the connecting means uses the mooring cable 13 and the articulated fender support frame 14, and the buoyancy body 15 is further provided.
  • the mooring method is a multi-point mooring method, and a method of mooring the large floating production ship 1 and the storage ship 2 is adopted.
  • the LNG transport facility 16 as the first transport facility is connected between the large floating production ship 1 and the storage ship 2 (FIG. 13, step 105).
  • the large floating production ship 1 is equipped with an LNG transportation facility 16, that is, a loading arm for LNG transportation, and a return gas loading arm for returning the natural gas vaporized in the storage ship 2 to the large floating production ship 1.
  • the transport ship 3 is arranged in the vicinity of the storage ship 2 in the arrangement of Embodiment 1-1 (FIG. 2) or 1-2 (FIG. 3), and then connected to the storage ship 2 (FIG. 13, step 301). .
  • the connecting means at this time the mooring cable 24 and the articulated fender support frame 25 are used in the embodiment 1-1 (FIG.
  • Embodiment 1-1 (FIG. 2), and a buoyancy body 26 is further provided.
  • the mooring line 28 is used.
  • the LNG transportation facility 23 in the embodiment 1-1 (FIG. 2) and the LNG transportation facility 27 in the embodiment 1-2 (FIG. 3) are connected between the storage ship 2 and the transportation ship 3 (FIG. 13, process). 302).
  • the storage ship 2 is equipped with an LNG transport facility 23, that is, a loading arm for LNG transport, and a return gas loading arm for returning the natural gas vaporized by the transport ship 3 to the storage ship 2.
  • a loading hose and a return gas loading hose are mounted as the LNG transport facility 27.
  • the LNG stored in the storage ship 2 is transported by the LNG transport pump through the LNG production step S1 (FIG. 13, step 303).
  • the transport ship 3 is detached from the storage ship 2 (FIG. 13, step 304), and the LNG is transported by operating the transport ship 3 (FIG. 13, step 305).
  • LNG production process S1 is comprised by the following processes.
  • the riser 11 is installed in the gas field (step S101), and fluid in which oil, gas, and water are mixed is recovered from the gas field (step S102).
  • the recovered fluid is roughly separated into oil, gas, and water by a three-phase separator (step S103).
  • the separated oil further removes moisture (step S104) and is stored in the oil storage tank of the large floating production ship 1 (step S105).
  • moisture, sulfur content, carbon dioxide gas, etc. are removed from the separated natural gas (step S106), and then compressed and cooled to obtain LNG (step S108).
  • a device for separating propane, butane and the like before cooling is mounted on the large floating production ship 1 and a separation step is performed (step S107).
  • the LNG produced by the large floating production ship 1 is transported to the storage ship 2 by the LNG transport pump and stored (step S109). Further, the natural gas generated from the tank of the storage ship 2 is converted into LNG by the reliquefaction device mounted on the storage ship 2 (step S110), and sent to the tank of the storage ship 2, thereby preventing the loss of natural gas. .
  • the LNG is transported from the storage ship 2 to the transport ship 3 through the LNG production process S1 (step 303).
  • positions the transport ship 3 in the vicinity of the storage ship 2, and connects with the storage ship 2 is carried out. Can be done continuously.
  • Embodiment 2 shows an example of a form suitable for an area where sea conditions are relatively severe and the water depth is deep.
  • 4 to 6 are a plan view and a side view showing configurations of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the second embodiment.
  • the large floating production ship 1 and the storage ship 2 are connected in parallel.
  • mold used is shown.
  • FIG. 4 illustrates only the large floating production ship 1 and the storage ship 2
  • FIG. 5 illustrates an embodiment 2-1 in which the transport ship 3 is connected to the storage ship 2 in parallel to form a horizontal type.
  • FIG. 6 shows an embodiment 2-2 in which the transport ship 3 is connected in series to the storage ship 2 to be a tandem type.
  • an oil tanker with a size of 250,000 tons, a three-phase separator, a gas refining device, a gas compression device, an oil / water treatment device, a control system, an LNG transport pump, a power generation device, a boiler, a mooring device, safety equipment, etc.
  • a large floating production ship 1 (FIG. 13, step 101).
  • the large floating production ship 1 is moored near the gas field in the sea area (FIG. 13, step 102).
  • the mooring method employs a method of mooring using the external turret 17 among the one-point mooring methods.
  • an LNG carrier with an existing storage facility with a capacity of 150,000 m 3 was remodeled to be equipped with a natural gas liquefaction facility to form storage vessel 2 (FIG. 13, step 201), and then in the vicinity of the gas field.
  • the connecting means uses the mooring cable 13 and the articulated fender support frame 14, and the buoyancy body 15 is further provided.
  • the natural gas transportation facility 16 as the first transportation facility is connected between the large floating production ship 1 and the storage ship 2 (FIG. 13, step 105). At this time, the natural gas transport facility 16 is a loading arm.
  • the transport ship 3 is arranged in the vicinity of the storage ship 2 in the arrangement of Embodiment 2-1 (FIG. 5) or 2-2 (FIG. 6), and then connected to the storage ship 2 (FIG. 13, step 301). .
  • the connection means at this time the mooring cable 24 and the articulated fender support frame 25 are used in the embodiment 2-1 (FIG. 5), and a buoyancy body 26 is further provided.
  • the mooring line 28 is used.
  • an LNG transport facility 23 is connected in the embodiment 2-1 (FIG. 5) and an LNG transport facility 27 is connected in the embodiment 2-2 (FIG. 6) (FIG. 13, process). 302).
  • the storage ship 2 is equipped with the LNG transportation facility 23, that is, the loading arm for LNG transportation, and the return gas loading arm for returning the natural gas vaporized by the transportation ship 3 to the storage ship 2.
  • the LNG transportation facility 23 that is, the loading arm for LNG transportation
  • the return gas loading arm for returning the natural gas vaporized by the transportation ship 3 to the storage ship 2.
  • a loading hose and a return gas loading hose are mounted as the LNG transport facility 27.
  • the LNG produced by the storage ship 2 is transported by the LNG transport pump through the LNG production step S2 (FIG. 13, step 303).
  • the transport ship 3 is detached from the storage ship 2 (FIG. 13, step 304), and the LNG is transported by operating the transport ship 3 (FIG. 13, step 305).
  • LNG production process S2 is comprised by the following processes.
  • the riser 11 is installed in the gas field (step S201), and the fluid in which oil, gas, and water are mixed is recovered from the gas field (step S202).
  • the recovered fluid is roughly separated into oil, gas, and water by a three-phase separator (step S203).
  • the separated oil further removes moisture (step S204) and is stored in the oil storage tank of the large floating production ship 1 (step S205).
  • moisture, sulfur content, carbon dioxide gas, etc. are removed from the separated natural gas (step S206) to obtain a natural gas containing no impurities.
  • a device for separating propane, butane and the like before cooling is mounted on the large floating production ship 1 and a separation step is performed (step S207).
  • natural gas purified by the large floating production ship 1 is transported to the storage ship 2 by a gas compressor (step S208). Then, natural gas is cooled and liquefied with a refrigerant such as nitrogen cooled by a turbo expander using natural gas as a nitrogen refrigerant in the storage ship 2 to obtain LNG (step S209).
  • the LNG is transported from the storage ship 2 to the transport ship 3 through the LNG production process S2 (process 303).
  • positions the transport ship 3 in the vicinity of the storage ship 2, and connects with the storage ship 2 is carried out. Can be done continuously.
  • Embodiment 3 shows an example of the form suitable for the Southeast Asian sea area especially in the area where sea conditions are comparatively severe.
  • 7 to 9 are a plan view and a side view showing the configuration of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the third embodiment.
  • the large floating production ship 1 and the storage ship 2 are connected in series.
  • mold connected is shown.
  • FIG. 7 shows only the large floating production ship 1 and the storage ship 2
  • FIG. 8 illustrates an embodiment 3-1 in which the transport ship 3 is connected to the storage ship 2 in parallel and is a horizontal type.
  • FIG. 9 illustrates an embodiment 3-2 in which the transport ship 3 is connected to the storage ship 2 in series to form a tandem type.
  • the connecting means of the large floating production ship 1 and the storage ship 2 uses a mooring line 7, and a loading hose and a return gas loading hose are mounted as an LNG transport facility (natural gas transport facility) 6.
  • a mooring line 24 and an articulated fender support frame 25 are used as a connecting means for the storage ship 2 and the transport ship 3, and a buoyancy body 26 is further provided.
  • the mooring line 28 is used.
  • Embodiment 4 shows an example of a form suitable for an area where sea conditions are relatively severe and the water depth is deep.
  • 10 to 12 are a plan view and a side view showing the configuration of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the fourth embodiment.
  • the large floating production ship 1 and the storage ship 2 are arranged in parallel.
  • adopted the horizontal type connected is shown.
  • FIG. 10 illustrates only the large floating production ship 1 and the storage ship 2
  • FIG. 11 illustrates the embodiment 4-1 in which the transport ship 3 is connected to the storage ship 2 in parallel to be installed horizontally.
  • FIG. 12 illustrates an embodiment 4-2 in which the transport ship 3 is connected to the storage ship 2 in series to be a tandem type.
  • the connecting means of the large floating production ship 1 and the storage ship 2 uses a mooring line 7, and a loading hose and a return gas loading hose are mounted as an LNG transport facility (natural gas transport facility) 6.
  • the mooring line 24 and the articulated fender support frame 25 are used as a connecting means for the storage ship 2 and the transport ship 3, and a buoyancy body 26 is further provided.
  • the mooring line 28 is used.

Abstract

Disclosed is a method for transporting liquefied natural gas produced in a sea area wherein costs and materials required when a large floating production/storage/shipment system is used are reduced to thereby provide an efficient method. A method for producing liquefied natural gas in a sea area and transporting the liquefied natural gas, characterized by comprising a step for remodeling an existing ship into a large floating production ship (1), a step for remodeling an existing ship into a storage ship (2) equipped with a facility for storing liquefied natural gas, a step for producing liquefied natural gas in a sea area by coupling the large floating production ship (1) with the storage ship (2), and a step for transporting liquefied natural gas by using a transportation ship (3).

