WO2018078688A1 - Procédé de fabrication d'une installation d'hydrocarbures gazeux liquéfiés de type flottante - Google Patents

Procédé de fabrication d'une installation d'hydrocarbures gazeux liquéfiés de type flottante Download PDF

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Publication number
WO2018078688A1
WO2018078688A1 PCT/JP2016/081425 JP2016081425W WO2018078688A1 WO 2018078688 A1 WO2018078688 A1 WO 2018078688A1 JP 2016081425 W JP2016081425 W JP 2016081425W WO 2018078688 A1 WO2018078688 A1 WO 2018078688A1
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WIPO (PCT)
Prior art keywords
hydrocarbon gas
gas
plant
liquefied hydrocarbon
floating
Prior art date
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PCT/JP2016/081425
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English (en)
Japanese (ja)
Inventor
輝久 緒方
菊池　淳
Original Assignee
千代田化工建設株式会社
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 千代田化工建設株式会社 filed Critical 千代田化工建設株式会社
Priority to KR1020177029666A priority Critical patent/KR101929435B1/ko
Priority to JP2017536980A priority patent/JP6337213B1/ja
Priority to CN201680024072.7A priority patent/CN108473180B/zh
Priority to SG11201803401TA priority patent/SG11201803401TA/en
Priority to PCT/JP2016/081425 priority patent/WO2018078688A1/fr
Publication of WO2018078688A1 publication Critical patent/WO2018078688A1/fr

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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B83/00—Rebuilding or retrofitting vessels, e.g. retrofitting ballast water treatment systems
    • B63B83/30—Rebuilding or retrofitting vessels, e.g. retrofitting ballast water treatment systems for improving energy efficiency, e.g. by improving hydrodynamics or by upgrading the power plant
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B25/00—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby
    • B63B25/02—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods
    • B63B25/08—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid
    • B63B25/12—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid closed
    • B63B25/16—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid closed heat-insulated
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/08—Mounting arrangements for vessels
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/08—Mounting arrangements for vessels
    • F17C13/082—Mounting arrangements for vessels for large sea-borne storage vessels
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
    • B63B35/44—Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
    • B63B2035/4433—Floating structures carrying electric power plants
    • B63B2035/444—Floating structures carrying electric power plants for converting combustion energy into electric energy
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/06—Fluid distribution
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]