Description

海域で生産された液化天然ガスを輸送する方法Method for transporting liquefied natural gas produced in the sea
　本発明は、海域で生産された液化天然ガスを輸送する方法に係り、特に、大型浮遊式生産貯蔵出荷システムを用いた液化天然ガスの輸送方法に関する。 The present invention relates to a method for transporting liquefied natural gas produced in the sea area, and more particularly, to a method for transporting liquefied natural gas using a large floating production storage shipping system.
　近年、石油価格の高騰や、将来予想される石油の枯渇への対処として、石油代替エネルギーの開発や導入が盛んに行われるようになってきている。数ある代替エネルギーの中でも、天然ガスは燃焼時に発生する窒素酸化物（ＮＯｘ）及び二酸化炭素（ＣＯ２）の排出量が石炭に比べて少なく、且つ硫黄酸化物（ＳＯｘ）も発生しないため、環境負荷の小さいエネルギー源である。また、その供給源となるガス田はストランデッド・ガス田（既発見未開発のガス田で、開発計画が立っていないもの）を含み多数存在し、その埋蔵量は現在の予測を大幅に上回ると予想される。こうした背景の下、天然ガスの利用・ガス田の開発が積極的に行われるようになってきている。 In recent years, the development and introduction of petroleum alternative energy has been actively performed as a countermeasure to rising oil prices and the anticipated depletion of oil. Because among other alternative energy, nitrogen oxides natural gas generated during the combustion (NOx) and emissions of carbon dioxide (CO 2) is less than that of the coal, and sulfur oxides (SOx) does not occur, environmental An energy source with a low load. In addition, there are many gas fields that are the source of supply, including the Stranded gas field (an undiscovered and undeveloped gas field that has not been developed yet), and its reserves will greatly exceed current forecasts. is expected. Against this backdrop, the use of natural gas and the development of gas fields have been actively carried out.
　従来、天然ガスはガス田から需要地まで輸送する技術としてパイプラインを用いる技術が主流とされていた。しかし、こうしたパイプラインを用いた輸送技術は、ガス田から比較的近い地域などの、地理的に限られた地域にしか適用できないという問題があった。これに対し、気体である天然ガスを冷却して液化する設備をガス田近傍に建設し、液化天然ガス（以下、「ＬＮＧ」と称する。）を生産してＬＮＧタンカーで輸送する技術が提案されている。これにより、ガス田からパイプラインを敷設することが難しい遠隔地へもＬＮＧタンカーにより大量の天然ガスを輸送することができる。 Conventionally, for natural gas, a technology using a pipeline has been mainly used as a technology for transporting from a gas field to a demand point. However, there is a problem that the transportation technology using such a pipeline can be applied only to a geographically limited region such as a region relatively close to the gas field. On the other hand, a technology has been proposed in which a facility for cooling and liquefying natural gas, which is a gas, is constructed near the gas field, and liquefied natural gas (hereinafter referred to as “LNG”) is produced and transported by an LNG tanker. ing. Thereby, a large amount of natural gas can be transported by a LNG tanker to a remote place where it is difficult to lay a pipeline from the gas field.
　一般に、ＬＮＧ生産設備は（以下、「プラント」と称する。）ガス田に近い陸上に建設される。ガス田は海洋に存在することが多く、ガス田からのガスはプラントへ海底パイプラインで輸送されるが、ガス田が陸地から離れている場合はプラントをガス田近傍の海域に建設することが望ましい。しかしながら、固定式設備を海域に建設する費用は非常に高額になる上、水深３００ｍ以上ではプラントの建築が困難であるという問題点が挙げられることから、各種プラントを浮体に搭載し、海洋ガス田近傍に設置するという大型浮遊式生産貯蔵出荷システム（Ｆｌｏａｔｉｎｇ　Ｐｒｏｄｕｃｔｉｏｎ，Ｓｔｏｒａｇｅ　ａｎｄ　Ｏｆｆｌｏａｄｉｎｇ　Ｓｙｓｔｅｍ．以下、「ＦＰＳＯ」と称する。）が提案されている（例えば、特許文献１、２、非特許文献１を参照）。すなわち、ガス田から流体を採掘し、ガス前処理設備、液化プラント（ＬＮＧの生産）、ＬＮＧ貯蔵設備を順に経た後、直接ＬＮＧタンカーに出荷するという技術である。これにより、採掘していたガス田が枯渇してもＦＰＳＯを別のガス田に移動でき、新たにプラントを建設する費用がかからなくてすむため、コスト削減につながる。また、あらゆる水深に適用可能となり、開発地域の拡大を図ることができる。さらに、ガス田の近傍にプラントを浮遊して設置するため、パイプラインを用いる技術と比較し、珊瑚礁や海岸線の環境に悪影響を及ぼすことが少ない。 Generally, the LNG production facility (hereinafter referred to as “plant”) is constructed on land close to the gas field. Gas fields often exist in the ocean, and the gas from the gas field is transported to the plant by a submarine pipeline, but if the gas field is far from the land, the plant may be constructed in the sea area near the gas field. desirable. However, the cost of constructing fixed facilities in the sea area is very high, and the construction of the plant is difficult at a water depth of 300 m or more. Large floating production storage and shipping systems (Floating Production, Storage and Offloading System. Hereinafter referred to as “FPSO”) have been proposed (see, for example, Patent Documents 1 and 2 and Non-Patent Document 1). ). That is, it is a technique in which a fluid is extracted from a gas field, and after passing through a gas pretreatment facility, a liquefaction plant (LNG production), and an LNG storage facility in this order, it is shipped directly to an LNG tanker. As a result, even if the gas field that has been mined is depleted, the FPSO can be moved to another gas field, and the cost for constructing a new plant is not required, leading to cost reduction. In addition, it can be applied to all depths, and the development area can be expanded. Furthermore, because the plant is installed in the vicinity of the gas field, it has less adverse effects on the coral reef and coastline environment compared to technologies using pipelines.
特開昭４７－８９２２号公報JP 47-8922 A 特表２００２－５０１８６１号公報JP-T-2002-501861
　一般に、石油用ＦＰＳＯにおいては、油・ガス・水等の混合物を海底から採掘するための設備、さらに油・ガス・水等の成分をそれぞれ分離する処理設備、石油を貯蔵するためのタンク及び石油の輸送設備を備えている必要がある。そしてこれら設備は、海上の厳しい海象条件に耐えうる十分な強度が必要とされる。 Generally, in FPSO for petroleum, equipment for mining a mixture of oil, gas, water, etc. from the seabed, further processing equipment for separating components such as oil, gas, water, etc., tanks for storing oil, and petroleum It is necessary to have transportation equipment. These facilities are required to have sufficient strength to withstand severe sea conditions at sea.
　一方、ＬＮＧ用ＦＰＳＯにおいては上記設備に加え、得られたガス成分を液化するための液化プラント、ＬＮＧを貯蔵するための専用特殊タンクを備えることも必要である。また、ＬＮＧは－１６２℃という極低温の流体であり、それを取り扱う設備も極低温に保つ必要があるため、その設備は防熱とする必要がある。したがって、ＬＮＧ用ＦＰＳＯにおいては非常に大型、複雑、かつ十分な強度を備えている浮体施設が必要となる。そのため、これらの条件を満たした新しい浮体施設の建造には、石油用ＦＰＳＯの浮体施設を建造する場合と比較して莫大なコスト、材料及び建造時間がかかるという問題点が挙げられる。また建造できる造船所も限られてしまう。 On the other hand, in addition to the above equipment, FPSO for LNG needs to be equipped with a liquefaction plant for liquefying the obtained gas components and a dedicated special tank for storing LNG. Moreover, since LNG is a fluid having a cryogenic temperature of −162 ° C., and facilities for handling the fluid need to be kept at a cryogenic temperature, the facilities need to be heat-insulated. Therefore, a FPSO for LNG requires a floating facility that is very large, complex, and has sufficient strength. Therefore, the construction of a new floating facility that satisfies these conditions has a problem that it takes enormous cost, material, and construction time as compared with the case of building a floating facility for petroleum FPSO. Also, shipyards that can be built are limited.
　また、ＬＮＧ用ＦＰＳＯの使用においては、その安全性や関連周辺技術を含め、全体システムの運転に関する検討が不可欠である。実際に現場でＦＰＳＯの運転を行う作業員にとって、新しいシステムの導入においては、予測できない危険性を伴うことがあり、作業上の安全性が問題になる場合もある。そのため、ＬＮＧ用ＦＰＳＯの運転前には十分な安全性評価が必要であり、その評価には長期間を要する。したがって、上記のように新たに浮体施設を建造して安全性の評価を行う場合には、その結果が得られるまでに、さらに多くの時間が必要となる。 Also, when using FPSO for LNG, it is essential to study the operation of the entire system, including its safety and related peripheral technologies. For workers who actually operate the FPSO on site, the introduction of a new system may involve an unpredictable danger, and work safety may be a problem. Therefore, a sufficient safety evaluation is required before the operation of the LNG FPSO, and the evaluation takes a long time. Therefore, when a floating facility is newly constructed and safety is evaluated as described above, more time is required until the result is obtained.
　本発明の目的は、海域で生産されたＬＮＧを輸送する方法において、ＦＰＳＯを使用する際に必要となるコスト、材料及び建造時間を削減する方法を提供し、併せて安全で、運用上の自由度を確保し効率の良い方法を提供することにある。 It is an object of the present invention to provide a method for reducing the cost, material and construction time required when using FPSO in a method for transporting LNG produced in the sea area. The purpose is to provide an efficient method with a certain degree of security.
　前記課題は、本発明に係る海域で生産されたＬＮＧを輸送する方法によれば、海域で液化天然ガスを生産し、該液化天然ガスを輸送する方法であって、既存の船舶を大型浮遊式生産船に改造する工程と、前記改造された大型浮遊式生産船をガス田近傍に係留する工程と、前記改造された大型浮遊式生産船において海底から天然ガスを回収、分離、精製、液化する工程と、既存の船舶を液化天然ガスの貯蔵設備を備えた貯蔵船に改造する工程と、前記改造された大型浮遊式生産船の近傍に、前記改造された貯蔵船を配設し、前記改造された大型浮遊式生産船に前記改造された貯蔵船を連結する工程と、前記改造された大型浮遊式生産船と前記改造された貯蔵船との間に、液化天然ガスの第１の輸送設備を接続する工程と、前記第１の輸送設備により、前記改造された大型浮遊式生産船において生産された液化天然ガスを前記改造された貯蔵船に輸送する工程と、前記改造された貯蔵船の近傍に、液化天然ガスの貯蔵設備を備えた輸送船を配設し、前記改造された貯蔵船に前記輸送船を連結する工程と、前記改造された貯蔵船と前記輸送船との間に、液化天然ガスの第２の輸送設備を接続する工程と、前記第２の輸送設備により、前記改造された貯蔵船に貯蔵された液化天然ガスを前記輸送船に輸送する工程と、前記輸送船を前記改造された貯蔵船より離脱させ、前記輸送船を運行して天然ガスを輸送する工程と、を備えることにより解決される。 According to the method for transporting LNG produced in the sea area according to the present invention, the above-mentioned problem is a method for producing liquefied natural gas in the sea area and transporting the liquefied natural gas. The process of remodeling into a production ship, the process of mooring the modified large floating production ship near the gas field, and collecting, separating, refining, and liquefying natural gas from the seabed in the modified large floating production ship A step of remodeling an existing ship into a storage ship equipped with a storage facility for liquefied natural gas, and arranging the remodeled storage ship in the vicinity of the remodeled large floating production ship. A first transportation facility for liquefied natural gas between the step of connecting the modified storage ship to the modified large floating production ship and the modified large floating production ship and the modified storage ship And connecting the first transportation facility And a step of transporting the liquefied natural gas produced in the modified large floating production ship to the modified storage ship, and a liquefied natural gas storage facility in the vicinity of the modified storage ship. Arranging a transport ship, connecting the transport ship to the modified storage ship, and connecting a second transportation facility for liquefied natural gas between the modified storage ship and the transport ship; A step of transporting liquefied natural gas stored in the modified storage ship to the transport ship by the second transport facility; and detaching the transport ship from the modified storage ship; And a process of transporting natural gas by operating a ship.
　上述のように、ＬＮＧタンクと生産設備と輸送設備が一体となった従来型の大型浮遊式生産船を使ったＬＮＧ輸送方法にかわり、既存船舶を改造して大型浮遊式生産船とし、ＬＮＧタンクと生産設備及び輸送設備を分離する。海域で生産されたＬＮＧを輸送する方法において、ＦＰＳＯを採用する際、その中核となるＬＮＧ貯蔵タンクを内蔵した一体型の大型浮遊式生産施設を新規に建造することは莫大なコスト、材料及び建造時間を要する。したがって、生産と貯蔵という機能を分離して、既存のＬＮＧタンクを持たない大型船舶を改造し、その改造船をＬＮＧ用ＦＰＳＯにおいてＬＮＧタンクを持たない大型浮遊式生産施設として使用し、ＬＮＧタンクを持った既存のＬＮＧ運搬船を貯蔵船に改造することにより、大幅なコスト、材料の削減を図ることができる。また、既存船舶を改造する技術により、大型浮遊式生産施設及び貯蔵船の設計時間、建造時間を大幅に短縮できることから、新規に造船する場合と比して早期の操業開始が可能となる。
　また、既存の船舶を用いるため、作業員が運転技術の習得に要する時間が新規船を用いた場合と比して短くて済み、その結果、効率良くＬＮＧを輸送することができる。 As described above, instead of the LNG transportation method using the conventional large floating production ship, where the LNG tank, production equipment, and transportation equipment are integrated, the existing ship is modified to a large floating production ship. Separate production equipment and transportation equipment. When adopting FPSO in the method of transporting LNG produced in the sea area, constructing a new large-scale floating production facility with a built-in LNG storage tank is a huge cost, material and construction It takes time. Therefore, separating the functions of production and storage, remodeling a large ship that does not have an existing LNG tank, using the remodeled ship as a large floating production facility that does not have an LNG tank in the LNG FPSO, By remodeling the existing LNG carrier with a storage vessel, significant cost and material savings can be achieved. In addition, the technology for remodeling existing ships can greatly reduce the design time and construction time of large floating production facilities and storage vessels, so it is possible to start operations earlier than when newly building ships.
In addition, since the existing ship is used, the time required for the operator to acquire the driving technique can be shortened compared to the case where the new ship is used, and as a result, LNG can be transported efficiently.
　このとき、請求項２のように、前記改造された大型浮遊式生産船において、海底より天然ガスを含む流体を回収する工程と、前記流体を分離、精製する工程と、前記分離工程で得られた気体を液化するために加圧、冷却して液化天然ガスを得る工程と、前記液化天然ガスを緩衝貯蔵設備に輸送する工程と、前記緩衝貯蔵設備から前記改造された貯蔵船と連結された第１の輸送設備に液化天然ガスを輸送する工程と、を備えていると好適である。 At this time, as in claim 2, in the modified large floating production ship, it is obtained by a step of recovering a fluid containing natural gas from the seabed, a step of separating and purifying the fluid, and a step of separating. The liquefied natural gas is liquefied to be liquefied and cooled to obtain liquefied natural gas; the liquefied natural gas is transported to a buffer storage facility; and the buffer storage facility is connected to the modified storage ship. And a step of transporting liquefied natural gas to the first transport facility.
　このように大型浮遊式生産船において、天然ガスの液化工程を行い、緩衝貯蔵設備にＬＮＧを貯蔵することができるため、例えば貯蔵船が天候の悪化により大型浮遊式生産船の近傍に係留できない場合であっても、連続的にＬＮＧを生産することができ、効率の良いＬＮＧの生産及び輸送が可能となる。 In this way, in the large floating production ship, the liquefaction process of natural gas can be performed and LNG can be stored in the buffer storage facility. For example, when the storage ship cannot be moored near the large floating production ship due to bad weather Even so, it is possible to produce LNG continuously, and to produce and transport LNG efficiently.
　また、請求項３のように、前記改造された貯蔵船において、前記改造された大型浮遊式生産船から輸送された液化天然ガスを貯蔵設備に輸送する工程と、気化したガスを再液化する工程と、前記再液化して得られた液化天然ガスを前記改造された貯蔵船の貯蔵設備に輸送する工程と、前記輸送船と連結された第２の輸送設備に液化天然ガスを輸送する工程と、を備えていると好ましい。 Further, as in claim 3, in the modified storage ship, a step of transporting liquefied natural gas transported from the modified large floating production ship to a storage facility, and a step of reliquefying the vaporized gas And transporting the liquefied natural gas obtained by reliquefaction to the storage facility of the modified storage ship, transporting the liquefied natural gas to a second transport facility connected to the transport ship, and Are preferably provided.
　このように貯蔵船において、ＬＮＧの貯蔵工程、気化したガスの再液化工程、再液化したＬＮＧのリサイクル工程を行うことにより、回収した天然ガスを無駄なく輸送することができる。また、ＬＮＧの生産工程は大型浮遊式生産船、貯蔵工程は貯蔵船が担うことにより、それぞれの工程を異なる施設で行うことができるため、事故が発生した場合には被害を最小限に抑えることができ、安全性の高いＬＮＧ輸送が可能となる。また、生産工程と貯蔵工程を行う施設を分離し、大型浮遊式生産船においてＬＮＧを貯蔵する必要がないため、海上での修理が非常に困難とされているＬＮＧの貯蔵タンクの修理が必要になった場合、代替貯蔵船として、比較的安価な代替船舶を使用できるので、全システムを停止する必要がなく、効率的なＬＮＧの生産、輸送が可能となる。 Thus, the collected natural gas can be transported without waste by performing the LNG storage step, the vaporized gas reliquefaction step, and the reliquefied LNG recycle step in the storage vessel. In addition, since the production process of LNG is handled by a large floating production ship and the storage process is handled by a storage ship, each process can be carried out at different facilities, so if an accident occurs, damage should be minimized. LNG transport with high safety is possible. Also, it is not necessary to store the LNG on the large floating production ship by separating the facilities that perform the production process and the storage process, so it is necessary to repair the LNG storage tank, which is considered extremely difficult to repair at sea. In this case, since a relatively inexpensive alternative ship can be used as an alternative storage ship, it is not necessary to stop the entire system, and efficient production and transportation of LNG becomes possible.
　また、前記課題は、本発明による海域で生産されたＬＮＧを輸送する方法によれば、海域で液化天然ガスを生産し、該液化天然ガスを輸送する方法であって、既存の船舶を大型浮遊式生産船に改造する工程と、前記改造された大型浮遊式生産船をガス田近傍に係留する工程と、前記改造された大型浮遊式生産船において海底から天然ガスを回収、分離、精製する工程と、既存の船舶を天然ガスの液化及び貯蔵設備と液化天然ガスの貯蔵設備を備えた貯蔵船に改造する工程と、前記改造された大型浮遊式生産船の近傍に、前記改造された貯蔵船を配設し、前記改造された大型浮遊式生産船に前記改造された貯蔵船を連結する工程と、前記改造された大型浮遊式生産船と前記改造された貯蔵船との間に、天然ガスの第１の輸送設備を接続する工程と、前記第１の輸送設備により、前記改造された大型浮遊式生産船において精製された天然ガスを前記改造された貯蔵船に輸送する工程と、前記改造された貯蔵船において天然ガスを液化する工程と、前記改造された貯蔵船の近傍に、液化天然ガスの貯蔵設備を備えた輸送船を配設し、前記改造された貯蔵船に前記輸送船を連結する工程と、前記改造された貯蔵船と前記輸送船との間に、液化天然ガスの第２の輸送設備を接続する工程と、前記第２の輸送設備により、前記改造された貯蔵船に貯蔵された液化天然ガスを前記輸送船に輸送する工程と、前記輸送船を前記改造された貯蔵船より離脱させ、前記輸送船を運行して液化天然ガスを輸送する工程と、を備えることにより解決される。 In addition, according to the method for transporting LNG produced in the sea area according to the present invention, the above-described problem is a method for producing liquefied natural gas in the sea area and transporting the liquefied natural gas. A process of remodeling into a production ship, a process of mooring the modified large floating production ship near the gas field, and a process of recovering, separating and refining natural gas from the sea floor in the modified large floating production ship And remodeling an existing ship into a storage ship equipped with a liquefaction and storage facility for natural gas and a storage facility for liquefied natural gas, and the modified storage ship in the vicinity of the modified large floating production ship. Between the modified large floating production ship and the modified large floating production ship, and the modified large floating production ship and the modified storage ship. To connect the first transport facility And a step of transporting the natural gas purified in the modified large floating production ship to the modified storage ship by the first transport facility, and liquefying the natural gas in the modified storage ship And a step of disposing a transport ship equipped with a storage facility for liquefied natural gas in the vicinity of the modified storage ship, and connecting the transport ship to the modified storage ship; and the modified storage A step of connecting a second liquefied natural gas transport facility between the ship and the transport ship; and the transport ship receives the liquefied natural gas stored in the modified storage ship by the second transport facility. And a step of detaching the transport ship from the modified storage ship and operating the transport ship to transport liquefied natural gas.
　上述のように、海域で生産されたＬＮＧを輸送する方法において、天然ガスを液化する工程を改造された貯蔵船が担うことも可能とある。改造に適した既存の船舶の大きさが十分でなく、液化設備までを大型浮遊式生産船が搭載できない場合、液化設備を貯蔵船に設置することにより、使用可能となる既存船舶の選択において、自由度を確保することができる。また、ＦＰＳＯを採用する際、その中核となる大型浮遊式生産船を建造することは莫大なコスト、材料、建造時間を要する。したがって、その設備を減縮することにより、大型浮遊式生産船の建造に必要な経費を削減することが可能となる。 As described above, in a method of transporting LNG produced in the sea area, it is possible that a modified storage ship takes charge of the process of liquefying natural gas. When the size of an existing ship suitable for remodeling is not enough and a large floating production ship cannot be installed up to the liquefaction facility, by installing the liquefaction facility on the storage ship, A degree of freedom can be secured. In addition, when employing FPSO, building a large floating production ship, which is the core, requires enormous costs, materials, and construction time. Therefore, by reducing the equipment, it is possible to reduce the cost required for the construction of a large floating production ship.
　このとき、請求項５のように、前記改造された貯蔵船において、前記改造された大型浮遊式生産船から輸送された天然ガスを冷却して液化天然ガスを得る工程と、前記液化天然ガスを貯蔵する工程と、前記輸送船と連結された第２の輸送設備に液化天然ガスを輸送する工程と、を備えていると好ましい。 At this time, as in claim 5, in the modified storage ship, a step of cooling the natural gas transported from the modified large floating production ship to obtain liquefied natural gas; and Preferably, the method includes a storing step and a step of transporting the liquefied natural gas to the second transport facility connected to the transport ship.
　このように貯蔵船において、天然ガスの液化工程を行うことにより、大型浮遊式生産船から貯蔵船への天然ガスの輸送は気体の状態で行うことができる。したがって、ＬＮＧを取り扱う範囲が貯蔵船及び輸送船のみでよく、低温設備の建造、維持にかかる費用を最小限に抑えることができる。 Thus, by performing the natural gas liquefaction process in the storage ship, the natural gas can be transported from the large floating production ship to the storage ship in a gaseous state. Accordingly, the range for handling LNG may be only storage vessels and transport vessels, and the cost for construction and maintenance of low-temperature facilities can be minimized.
　このとき、請求項６のように、前記改造された貯蔵船の近傍に、液化天然ガスの貯蔵設備を備えた輸送船を停泊させ、前記改造された貯蔵船に前記輸送船を連結する工程から、前記輸送船を前記改造された貯蔵船より離脱させ、前記輸送船を運行して天然ガスを輸送する工程までの各工程を連続して繰り返すと好適である。 At this time, as in claim 6, from the step of anchoring a transport ship equipped with a storage facility for liquefied natural gas in the vicinity of the modified storage ship, and connecting the transport ship to the modified storage ship It is preferable that the transport ship is detached from the modified storage ship, and the steps from the operation of the transport ship to the transportation of natural gas are repeated continuously.
　このように輸送船を連続的に稼働させることで、大型浮遊式生産船及び貯蔵船において海底から天然ガスを回収し、ＬＮＧを生産している間でも連続してＬＮＧ輸送を行うことができ、その結果、時間を浪費することなく、ＬＮＧ輸送を効率的に行うことができる。 By continuously operating the transport ship in this way, natural gas can be recovered from the sea floor in large floating production ships and storage ships, and LNG transport can be performed continuously even while producing LNG, As a result, LNG transportation can be performed efficiently without wasting time.
　本発明の請求項１の海域で生産されたＬＮＧを輸送する方法によれば、既存船を改造して大型浮遊式生産船及び貯蔵船を建造することができるため、必要なコスト、材料及び建造時間を削減することができ、さらに運転等にかかる時間を短縮することができ、効率の良いＬＮＧの輸送が可能となる。
　また請求項２の発明によれば、連続的にＬＮＧを生産することができ、効率の良いＬＮＧの生産及び輸送が可能となる。また、貯蔵船の改造部は最小限に抑えられるため、コスト及び建造に必要な時間を削減することができる。
　さらに請求項３の発明によれば、気化した天然ガスのリサイクル工程を設けることにより、回収した天然ガスを無駄なく輸送することができる。生産工程及び貯蔵工程を異なる施設で行うため、安全性の高いＬＮＧの生産が可能となる。また、生産工程及び貯蔵工程において、どちらか一方の工程を行う設備の修理が必要になった場合においても、全システムを停止する必要がなく、効率的なＬＮＧの生産が可能となる。
　さらにまた、請求項４の海域で生産されたＬＮＧを輸送する方法によれば、液化工程を貯蔵船が担うことにより、大型浮遊式生産船に液化設備を備える必要がなくなるため、大型浮遊式生産船を建造するために必要な既存船舶の大きさは比較的小さなものでも使用することができ、改造に必要なコスト、材料を削減することがきる。
　また、請求項５の発明によれば、天然ガスの液化工程を貯蔵船で行うため、ＬＮＧを取り扱う範囲が貯蔵船及び輸送船のみでよく、低温設備の建造、維持にかかる費用を削減することができる。
　さらに請求項６の発明によれば、輸送船を連続的に稼働させ、ＬＮＧを生産している間もＬＮＧ輸送を行うことができるため、時間を浪費することなく、ＬＮＧ輸送を効率的に行うことができる。 According to the method for transporting LNG produced in the sea area of claim 1 of the present invention, it is possible to construct a large floating production ship and a storage ship by modifying an existing ship. Time can be reduced, and further, the time required for operation and the like can be shortened, and LNG can be transported efficiently.
According to the invention of claim 2, LNG can be continuously produced, and efficient production and transportation of LNG becomes possible. Further, since the number of modified parts of the storage ship can be minimized, the cost and the time required for construction can be reduced.
Furthermore, according to the invention of claim 3, the recovered natural gas can be transported without waste by providing a process for recycling the vaporized natural gas. Since the production process and the storage process are performed in different facilities, highly safe production of LNG is possible. In addition, even in the case where it is necessary to repair the facility for performing either one of the production process and the storage process, it is not necessary to stop the entire system, and efficient LNG production is possible.
Furthermore, according to the method for transporting LNG produced in the sea area of claim 4, since the storage vessel takes charge of the liquefaction process, it is not necessary to provide a liquefaction facility in the large floating production vessel. The size of an existing ship necessary for building a ship can be used even if it is relatively small, and the cost and material required for remodeling can be reduced.
Further, according to the invention of claim 5, since the liquefaction process of natural gas is carried out by a storage ship, the range for handling LNG may be only a storage ship and a transport ship, and the cost for constructing and maintaining a low-temperature facility can be reduced. Can do.
Further, according to the invention of claim 6, since the LNG transportation can be performed while the transport ship is continuously operated and the LNG is produced, the LNG transportation is efficiently performed without wasting time. be able to.
（ａ）実施形態１に係る大型浮遊式生産船及び貯蔵船の側面図である。（ｂ）実施形態１に係る大型浮遊式生産船及び貯蔵船の平面図である。(A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 1. FIG. (B) It is a top view of the large floating production ship and storage ship which concern on Embodiment 1. FIG. （ａ）実施形態１－１に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態１－１に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship which concern on Embodiment 1-1. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 1-1. （ａ）実施形態１－２に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態１－２に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship which concern on Embodiment 1-2. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 1-2. （ａ）実施形態２に係る大型浮遊式生産船及び貯蔵船の側面図である。（ｂ）実施形態２に係る大型浮遊式生産船及び貯蔵船の平面図である。(A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 2. FIG. (B) It is a top view of the large-sized floating production ship and storage ship which concern on Embodiment 2. FIG. （ａ）実施形態２－１に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態２－１に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-1. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-1. （ａ）実施形態２－２に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態２－２に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-2. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 2-2. （ａ）実施形態３に係る大型浮遊式生産船及び貯蔵船の側面図である。（ｂ）実施形態３に係る大型浮遊式生産船及び貯蔵船の平面図である。(A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 3. FIG. (B) It is a top view of the large-sized floating production ship and storage ship which concern on Embodiment 3. FIG. （ａ）実施形態３－１に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態３－１に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 3-1. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 3-1. （ａ）実施形態３－２に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態３－２に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship which concern on Embodiment 3-2. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 3-2. （ａ）実施形態４に係る大型浮遊式生産船及び貯蔵船の側面図である。（ｂ）実施形態４に係る大型浮遊式生産船及び貯蔵船の平面図である。(A) It is a side view of the large floating production ship and storage ship which concern on Embodiment 4. FIG. (B) It is a top view of the large-sized floating production ship and storage ship which concern on Embodiment 4. FIG. （ａ）実施形態４－１に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態４－１に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-1. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-1. （ａ）実施形態４－２に係る大型浮遊式生産船、貯蔵船及び輸送船の側面図である。（ｂ）実施形態４－２に係る大型浮遊式生産船、貯蔵船及び輸送船の平面図である。(A) It is a side view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-2. (B) It is a top view of the large floating production ship, storage ship, and transport ship concerning Embodiment 4-2. 本発明の実施形態に係るＬＮＧの輸送方法を示すフローチャート図である。It is a flowchart figure which shows the transportation method of LNG which concerns on embodiment of this invention. 実施形態１に係るＬＮＧ生産工程を示すフローチャート図である。It is a flowchart figure which shows the LNG production process which concerns on Embodiment 1. FIG. 実施形態２に係るＬＮＧ生産工程を示すフローチャート図である。It is a flowchart figure which shows the LNG production process which concerns on Embodiment 2. FIG.
１　大型浮遊式生産船
２　貯蔵船
３　輸送船
４　海面
５　海底
６，１６，２３，２７　ＬＮＧ輸送設備（天然ガス輸送設備）
７　係留索
１１　ライザー
１２　係留索
１３　係留索
１４，２５　関節付きフェンダー支持フレーム
１５　浮力体
１７　エクスターナルタレット
２１　係留索
２２，３１　ＬＮＧ貯蔵設備
２４　係留索
２６　浮力体
２８　係留索
Ｓ１，Ｓ２　ＬＮＧ生産工程 1 Large floating production ship 2 Storage ship 3 Transport ship 4 Sea surface 5 Seabed 6, 16, 23, 27 LNG transport equipment (natural gas transport equipment)
7 Mooring Line 11 Riser 12 Mooring Line 13 Mooring Lines 14, 25 Fender Support Frame 15 with Articulation Floating Body 17 External Turret 21 Mooring Lines 22, 31 LNG Storage Facility 24 Mooring Line 26 Buoyant Body 28 Mooring Lines S1, S2 LNG Production Process
　本発明の実施形態に係るＬＮＧの輸送方法を図面に基づいて説明する。なお、以下に説明する設備、配置、構成等は、本発明を限定するものでなく、本発明の趣旨の範囲内で種々改変することができるものである。図１～３は実施形態１に係る大型浮遊式生産船、貯蔵船及び輸送船の連結形態を示しており、図１（ａ）、（ｂ）はそれぞれ大型浮遊式生産船及び貯蔵船の側面図及び平面図であり、図２（ａ）、（ｂ）は実施形態１－１、図３（ａ）、（ｂ）は実施形態１－２の輸送船を含めた連結状態の側面図及び平面図であり、図４～６は実施形態２に係る大型浮遊式生産船、貯蔵船及び輸送船の連結形態を示しており、図４（ａ）、（ｂ）はそれぞれ大型浮遊式生産船及び貯蔵船の側面図及び平面図であり、図５（ａ）、（ｂ）は実施形態２－１、図６（ａ）、（ｂ）は実施形態２－２の輸送船を含めた連結状態の側面図及び平面図であり、図７～９は実施形態３に係る大型浮遊式生産船及び貯蔵船及び輸送船の連結形態を示しており、図７（ａ）、（ｂ）はそれぞれ大型浮遊式生産船及び貯蔵船の側面図及び平面図であり、図８（ａ）、（ｂ）は実施形態３－１、図９（ａ）、（ｂ）は実施形態３－２の輸送船を含めた連結状態の側面図及び平面図であり、図１０～１２は実施形態４に係る大型浮遊式生産船、貯蔵船及び輸送船の連結形態を示しており、図１０（ａ）、（ｂ）はそれぞれ大型浮遊式生産船及び貯蔵船の側面図及び平面図であり、図１１（ａ）、（ｂ）は実施形態４－１、図１２（ａ）、（ｂ）は実施形態４－２の輸送船を含めた連結状態の側面図及び平面図であり、図１３は本発明の実施形態に係るＬＮＧの輸送方法を示すフローチャート図、図１４は実施形態１に係るＬＮＧ生産工程を示すフローチャート図、図１５は実施形態２に係るＬＮＧ生産工程を示すフローチャート図である。 LNG transport method according to an embodiment of the present invention will be described with reference to the drawings. The equipment, arrangement, configuration, and the like described below do not limit the present invention and can be variously modified within the scope of the present invention. FIGS. 1 to 3 show a connection form of a large floating production ship, a storage ship and a transport ship according to Embodiment 1, and FIGS. 1 (a) and 1 (b) are side views of the large floating production ship and the storage ship, respectively. FIGS. 2 (a) and 2 (b) are side views and FIG. 3 (a) and FIG. 3 (b) are side views and FIG. FIGS. 4 to 6 show the connection form of the large floating production ship, storage ship and transport ship according to the second embodiment, and FIGS. 4 (a) and 4 (b) show the large floating production ship. FIGS. 5A and 5B are a side view and a plan view of a storage ship, and FIGS. 5A and 5B are connections including the transport ship of Embodiment 2-1, FIGS. FIGS. 7 to 9 show a connection form of a large floating production ship, a storage ship and a transport ship according to the third embodiment, and FIG. b) is a side view and a plan view of a large floating production ship and a storage ship, respectively. FIGS. 8 (a) and 8 (b) are Embodiment 3-1, and FIGS. 9 (a) and 9 (b) are Embodiment 3. FIG. 10 is a side view and a plan view of a connected state including a transport ship of FIG. 2, and FIGS. 10 to 12 show a connection form of a large floating production ship, a storage ship and a transport ship according to the fourth embodiment. FIGS. 11A and 11B are a side view and a plan view of a large floating production ship and a storage ship, respectively, and FIGS. 11A and 11B are Embodiments 4-1, FIGS. ) Is a side view and a plan view of the connected state including the transport ship of Embodiment 4-2, FIG. 13 is a flowchart showing the LNG transport method according to the embodiment of the present invention, and FIG. FIG. 15 is a flowchart showing the LNG production process according to the second embodiment. It is an over door view.
　図１～図１２中、大型浮遊式生産船１に用いるための改造用既存船は、ＬＮＧタンカー、石油用タンカー、石油用ＦＰＳＯ船等を用いることができる。その中でも、船体の大きさが２００，０００～３５０，０００トンの船舶を用いると好ましい。改造後の船体には、海底５に接地した係留索１２（図１～３及び図７～９）または係留索１２及びエクスターナルタレット１７（図４～６及び図１０～１２）と、同じく海底５に接地したライザー１１と、第１の輸送設備であるＬＮＧ輸送設備（天然ガス輸送設備）１６（図１～６）またはＬＮＧ輸送設備（天然ガス輸送設備）６（図７～１２）と、得られる流体を貯蔵するための貯蔵設備と、油処理設備、ガス処理設備、水処理設備、発電設備等の生産設備と、コントロールシステムと、ボイラーと、各種ポンプ等のユーティリティ用の設備と、消火装置と、救命艇と、ヘリコプターデッキと、デッキクレーンと、バラストタンクと、作業員のための居住設備と、を少なくとも各一つ以上備えているものとする。 In FIG. 1 to FIG. 12, the existing ship for modification to be used for the large floating production ship 1 can be an LNG tanker, an oil tanker, an oil FPSO ship, or the like. Among them, it is preferable to use a ship having a hull size of 200,000 to 350,000 tons. The modified hull includes a mooring line 12 (FIGS. 1 to 3 and FIGS. 7 to 9) grounded to the seabed 5 or a mooring line 12 and an external turret 17 (FIGS. 4 to 6 and FIGS. 10 to 12). A riser 11 that is grounded, and a LNG transport facility (natural gas transport facility) 16 (FIGS. 1 to 6) or an LNG transport facility (natural gas transport facility) 6 (FIGS. 7 to 12) as the first transport facility. Storage equipment for storing fluids, production equipment such as oil treatment equipment, gas treatment equipment, water treatment equipment, power generation equipment, control systems, boilers, utility equipment such as various pumps, and fire extinguishing equipment And a lifeboat, a helicopter deck, a deck crane, a ballast tank, and at least one residence facility for workers.
　また、大型浮遊式生産船１にはＬＮＧの緩衝貯蔵設備を備えていてもよい。ＬＮＧの緩衝貯蔵設備は、貯蔵船２へのＬＮＧ輸送が短期的または長期的に中断する場合、ＬＮＧを緩衝貯蔵するために設置される。たとえば、短期的に中断する場合の例として、悪天候時、貯蔵船２が大型浮遊式生産船１に接近することができない場合などが挙げられる。なお、この緩衝貯蔵設備の容積は５，０００ｍ３～１０，０００ｍ３であると好ましい。 Further, the large floating production ship 1 may be provided with an LNG buffer storage facility. The LNG buffer storage facility is installed to buffer and store LNG when the LNG transport to the storage ship 2 is interrupted in the short term or in the long term. For example, a case where the storage ship 2 cannot approach the large floating production ship 1 during bad weather is an example of a case where the suspension is short-term. The volume of the buffer storage facility is preferably 5,000 m 3 to 10,000 m 3 .
　さらに、大型浮遊式生産船１には及び天然ガスの液化設備を備えていてもよい。この液化設備は、カスケードプロセス、混合冷媒プロセス、エキスパンダープロセス等を用いることができる。その中でも、生産効率がよく、混合冷媒の成分がいずれも原料天然ガスに含まれる成分を用いることができる、混合冷媒プロセスを用いることが好ましい。 Furthermore, the large floating production ship 1 and a natural gas liquefaction facility may be provided. As this liquefaction facility, a cascade process, a mixed refrigerant process, an expander process, or the like can be used. Among them, it is preferable to use a mixed refrigerant process in which production efficiency is good and all components of the mixed refrigerant can use components contained in the raw natural gas.
　貯蔵船２に用いるための改造用既存船は、ＬＮＧ用タンカーを用いることができる。その中でも、船体のタンク容量が８０，０００～１５０，０００ｍ３の船舶を用いると好ましい。改造後の船体にはＬＮＧ貯蔵設備２２と、第２の輸送設備であるＬＮＧ輸送設備（天然ガス輸送設備）２３（図２、５、８、１１）またはＬＮＧ輸送設備（天然ガス輸送設備）２７（図３、６、９、１２）と、ＬＮＧ輸送ポンプ、発電設備、消火装置と、救命艇と、デッキクレーンと、バラストタンクと、作業員のための居住設備と、を少なくとも各一つ以上備えているものとする。また、天然ガスの液化設備または気化したガスの再液化設備を備えていてもよく、その液化プロセスは上述のように、カスケードプロセス、混合冷媒プロセス、エキスパンダープロセス等を用いることができる。 An LNG tanker can be used for the existing ship for modification to be used for the storage ship 2. Among them, it is preferable to use a ship having a hull tank capacity of 80,000 to 150,000 m 3 . The modified hull includes an LNG storage facility 22 and a second transport facility LNG transport facility (natural gas transport facility) 23 (FIGS. 2, 5, 8 and 11) or LNG transport facility (natural gas transport facility) 27. (Figs. 3, 6, 9, and 12), at least one LNG transport pump, power generation equipment, fire extinguishing device, lifeboat, deck crane, ballast tank, and housing facilities for workers. It shall be provided. Further, a natural gas liquefaction facility or a vaporized gas reliquefaction facility may be provided, and the liquefaction process may be a cascade process, a mixed refrigerant process, an expander process, or the like as described above.
　輸送船３は、一般的なＬＮＧタンカーを用いることができ、ＬＮＧ貯蔵設備３１を備えているものとする。
　ＬＮＧ貯蔵設備２２及びＬＮＧ貯蔵設備３１の型式は、モス型、独立角形、独立円筒型、メンブレン型等を用いることができる。その中でも、スロッシング衝撃が小さく、ＬＮＧの蒸発ガス（ＢＯＧ）が少ないモス型あるいはスロッシング衝撃に十分な強度をもった独立角型を用いるのが好ましい。 The transport ship 3 can use a general LNG tanker and is provided with an LNG storage facility 31.
As the model of the LNG storage facility 22 and the LNG storage facility 31, a moss type, an independent square shape, an independent cylindrical shape, a membrane type, or the like can be used. Among them, it is preferable to use a moss type having a small sloshing impact and a small amount of LNG vapor (BOG) or an independent square type having a sufficient strength for the sloshing impact.
　大型浮遊式生産船１、貯蔵船２、輸送船３の船体構造は船級協会の要求にしたがう。 The hull structure of large floating production ship 1, storage ship 2 and transport ship 3 is in accordance with the requirements of the classification society.
　係留形式は多点係留式（図１～３及び図７～９）、一点係留式（図４～６及び図１０～１２）を用いることができる。多点係留式は必要経費が少なくて済み、一点係留式は広範囲で用いることができるという利点が挙げられる。多点係留式（図１～３及び図７～９）とする場合は、貯蔵船２に係留索２１を備える。一点係留にはタレットが船体内部に位置するインターナルタレット、切り離し型のディスコネクタブルタレット、タレットが船首外部にあるエクスターナルタレット、タワーヨークを用いることができ、これらの中から、海象条件に合った最適なシステムを選択することができる。例えば、図４～６及び図１０～１２のエクスターナルタレット１７は、比較的海象条件が厳しくなく、水深が深い地域に用いられる。 As the mooring type, a multipoint mooring type (FIGS. 1 to 3 and FIGS. 7 to 9) and a single point mooring type (FIGS. 4 to 6 and FIGS. 10 to 12) can be used. The multi-point mooring method requires less cost and the one-point mooring method has the advantage that it can be used in a wide range. In the case of the multi-point mooring type (FIGS. 1 to 3 and FIGS. 7 to 9), the storage ship 2 is provided with a mooring line 21. For one-point mooring, an internal turret with the turret located inside the hull, a disconnectable disconnectable turret, an external turret with the turret outside the bow, and a tower yoke can be used. An optimal system can be selected. For example, the external turrets 17 of FIGS. 4 to 6 and FIGS. 10 to 12 are used in areas where the sea conditions are relatively strict and the water depth is deep.
　各船舶の配置は、大型浮遊式生産船１と貯蔵船２が直列に連結されるタンデム型、並列に連結される横付け型とすることができる。タンデム型は連結時に船体側面の損傷が少なく、より広い海域で用いることができ、横付け型はＬＮＧ輸送経路が短く、且つ人員の移動も容易に行えるなどの利点が挙げられる。貯蔵船２と輸送船３の配置においても、タンデム型、横付け型を用いることができる。これらの配置はＦＰＳＯを用いる海象条件により選択される。 The arrangement of each ship can be a tandem type in which the large floating production ship 1 and the storage ship 2 are connected in series, or a horizontal type in which they are connected in parallel. The tandem type has advantages such that the side of the hull is less damaged at the time of connection and can be used in a wider sea area, and the horizontal type has a short LNG transport route and can easily move personnel. Also in the arrangement of the storage ship 2 and the transport ship 3, a tandem type or a horizontal type can be used. These arrangements are selected according to sea conditions using FPSO.
　各船舶の連結設備は、各船舶の配置を横付け型とする場合、関節構造を持った関節付きフェンダー支持フレーム１４（図１～６）及び２５（図２、５、８及び１１）のような剛性的な連結手段、または係留索１３（図１～６）及び２４（図２、５、８及び１１）のような弾性的な連結手段を適宜選択することができる他、両方の手段を同時に用いることができる。なお、剛性的に連結する場合、各船舶の相対運動を許容できるようにその連結手段に関節を設け、浮力体１５（図１～６）及び２６（図２、５、８及び１１）を設ける必要がある。また、各船舶の配置をタンデム型とする場合、係留索７（図７～１２）及び２８（図３、６、９、１２）のような弾性的な連結手段が好ましい。 As for the connection equipment of each ship, when the arrangement of each ship is a horizontal type, the jointed fender support frames 14 (FIGS. 1 to 6) and 25 (FIGS. 2, 5, 8 and 11) having a joint structure are used. Rigid connection means, or elastic connection means such as mooring lines 13 (FIGS. 1-6) and 24 (FIGS. 2, 5, 8 and 11) can be selected as appropriate, and both means can be used simultaneously. Can be used. In the case of rigid connection, joints are provided in the connection means so as to allow relative movement of each ship, and buoyancy bodies 15 (FIGS. 1 to 6) and 26 (FIGS. 2, 5, 8 and 11) are provided. There is a need. Further, when the arrangement of each ship is a tandem type, elastic connection means such as mooring lines 7 (FIGS. 7 to 12) and 28 (FIGS. 3, 6, 9, and 12) are preferable.
　各船舶間におけるＬＮＧ輸送設備（天然ガス輸送設備）６、１６、２３及び２７は、ローディングアーム、ローディングホースを用いることができる。また、大型浮遊式生産船１においてＬＮＧを生産し、貯蔵船２に輸送した場合、貯蔵船２で気化した天然ガスを再液化のために大型浮遊式生産船１に送り返すリターンガスローディングアーム、リターンガスローディングホースを備えていることが必要である。なお、ＬＮＧの輸送（荷役）時において、船舶の相対変位（揺動）が大きい場合は、フレキシブルなローディングホース及びリターンガスローディングホースを用いるのが好ましい。さらに、このローディングホース及びリターンガスローディングホースは、海面４から十分な高さを維持できるよう配設し、界面の波の影響を受けない位置にあることがと好ましい。 The LNG transport facility (natural gas transport facility) 6, 16, 23 and 27 between the ships can use a loading arm and a loading hose. In addition, when LNG is produced in the large floating production ship 1 and transported to the storage ship 2, the return gas loading arm that returns the natural gas vaporized in the storage ship 2 to the large floating production ship 1 for re-liquefaction. It is necessary to have a gas loading hose. Note that when the LNG is transported (shipping), if the relative displacement (swing) of the ship is large, it is preferable to use a flexible loading hose and a return gas loading hose. Further, it is preferable that the loading hose and the return gas loading hose are arranged so as to maintain a sufficient height from the sea surface 4 and are in a position not affected by the wave at the interface.
　図１３は、本発明の実施形態に係るＬＮＧの輸送方法をフローチャートで示したものであり、以下の実施形態はこのフローチャートをより具体的に説明するものである。図１３中、ＬＮＧ生産工程Ｓ１は大型浮遊式生産船１において天然ガスの液化を行う工程を示したものであり、貯蔵船２において気化した天然ガスを再液化する工程を任意で含むことができる。ＬＮＧ生産工程Ｓ１については、以下の実施形態１及び図１４で詳細に説明する。また、ＬＮＧ生産工程Ｓ２は貯蔵船２において天然ガスの液化を行う工程を示したものである。ＬＮＧ生産工程Ｓ２については、以下の実施形態２及び図１５で詳細に説明する。 FIG. 13 is a flowchart showing a method for transporting LNG according to an embodiment of the present invention, and the following embodiment will more specifically describe this flowchart. In FIG. 13, the LNG production process S1 shows a process of liquefying natural gas in the large floating production ship 1, and can optionally include a process of reliquefying the natural gas vaporized in the storage ship 2. . The LNG production process S1 will be described in detail with reference to the first embodiment and FIG. The LNG production process S2 shows a process of liquefying natural gas in the storage ship 2. The LNG production process S2 will be described in detail with reference to the second embodiment and FIG.
［実施形態１］
　実施形態１は、海象条件が穏やかな地域に適した形態の一例を示す。図１～３は実施形態１に係る大型浮遊式生産船１、貯蔵船２及び輸送船３の構成を示す平面図及び側面図であり、大型浮遊式生産船１と貯蔵船２が並列に連結される横付け型を採用した例を示している。特に、図１は大型浮遊式生産船１と貯蔵船２のみを図示しており、図２は輸送船３を貯蔵船２に並列に連結し、横付け型とした実施形態１－１を図示しており、図３は輸送船３を貯蔵船２に直列に連結し、タンデム型とした実施形態１－２を図示している。 [Embodiment 1]
Embodiment 1 shows an example of a form suitable for an area where the sea conditions are mild. 1 to 3 are a plan view and a side view showing the configuration of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the first embodiment. The large floating production ship 1 and the storage ship 2 are connected in parallel. The example which employ | adopted the horizontal type | mold used is shown. In particular, FIG. 1 shows only a large floating production ship 1 and a storage ship 2, and FIG. 2 illustrates an embodiment 1-1 in which a transport ship 3 is connected in parallel to the storage ship 2 and is a horizontal type. FIG. 3 illustrates an embodiment 1-2 in which the transport ship 3 is connected in series to the storage ship 2 to be a tandem type.
　まず、既存の２５０，０００トンの大きさの石油用タンカーに３相セパレーター、ガス精製装置、ガス圧縮装置、油水処理装置、液化設備、コントロールシステム、ＬＮＧ輸送ポンプ、発電装置、ボイラー、係留装置、安全設備等を搭載するように改造し、大型浮遊式生産船１とする（図１３、工程１０１）。その後、大型浮遊式生産船１を海域のガス田近傍に係留する（図１３、工程１０２）。
　一方、既存の容量１２５，０００ｍ３のＬＮＧタンクを持ったＬＮＧ用タンカーに再液化装置を搭載し、貯蔵設備として再利用するように改造して貯蔵船２とした（図１３、工程２０１）後、先にガス田近傍に係留した大型浮遊式生産船１の近傍に配設し（図１３、工程１０３）、連結する（図１３、工程１０４）。この時、連結手段は係留索１３及び関節付きフェンダー支持フレーム１４を用い、さらに浮力体１５を配設する。また、係留方式は多点係留式とし、大型浮遊式生産船１と貯蔵船２を係留する方式を採用する。
　次に、大型浮遊式生産船１と貯蔵船２の間に第１の輸送設備であるＬＮＧ輸送設備１６を接続する（図１３、工程１０５）。このとき、大型浮遊式生産船１にＬＮＧ輸送設備１６、すなわちＬＮＧ輸送用ローディングアームと、貯蔵船２で気化した天然ガスを大型浮遊式生産船１に戻すリターンガスローディングアームを搭載する。
　その後、輸送船３を実施形態１－１（図２）または１－２（図３）の配置で貯蔵船２の近傍に配設した後、貯蔵船２に連結する（図１３、工程３０１）。この時の連結手段は、実施形態１－１（図２）では係留索２４及び関節付きフェンダー支持フレーム２５を用い、さらに浮力体２６を配設する。また、実施形態１－２（図３）では係留索２８を用いる。
　さらに貯蔵船２と輸送船３の間に、実施形態１－１（図２）ではＬＮＧ輸送設備２３を、実施形態１－２（図３）ではＬＮＧ輸送設備２７を接続する（図１３、工程３０２）。このとき、実施形態１－１（図２）では貯蔵船２にＬＮＧ輸送設備２３、すなわちＬＮＧ輸送用ローディングアームと、輸送船３で気化した天然ガスを貯蔵船２に戻すリターンガスローディングアームを搭載する。また、実施形態１－２（図３）ではＬＮＧ輸送設備２７としてローディングホース及びリターンガスローディングホースを搭載する。 First, an oil tanker with a size of 250,000 tons, a three-phase separator, a gas refining device, a gas compression device, an oil / water treatment device, a liquefaction facility, a control system, an LNG transport pump, a power generation device, a boiler, a mooring device, It is remodeled so as to be equipped with safety equipment and the like, and a large floating production ship 1 is obtained (FIG. 13, step 101). Thereafter, the large floating production ship 1 is moored near the gas field in the sea area (FIG. 13, step 102).
On the other hand, a reliquefaction device is mounted on an LNG tanker having an LNG tank with a capacity of 125,000 m 3 , and modified to be reused as a storage facility to form a storage ship 2 (FIG. 13, step 201) In the vicinity of the large floating production ship 1 moored in the vicinity of the gas field (FIG. 13, step 103) and connected (FIG. 13, step 104). At this time, the connecting means uses the mooring cable 13 and the articulated fender support frame 14, and the buoyancy body 15 is further provided. The mooring method is a multi-point mooring method, and a method of mooring the large floating production ship 1 and the storage ship 2 is adopted.
Next, the LNG transport facility 16 as the first transport facility is connected between the large floating production ship 1 and the storage ship 2 (FIG. 13, step 105). At this time, the large floating production ship 1 is equipped with an LNG transportation facility 16, that is, a loading arm for LNG transportation, and a return gas loading arm for returning the natural gas vaporized in the storage ship 2 to the large floating production ship 1.
Thereafter, the transport ship 3 is arranged in the vicinity of the storage ship 2 in the arrangement of Embodiment 1-1 (FIG. 2) or 1-2 (FIG. 3), and then connected to the storage ship 2 (FIG. 13, step 301). . As the connecting means at this time, the mooring cable 24 and the articulated fender support frame 25 are used in the embodiment 1-1 (FIG. 2), and a buoyancy body 26 is further provided. In the embodiment 1-2 (FIG. 3), the mooring line 28 is used.
Further, the LNG transportation facility 23 in the embodiment 1-1 (FIG. 2) and the LNG transportation facility 27 in the embodiment 1-2 (FIG. 3) are connected between the storage ship 2 and the transportation ship 3 (FIG. 13, process). 302). At this time, in Embodiment 1-1 (FIG. 2), the storage ship 2 is equipped with an LNG transport facility 23, that is, a loading arm for LNG transport, and a return gas loading arm for returning the natural gas vaporized by the transport ship 3 to the storage ship 2. To do. In the embodiment 1-2 (FIG. 3), a loading hose and a return gas loading hose are mounted as the LNG transport facility 27.
　その後、ＬＮＧ生産工程Ｓ１を経て、貯蔵船２に貯蔵されたＬＮＧをＬＮＧ輸送用ポンプにて輸送する（図１３、工程３０３）。
　さらにその後、輸送船３を貯蔵船２より離脱させ（図１３、工程３０４）、輸送船３を運行することによりＬＮＧを輸送する（図１３、工程３０５）。 Thereafter, the LNG stored in the storage ship 2 is transported by the LNG transport pump through the LNG production step S1 (FIG. 13, step 303).
Thereafter, the transport ship 3 is detached from the storage ship 2 (FIG. 13, step 304), and the LNG is transported by operating the transport ship 3 (FIG. 13, step 305).
　なお、ＬＮＧ生産工程Ｓ１は図１４に示すように、以下の工程により構成される。
　ライザー１１をガス田に設置し（工程Ｓ１０１）、ガス田より油、ガス、水の混在した流体を回収する（工程Ｓ１０２）。回収された流体は３相セパレーターで、油、ガス、水に粗分離する（工程Ｓ１０３）。分離された油はさらに水分を除去し（工程Ｓ１０４）、大型浮遊式生産船１の油用貯蔵タンクに蓄えられる（工程Ｓ１０５）。一方、分離された天然ガスは水分、硫黄分、炭酸ガス等を除去され（工程Ｓ１０６）、その後、圧縮、冷却されＬＮＧを得る（工程Ｓ１０８）。ガス田のガス成分によってはプロパン、ブタン等を冷却前に分離する装置を大型浮遊式生産船１に搭載し、分離工程を行う（工程Ｓ１０７）。 In addition, as shown in FIG. 14, LNG production process S1 is comprised by the following processes.
The riser 11 is installed in the gas field (step S101), and fluid in which oil, gas, and water are mixed is recovered from the gas field (step S102). The recovered fluid is roughly separated into oil, gas, and water by a three-phase separator (step S103). The separated oil further removes moisture (step S104) and is stored in the oil storage tank of the large floating production ship 1 (step S105). On the other hand, moisture, sulfur content, carbon dioxide gas, etc. are removed from the separated natural gas (step S106), and then compressed and cooled to obtain LNG (step S108). Depending on the gas components of the gas field, a device for separating propane, butane and the like before cooling is mounted on the large floating production ship 1 and a separation step is performed (step S107).
　次に、大型浮遊式生産船１にて生産したＬＮＧをＬＮＧ輸送用ポンプにて貯蔵船２に輸送し、貯蔵する（工程Ｓ１０９）。また、貯蔵船２のタンクから発生する天然ガスを貯蔵船２に搭載された再液化装置にてＬＮＧに変換し（工程Ｓ１１０）、貯蔵船２のタンクに送ることにより、天然ガスのロスを防ぐ。
　上記のＬＮＧ生産工程Ｓ１を経て、貯蔵船２から輸送船３へＬＮＧを輸送する（工程３０３）。
　なお、輸送船３を貯蔵船２の近傍に配設し、貯蔵船２と連結する工程（図１３、工程３０１）から輸送船３を用いてＬＮＧを輸送する工程（図１３、工程３０５）を連続して行うことができる。 　 Next, the LNG produced by the large floating production ship 1 is transported to the storage ship 2 by the LNG transport pump and stored (step S109). Further, the natural gas generated from the tank of the storage ship 2 is converted into LNG by the reliquefaction device mounted on the storage ship 2 (step S110), and sent to the tank of the storage ship 2, thereby preventing the loss of natural gas. .
The LNG is transported from the storage ship 2 to the transport ship 3 through the LNG production process S1 (step 303).
In addition, the process (FIG. 13, process 305) which transports LNG using the transport ship 3 from the process (FIG. 13, process 301) which arrange | positions the transport ship 3 in the vicinity of the storage ship 2, and connects with the storage ship 2 is carried out. Can be done continuously.
［実施形態２］
　実施形態２は、比較的海象条件が厳しく、水深が深い地域に適した形態の一例を示す。図４～６は実施形態２に係る大型浮遊式生産船１、貯蔵船２及び輸送船３の構成を示す平面図及び側面図であり、大型浮遊式生産船１と貯蔵船２が並列に連結される横付け型を採用した例を示している。特に、図４は大型浮遊式生産船１と貯蔵船２のみを図示しており、図５は輸送船３を貯蔵船２に並列に連結し、横付け型とした実施形態２－１を図示しており、図６は輸送船３を貯蔵船２に直列に連結し、タンデム型とした実施形態２－２を図示している。 [Embodiment 2]
Embodiment 2 shows an example of a form suitable for an area where sea conditions are relatively severe and the water depth is deep. 4 to 6 are a plan view and a side view showing configurations of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the second embodiment. The large floating production ship 1 and the storage ship 2 are connected in parallel. The example which employ | adopted the horizontal type | mold used is shown. In particular, FIG. 4 illustrates only the large floating production ship 1 and the storage ship 2, and FIG. 5 illustrates an embodiment 2-1 in which the transport ship 3 is connected to the storage ship 2 in parallel to form a horizontal type. FIG. 6 shows an embodiment 2-2 in which the transport ship 3 is connected in series to the storage ship 2 to be a tandem type.
　まず、既存の２５０，０００トンの大きさの石油用タンカーに３相セパレーター、ガス精製装置、ガス圧縮装置、油水処理装置、コントロールシステム、ＬＮＧ輸送ポンプ、発電装置、ボイラー、係留装置、安全設備等を搭載するように改造し、大型浮遊式生産船１とする（図１３、工程１０１）。その後、大型浮遊式生産船１を海域のガス田近傍に係留する（図１３、工程１０２）。係留方式は一点係留式の中でもエクスターナルタレット１７を用いて係留する方式を採用する。
　一方、既存の容量１５０，０００ｍ３の貯蔵設備を持ったＬＮＧ運搬船を天然ガスの液化設備を搭載するように改造して貯蔵船２とした（図１３、工程２０１）後、先にガス田近傍に係留した大型浮遊式生産船１の近傍に配設し（図１３、工程１０３）、連結する（図１３、工程１０４）。この時、連結手段は係留索１３及び関節付きフェンダー支持フレーム１４を用い、さらに浮力体１５を配設する。
　次に、大型浮遊式生産船１と貯蔵船２の間に第１の輸送設備である天然ガス輸送設備１６を接続する（図１３、工程１０５）。このとき、天然ガス輸送設備１６はローディングアームとする。
　その後、輸送船３を実施形態２－１（図５）または２－２（図６）の配置で貯蔵船２の近傍に配設した後、貯蔵船２に連結する（図１３、工程３０１）。この時の連結手段は、実施形態２－１（図５）では係留索２４及び関節付きフェンダー支持フレーム２５を用い、さらに浮力体２６を配設する。また、実施形態２－２（図６）では係留索２８を用いる。
　さらに貯蔵船２と輸送船３の間に、実施形態２－１（図５）ではＬＮＧ輸送設備２３を、実施形態２－２（図６）ではＬＮＧ輸送設備２７を接続する（図１３、工程３０２）。このとき、実施形態２－１（図５）では貯蔵船２にＬＮＧ輸送設備２３、すなわちＬＮＧ輸送用ローディングアームと、輸送船３で気化した天然ガスを貯蔵船２に戻すリターンガスローディングアームを搭載する。また、実施形態２－２（図６）ではＬＮＧ輸送設備２７としてローディングホース及びリターンガスローディングホースを搭載する。 First, an oil tanker with a size of 250,000 tons, a three-phase separator, a gas refining device, a gas compression device, an oil / water treatment device, a control system, an LNG transport pump, a power generation device, a boiler, a mooring device, safety equipment, etc. To a large floating production ship 1 (FIG. 13, step 101). Thereafter, the large floating production ship 1 is moored near the gas field in the sea area (FIG. 13, step 102). The mooring method employs a method of mooring using the external turret 17 among the one-point mooring methods.
On the other hand, an LNG carrier with an existing storage facility with a capacity of 150,000 m 3 was remodeled to be equipped with a natural gas liquefaction facility to form storage vessel 2 (FIG. 13, step 201), and then in the vicinity of the gas field. Is placed near the large floating production ship 1 moored at (FIG. 13, step 103) and connected (FIG. 13, step 104). At this time, the connecting means uses the mooring cable 13 and the articulated fender support frame 14, and the buoyancy body 15 is further provided.
Next, the natural gas transportation facility 16 as the first transportation facility is connected between the large floating production ship 1 and the storage ship 2 (FIG. 13, step 105). At this time, the natural gas transport facility 16 is a loading arm.
Thereafter, the transport ship 3 is arranged in the vicinity of the storage ship 2 in the arrangement of Embodiment 2-1 (FIG. 5) or 2-2 (FIG. 6), and then connected to the storage ship 2 (FIG. 13, step 301). . As the connection means at this time, the mooring cable 24 and the articulated fender support frame 25 are used in the embodiment 2-1 (FIG. 5), and a buoyancy body 26 is further provided. In the embodiment 2-2 (FIG. 6), the mooring line 28 is used.
Further, between the storage ship 2 and the transport ship 3, an LNG transport facility 23 is connected in the embodiment 2-1 (FIG. 5) and an LNG transport facility 27 is connected in the embodiment 2-2 (FIG. 6) (FIG. 13, process). 302). At this time, in the embodiment 2-1 (FIG. 5), the storage ship 2 is equipped with the LNG transportation facility 23, that is, the loading arm for LNG transportation, and the return gas loading arm for returning the natural gas vaporized by the transportation ship 3 to the storage ship 2. To do. In the embodiment 2-2 (FIG. 6), a loading hose and a return gas loading hose are mounted as the LNG transport facility 27.
　その後、ＬＮＧ生産工程Ｓ２を経て、貯蔵船２で生産されたＬＮＧをＬＮＧ輸送用ポンプにて輸送する（図１３、工程３０３）。
　さらにその後、輸送船３を貯蔵船２より離脱させ（図１３、工程３０４）、輸送船３を運行することによりＬＮＧを輸送する（図１３、工程３０５）。 Thereafter, the LNG produced by the storage ship 2 is transported by the LNG transport pump through the LNG production step S2 (FIG. 13, step 303).
Thereafter, the transport ship 3 is detached from the storage ship 2 (FIG. 13, step 304), and the LNG is transported by operating the transport ship 3 (FIG. 13, step 305).
　なお、ＬＮＧ生産工程Ｓ２は図１５に示すように、以下の工程により構成される。
　ライザー１１をガス田に設置し（工程Ｓ２０１）、ガス田より油、ガス、水の混在した流体を回収する（工程Ｓ２０２）。回収された流体は３相セパレーターで、油、ガス、水に粗分離する（工程Ｓ２０３）。分離された油はさら水分を除去し（工程Ｓ２０４）、大型浮遊式生産船１の油用貯蔵タンクに蓄えられる（工程Ｓ２０５）。一方、分離された天然ガスは水分、硫黄分、炭酸ガス等を除去され（工程Ｓ２０６）、不純物を含まない天然ガスを得る。ガス田のガス成分によってはプロパン、ブタン等を冷却前に分離する装置を大型浮遊式生産船１に搭載し、分離工程を行う（工程Ｓ２０７）。 In addition, as shown in FIG. 15, LNG production process S2 is comprised by the following processes.
The riser 11 is installed in the gas field (step S201), and the fluid in which oil, gas, and water are mixed is recovered from the gas field (step S202). The recovered fluid is roughly separated into oil, gas, and water by a three-phase separator (step S203). The separated oil further removes moisture (step S204) and is stored in the oil storage tank of the large floating production ship 1 (step S205). On the other hand, moisture, sulfur content, carbon dioxide gas, etc. are removed from the separated natural gas (step S206) to obtain a natural gas containing no impurities. Depending on the gas components in the gas field, a device for separating propane, butane and the like before cooling is mounted on the large floating production ship 1 and a separation step is performed (step S207).
　次に、大型浮遊式生産船１にて精製された天然ガスをガス圧縮機にて貯蔵船２に輸送する（工程Ｓ２０８）。その後、貯蔵船２にて天然ガスを窒素冷媒としたターボエクスパンダーで冷却した窒素等の冷媒で天然ガスを冷却して液化し、ＬＮＧを得る（工程Ｓ２０９）。
　上記のＬＮＧ生産工程Ｓ２を経て、貯蔵船２から輸送船３へＬＮＧを輸送する（工程３０３）。
　なお、輸送船３を貯蔵船２の近傍に配設し、貯蔵船２と連結する工程（図１３、工程３０１）から輸送船３を用いてＬＮＧを輸送する工程（図１３、工程３０５）を連続して行うことができる。 　 Next, natural gas purified by the large floating production ship 1 is transported to the storage ship 2 by a gas compressor (step S208). Then, natural gas is cooled and liquefied with a refrigerant such as nitrogen cooled by a turbo expander using natural gas as a nitrogen refrigerant in the storage ship 2 to obtain LNG (step S209).
　 The LNG is transported from the storage ship 2 to the transport ship 3 through the LNG production process S2 (process 303).
In addition, the process (FIG. 13, process 305) which transports LNG using the transport ship 3 from the process (FIG. 13, process 301) which arrange | positions the transport ship 3 in the vicinity of the storage ship 2, and connects with the storage ship 2 is carried out. Can be done continuously.
［実施形態３］
　実施形態３は、比較的海象条件が厳しい地域の中でも、特に東南アジア海域に適した形態の一例を示す。図７～図９は実施形態３に係る大型浮遊式生産船１、貯蔵船２及び輸送船３の構成を示す平面図及び側面図であり、大型浮遊式生産船１と貯蔵船２が直列に連結されるタンデム型を採用した例を示している。特に、図７は大型浮遊式生産船１と貯蔵船２のみを図示しており、図８は輸送船３を貯蔵船２に並列に連結し、横付け型とした実施形態３－１を図示しており、図９は輸送船３を貯蔵船２に直列に連結し、タンデム型とした実施形態３－２を図示している。 [Embodiment 3]
Embodiment 3 shows an example of the form suitable for the Southeast Asian sea area especially in the area where sea conditions are comparatively severe. 7 to 9 are a plan view and a side view showing the configuration of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the third embodiment. The large floating production ship 1 and the storage ship 2 are connected in series. The example which employ | adopted the tandem type | mold connected is shown. In particular, FIG. 7 shows only the large floating production ship 1 and the storage ship 2, and FIG. 8 illustrates an embodiment 3-1 in which the transport ship 3 is connected to the storage ship 2 in parallel and is a horizontal type. FIG. 9 illustrates an embodiment 3-2 in which the transport ship 3 is connected to the storage ship 2 in series to form a tandem type.
　各船舶の配置以外は、上述の実施形態１または２と同様の設備を用い、同様の工程を経ることにより実施可能となる。なお、各船舶の連結について、大型浮遊式生産船１と貯蔵船２の連結手段は係留索７を用い、ＬＮＧ輸送設備（天然ガス輸送設備）６としてローディングホース及びリターンガスローディングホースを搭載する。また、実施形態３－１（図８）では貯蔵船２と輸送船３の連結手段を係留索２４及び関節付きフェンダー支持フレーム２５を用い、さらに浮力体２６を配設する。また、実施形態３－２（図９）では係留索２８を用いる。 Except for the arrangement of each ship, the same equipment as in the above-described embodiment 1 or 2 is used, and it can be implemented through the same process. In connection with the connection of each ship, the connecting means of the large floating production ship 1 and the storage ship 2 uses a mooring line 7, and a loading hose and a return gas loading hose are mounted as an LNG transport facility (natural gas transport facility) 6. In the embodiment 3-1 (FIG. 8), a mooring line 24 and an articulated fender support frame 25 are used as a connecting means for the storage ship 2 and the transport ship 3, and a buoyancy body 26 is further provided. In the embodiment 3-2 (FIG. 9), the mooring line 28 is used.
［実施形態４］
　実施形態４は、比較的海象条件が厳しく、水深が深い地域に適した形態の一例を示す。図１０～図１２は実施形態４に係る大型浮遊式生産船１、貯蔵船２及び輸送船３の構成を示す平面図及び側面図であり、大型浮遊式生産船１と貯蔵船２が並列に連結される横付け型を採用した例を示している。特に、図１０は大型浮遊式生産船１と貯蔵船２のみを図示しており、図１１は輸送船３を貯蔵船２に並列に連結し、横付け型とした実施形態４－１を図示しており、図１２は輸送船３を貯蔵船２に直列に連結し、タンデム型とした実施形態４－２を図示している。 [Embodiment 4]
Embodiment 4 shows an example of a form suitable for an area where sea conditions are relatively severe and the water depth is deep. 10 to 12 are a plan view and a side view showing the configuration of the large floating production ship 1, the storage ship 2 and the transport ship 3 according to the fourth embodiment. The large floating production ship 1 and the storage ship 2 are arranged in parallel. The example which employ | adopted the horizontal type connected is shown. In particular, FIG. 10 illustrates only the large floating production ship 1 and the storage ship 2, and FIG. 11 illustrates the embodiment 4-1 in which the transport ship 3 is connected to the storage ship 2 in parallel to be installed horizontally. FIG. 12 illustrates an embodiment 4-2 in which the transport ship 3 is connected to the storage ship 2 in series to be a tandem type.
　各船舶の配置以外は、上述の実施形態１または２と同様の設備を用い、同様の工程を経ることにより実施可能となる。なお、各船舶の連結について、大型浮遊式生産船１と貯蔵船２の連結手段は係留索７を用い、ＬＮＧ輸送設備（天然ガス輸送設備）６としてローディングホース及びリターンガスローディングホースを搭載する。また、実施形態４－１（図１１）では貯蔵船２と輸送船３の連結手段を係留索２４及び関節付きフェンダー支持フレーム２５を用い、さらに浮力体２６を配設する。また、実施形態４－２（図１２）では係留索２８を用いる。 Except for the arrangement of each ship, the same equipment as in the above-described embodiment 1 or 2 is used, and it can be implemented through the same process. In connection with the connection of each ship, the connecting means of the large floating production ship 1 and the storage ship 2 uses a mooring line 7, and a loading hose and a return gas loading hose are mounted as an LNG transport facility (natural gas transport facility) 6. In the embodiment 4-1 (FIG. 11), the mooring line 24 and the articulated fender support frame 25 are used as a connecting means for the storage ship 2 and the transport ship 3, and a buoyancy body 26 is further provided. In the embodiment 4-2 (FIG. 12), the mooring line 28 is used.

Claims (6)

  1. 　海域で液化天然ガスを生産し、該液化天然ガスを輸送する方法であって、
    　既存の船舶を大型浮遊式生産船に改造する工程と、
    　前記改造された大型浮遊式生産船をガス田近傍に係留する工程と、
    　前記改造された大型浮遊式生産船において海底から天然ガスを回収、分離、精製、液化する工程と、
    　既存の船舶を液化天然ガスの貯蔵設備を備えた貯蔵船に改造する工程と、
    　前記改造された大型浮遊式生産船の近傍に、前記改造された貯蔵船を配設し、前記改造された大型浮遊式生産船に前記改造された貯蔵船を連結する工程と、
    　前記改造された大型浮遊式生産船と前記改造された貯蔵船との間に、液化天然ガスの第１の輸送設備を接続する工程と、
    　前記第１の輸送設備により、前記改造された大型浮遊式生産船において生産された液化天然ガスを前記改造された貯蔵船に輸送する工程と、
    　前記改造された貯蔵船の近傍に、液化天然ガスの貯蔵設備を備えた輸送船を配設し、前記改造された貯蔵船に前記輸送船を連結する工程と、
    　前記改造された貯蔵船と前記輸送船との間に、液化天然ガスの第２の輸送設備を接続する工程と、
    　前記第２の輸送設備により、前記改造された貯蔵船に貯蔵された液化天然ガスを前記輸送船に輸送する工程と、
    　前記輸送船を前記改造された貯蔵船より離脱させ、前記輸送船を運行して天然ガスを輸送する工程と、
    を備えてなることを特徴とする、海域で生産された液化天然ガスを輸送する方法。     A method for producing liquefied natural gas in a sea area and transporting the liquefied natural gas,
    Remodeling an existing ship into a large floating production ship;
    Mooring the modified large floating production ship near the gas field;
    Recovering, separating, purifying, and liquefying natural gas from the seabed in the modified large floating production ship;
    Remodeling existing vessels into storage vessels with liquefied natural gas storage facilities;
    Arranging the modified storage ship in the vicinity of the modified large floating production ship and connecting the modified storage ship to the modified large floating production ship;
    Connecting a first transportation facility for liquefied natural gas between the modified large floating production ship and the modified storage ship;
    Transporting liquefied natural gas produced in the modified large floating production ship to the modified storage ship by the first transport facility;
    Disposing a transport ship having a storage facility for liquefied natural gas in the vicinity of the modified storage ship, and connecting the transport ship to the modified storage ship;
    Connecting a second liquefied natural gas transport facility between the modified storage ship and the transport ship;
    Transporting liquefied natural gas stored in the modified storage ship to the transport ship by the second transport facility;
    Detaching the transport ship from the modified storage ship and operating the transport ship to transport natural gas;
    A method for transporting liquefied natural gas produced in the sea area, comprising:
  2. 　前記改造された大型浮遊式生産船において、
    　海底より天然ガスを含む流体を回収する工程と、
    　前記流体を分離、精製する工程と、
    　前記分離工程で得られた気体を液化するために加圧、冷却して液化天然ガスを得る工程と、
    　前記液化天然ガスを緩衝貯蔵設備に輸送する工程と、
    　前記緩衝貯蔵設備から前記改造された貯蔵船と連結された第１の輸送設備に液化天然ガスを輸送する工程と、
    　を備えてなることを特徴とする請求項１に記載の海域で生産された液化天然ガスを輸送する方法。     In the modified large floating production ship,
    Recovering a fluid containing natural gas from the seabed;
    Separating and purifying the fluid;
    Pressurizing and cooling to liquefy the gas obtained in the separation step to obtain liquefied natural gas;
    Transporting the liquefied natural gas to a buffer storage facility;
    Transporting liquefied natural gas from the buffer storage facility to a first transport facility coupled to the modified storage vessel;
    The method for transporting liquefied natural gas produced in the sea area according to claim 1, comprising:
  3. 　前記改造された貯蔵船において、
    　前記改造された大型浮遊式生産船から輸送された液化天然ガスを貯蔵設備に輸送する工程と、
    　気化したガスを再液化する工程と、
    　前記再液化して得られた液化天然ガスを前記改造された貯蔵船の貯蔵設備に輸送する工程と、
    　前記輸送船と連結された第２の輸送設備に液化天然ガスを輸送する工程と、
    　を備えてなることを特徴とする請求項１または２に記載の海域で生産された液化天然ガスを輸送する方法。     In the modified storage vessel,
    Transporting liquefied natural gas transported from the modified large floating production ship to a storage facility;
    Re-liquefying the vaporized gas;
    Transporting the liquefied natural gas obtained by the re-liquefaction to a storage facility of the modified storage ship;
    Transporting liquefied natural gas to a second transport facility connected to the transport ship;
    The method for transporting liquefied natural gas produced in the sea area according to claim 1 or 2, characterized by comprising:
  4. 　海域で液化天然ガスを生産し、該液化天然ガスを輸送する方法であって、
    　既存の船舶を大型浮遊式生産船に改造する工程と、
    　前記改造された大型浮遊式生産船をガス田近傍に係留する工程と、
    　前記改造された大型浮遊式生産船において海底から天然ガスを回収、分離、精製する工程と、
    　既存の船舶を天然ガスの液化及び貯蔵設備と液化天然ガスの貯蔵設備を備えた貯蔵船に改造する工程と、
    　前記改造された大型浮遊式生産船の近傍に、前記改造された貯蔵船を配設し、前記改造された大型浮遊式生産船に前記改造された貯蔵船を連結する工程と、
    　前記改造された大型浮遊式生産船と前記改造された貯蔵船との間に、天然ガスの第１の輸送設備を接続する工程と、
    　前記第１の輸送設備により、前記改造された大型浮遊式生産船において精製された天然ガスを前記改造された貯蔵船に輸送する工程と、
    　前記改造された貯蔵船において天然ガスを液化する工程と、
    　前記改造された貯蔵船の近傍に、液化天然ガスの貯蔵設備を備えた輸送船を配設し、前記改造された貯蔵船に前記輸送船を連結する工程と、
    　前記改造された貯蔵船と前記輸送船との間に、液化天然ガスの第２の輸送設備を接続する工程と、
    　前記第２の輸送設備により、前記改造された貯蔵船に貯蔵された液化天然ガスを前記輸送船に輸送する工程と、
    　前記輸送船を前記改造された貯蔵船より離脱させ、前記輸送船を運行して天然ガスを輸送する工程と、
    を備えてなることを特徴とする、海域で生産された液化天然ガスを輸送する方法。     A method for producing liquefied natural gas in a sea area and transporting the liquefied natural gas,
    Remodeling an existing ship into a large floating production ship;
    Mooring the modified large floating production ship near the gas field;
    Recovering, separating and refining natural gas from the sea floor in the modified large floating production ship;
    Remodeling an existing vessel into a storage vessel with natural gas liquefaction and storage facilities and liquefied natural gas storage facilities;
    Arranging the modified storage ship in the vicinity of the modified large floating production ship, and connecting the modified storage ship to the modified large floating production ship;
    Connecting a first natural gas transport facility between the modified large floating production ship and the modified storage ship;
    Transporting the natural gas purified in the modified large floating production ship to the modified storage ship by the first transport facility;
    Liquefying natural gas in the modified storage vessel;
    Disposing a transport ship having a storage facility for liquefied natural gas in the vicinity of the modified storage ship, and connecting the transport ship to the modified storage ship;
    Connecting a second liquefied natural gas transport facility between the modified storage ship and the transport ship;
    Transporting liquefied natural gas stored in the modified storage ship to the transport ship by the second transport facility;
    Detaching the transport ship from the modified storage ship and operating the transport ship to transport natural gas;
    A method for transporting liquefied natural gas produced in the sea area, comprising:
  5. 　前記改造された貯蔵船において、
    　前記改造された大型浮遊式生産船から輸送された天然ガスを冷却して液化天然ガスを得る工程と、
    　前記液化天然ガスを貯蔵する工程と、
    　前記輸送船と連結された第２の輸送設備に液化天然ガスを輸送する工程と、
    　を備えてなることを特徴とする請求項４に記載の海域で生産された液化天然ガスを輸送する方法。     In the modified storage vessel,
    Cooling the natural gas transported from the modified large floating production ship to obtain liquefied natural gas;
    Storing the liquefied natural gas;
    Transporting liquefied natural gas to a second transport facility connected to the transport ship;
    The method for transporting liquefied natural gas produced in the sea area according to claim 4.
  6. 　前記改造された貯蔵船の近傍に、液化天然ガスの貯蔵設備を備えた輸送船を停泊させ、前記改造された貯蔵船に前記輸送船を連結する工程から、
    　前記輸送船を前記改造された貯蔵船より離脱させ、前記輸送船を運行して天然ガスを輸送する工程までの各工程を連続して繰り返すことを特徴とする請求項１又は４に記載の海域で生産された液化天然ガスを輸送する方法。     From the step of anchoring a transport ship equipped with a storage facility for liquefied natural gas in the vicinity of the modified storage ship, and connecting the transport ship to the modified storage ship,
    5. The sea area according to claim 1, wherein each step of the transport ship is detached from the modified storage ship, and the steps until the transport ship is operated to transport natural gas are repeated continuously. For transporting liquefied natural gas produced in Japan.
PCT/JP2009/057104 2009-04-07 2009-04-07 Method for transporting liquefied natural gas produced in sea area WO2010116489A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PCT/JP2009/057104 WO2010116489A1 (en) 2009-04-07 2009-04-07 Method for transporting liquefied natural gas produced in sea area

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/JP2009/057104 WO2010116489A1 (en) 2009-04-07 2009-04-07 Method for transporting liquefied natural gas produced in sea area

Publications (1)

Publication Number Publication Date
WO2010116489A1 true WO2010116489A1 (en) 2010-10-14

Family

ID=42935798

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/JP2009/057104 WO2010116489A1 (en) 2009-04-07 2009-04-07 Method for transporting liquefied natural gas produced in sea area

Country Status (1)

Country Link
WO (1) WO2010116489A1 (en)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2508417A3 (en) * 2011-03-11 2013-01-23 Keppel Offshore&Marine Technology Centre Pte Ltd Offshore systems and methods for liquefied gas production, storage and offloading to reduce and prevent damage
WO2016055525A1 (en) * 2014-10-08 2016-04-14 Sbm Schiedam B.V. Lng carrier vessel, and method for manufacturing such an lng carrier vessel

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPS4840016A (en) * 1971-09-27 1973-06-12
JP2000513061A (en) * 1997-04-02 2000-10-03 シントロレウム コーポレーション System and method for hydrate recovery
JP2002501861A (en) * 1998-01-30 2002-01-22 デン ノルスケ スタッツ オルジェセルスカプ エイ．エス LNG transport system

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPS4840016A (en) * 1971-09-27 1973-06-12
JP2000513061A (en) * 1997-04-02 2000-10-03 シントロレウム コーポレーション System and method for hydrate recovery
JP2002501861A (en) * 1998-01-30 2002-01-22 デン ノルスケ スタッツ オルジェセルスカプ エイ．エス LNG transport system

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2508417A3 (en) * 2011-03-11 2013-01-23 Keppel Offshore&Marine Technology Centre Pte Ltd Offshore systems and methods for liquefied gas production, storage and offloading to reduce and prevent damage
US8864420B2 (en) 2011-03-11 2014-10-21 Keppel Offshore & Marine Technology Centre Pte Ltd Offshore systems and methods for liquefied gas production, storage and offloading to reduce and prevent damage
WO2016055525A1 (en) * 2014-10-08 2016-04-14 Sbm Schiedam B.V. Lng carrier vessel, and method for manufacturing such an lng carrier vessel
CN107074327A (en) * 2014-10-08 2017-08-18 Sbm斯希丹有限公司 The method of LNG cargo ships and this LNG cargo ships of manufacture

Similar Documents

Publication Publication Date Title
US9903647B2 (en) Systems and methods for floating dockside liquefaction of natural gas
CN103237728B (en) Float LNG plant and for method of the LNG vehicles conversion of a vessel for floating LNG plant
US10197220B2 (en) Integrated storage/offloading facility for an LNG production plant
US20160231050A1 (en) Expandable lng processing plant
AU2017207324B2 (en) Natural gas liquefaction vessel
Gu et al. LNG-FPSO: Offshore LNG solution
JP2011235675A (en) Lng floating production, storage and offloading facility and lng floating production, storage and offloading method
AU2007233572B2 (en) LNG production facility
AU2012207059B2 (en) Linked LNG production facility
WO2010116489A1 (en) Method for transporting liquefied natural gas produced in sea area
KR200482095Y1 (en) Topside module structure and marine structure having the same
AU2008219347B2 (en) Linked LNG production facility
AU2008219346B2 (en) Sheltered LNG production facility
AU2012207058A1 (en) Sheltered LNG production facility
KR20140144846A (en) Ship Or Floating Marine Structure
Fales et al. An Innovative Floating LNG Vessel

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 09842999

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 09842999

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: JP