Definitions

  • the present invention relates to a method for manufacturing a floating liquefied hydrocarbon gas plant that reuses a liquefied hydrocarbon gas tank in a ship that transports liquefied hydrocarbon gas.
  • LNG ship that transports liquefied natural gas (hereinafter referred to as “LNG”)
  • LNG ship a liquefied natural gas tank mounted on the hull (hereinafter referred to as “LNG ship”) , "LNG tank”)
  • LNG ship a liquefied natural gas tank mounted on the hull
  • LNG tank a liquefied natural gas tank mounted on the hull
  • Patent Document 1 For example, removing the LNG tank from the first hull of the LNG ship using the first crane, and mounting the LNG tank on a hull different from the first hull using the same or different crane as the first crane; And a technology for preventing the LNG tank from coming into contact with seawater is known (see Patent Document 1).
  • the inventors of the present application have found that when the LNG tank of an existing LNG ship is reused in the production of a floating liquefied natural gas plant operating on the sea, the longitudinal direction in the floating liquefied natural gas plant is It has been found that by making the length smaller than that of an existing LNG ship, the required strength of the hull part constituting the floating liquefied natural gas plant is reduced, and a part of the hull of the existing LNG ship can be reused. It was.
  • LNG can be used in a relatively small-scale plant (for example, supply of LNG-generated power according to small and medium power demand) Is possible. Further, there is an advantage that a BOG (boil-off gas) processing facility attached to the LNG tank or the like can be reused.
  • BOG blow-off gas
  • the above-mentioned technology for reusing ships by the inventors of the present application is not limited to LNG ships, but ships that transport other liquefied hydrocarbon gases such as LPG (liquefied petroleum gas) (hereinafter including LNG ships) It is also applicable to a liquefied hydrocarbon gas transport ship ”), and the floating plant to be manufactured is not limited to a liquefied natural gas plant, but other liquefied hydrocarbon gas such as LPG can be used. It is also possible to use a plant to be used (hereinafter collectively referred to as a “floating liquefied hydrocarbon gas plant” including a liquefied natural gas plant).
  • a method for manufacturing a floating liquefied hydrocarbon gas plant that reuses a liquefied hydrocarbon gas tank of a ship that transports liquefied hydrocarbon gas, Dividing a ship into a plurality of blocks including at least one liquefied hydrocarbon gas tank; and at least one of the plurality of blocks, a liquefied hydrocarbon gas plant connected to at least one of the blocks in the front-rear direction. And a step of constructing a new floating structure portion having the block, and the combined length of the block and the floating structure portion connected to the block is smaller than that of the ship.
  • the required strength and the required structural plate thickness for the hull part constituting the floating liquefied hydrocarbon gas plant are reduced by making the longitudinal length of the floating liquefied hydrocarbon gas plant smaller than that of the existing ship. Therefore, the existing ship can be reused efficiently (that is, including a part of the hull).
  • the second aspect of the present invention is characterized by further comprising a step of installing at least a part of plant equipment in the floating structure portion.
  • the degree of freedom of installation of equipment and devices constituting the plant equipment is increased, and the manufacturing of the floating liquefied hydrocarbon gas plant is facilitated.
  • the floating structure portion is provided with a plurality of decks arranged in the vertical direction in which the plant facilities are respectively arranged.
  • the block to which the floating structure portion is connected includes equipment for propelling the ship.
  • the plant equipment includes a gas engine and a gas using a hydrocarbon gas and / or a boil-off gas obtained by regasifying the liquefied hydrocarbon stored in the liquefied hydrocarbon gas tank. At least one of the turbines is included.
  • the electric power generated using hydrocarbon gas is liquefied. It can be used inside or outside a hydrocarbon gas plant. Moreover, the structure by which the cold energy utilization apparatus of liquefied hydrocarbon gas was attached to the gas engine is also possible.
  • a gas turbine combined power generation facility may be used as the plant facility.
  • At least one of the gas engine and the gas turbine is used for generating propulsion power.
  • this floating liquefied hydrocarbon gas plant can move on the sea without requiring a tugboat or the like.
  • a step of providing a heat exchanger that further heats the heated refrigerant, and a condenser that condenses the refrigerant discharged from the refrigerant turbine by heat exchange with the hydrocarbon gas delivered from the liquefied hydrocarbon gas tank. is further provided.
  • the exhaust heat of the gas engine heat of exhaust gas and coolant
  • the refrigerant turbine that uses hydrocarbon-based or carbon dioxide refrigerant as the working fluid
  • the exhaust heat recovery rate of the gas engine increases, As a result, the power generation efficiency of the plant equipment can be improved.
  • the gas turbine using a hydrocarbon gas stored in the liquefied hydrocarbon gas tank as a fuel, a hydrocarbon-based or carbon dioxide refrigerant as a working fluid,
  • a refrigerant turbine a generator driven by the refrigerant turbine, an exhaust heat recovery boiler that recovers exhaust heat of the gas turbine, and a heater that heats the coolant with a heat medium heated by the exhaust heat recovery boiler;
  • the refrigerant heater that heats the refrigerant using the coolant heated by the heater as a heat source and the heat exchange between the refrigerant discharged from the refrigerant turbine and the hydrocarbon gas delivered from the liquefied hydrocarbon gas tank
  • the step of providing a condenser for condensation is provided.
  • the plant equipment is characterized in that a re-gasified hydrocarbon gas is simultaneously delivered while power is generated by a generator driven by the gas engine.
  • the plant equipment is characterized in that a re-gasified hydrocarbon gas is simultaneously delivered while power is generated by a generator driven by the gas turbine.
  • the twelfth aspect of the present invention is characterized in that the liquefied hydrocarbon gas is at least one of liquefied natural gas and liquefied petroleum gas.
  • an existing ship that transports liquefied hydrocarbon gas can be efficiently reused as a floating liquefied hydrocarbon gas plant that uses liquefied natural gas and liquefied petroleum gas.
  • the method for manufacturing a floating liquefied hydrocarbon gas plant is characterized in that a floating structure portion connected to the block has the same width as the block.
  • a method for manufacturing a floating liquefied hydrocarbon gas plant wherein the plant installation area disposed in the floating structure portion is isolated from seawater by at least two longitudinal partition walls. It is characterized by that.
  • the method for producing a floating liquefied hydrocarbon gas plant is characterized in that the plant installation area disposed in the floating structure part is isolated from seawater by a double bottom. To do.
  • a method for producing a floating liquefied hydrocarbon gas plant includes plant waste water, plant fluid (including refrigerant fluid, heat fluid, etc.), fuel oil, and lubrication in the floating structure portion.
  • a tank for storing at least one of the oils is arranged.
  • a method for manufacturing a floating liquefied hydrocarbon gas plant is characterized in that a new floating structure portion is provided with the block and a longitudinal partition wall that is structurally continuous with the block. .
  • the method for manufacturing a floating liquefied hydrocarbon gas plant is characterized in that the floating structure portion is not closed by an upper deck or the like.
  • the method for manufacturing a floating liquefied hydrocarbon gas plant is characterized in that the floating structure portion has a plurality of sections divided by at least one partition wall.
  • a method for manufacturing a floating liquefied hydrocarbon gas plant wherein the block and a floating structure connected to the block have a ballast tank, and hull attitude control (trim and heel adjustment). Is possible.
  • the method for manufacturing a floating liquefied hydrocarbon gas plant is characterized in that the block and the floating structure part have a mooring facility with a jetty or the seabed.
  • a method for manufacturing a floating liquefied hydrocarbon gas plant for mooring a floating body constituted by the block and a floating structure portion connected to the block with a ship such as an LNG ship.
  • the facility has a loading facility for exchanging liquefied hydrocarbon gas (for example, LNG) and boil-off gas, and the liquefied hydrocarbon gas can be received from the ship into the liquefied hydrocarbon gas tank in the block.
  • a method for manufacturing a floating liquefied hydrocarbon gas plant for mooring a floating body constituted by the block and a floating structure portion connected to the block with a ship such as an LNG ship.
  • the facility has a loading facility for exchanging liquefied hydrocarbon gas (for example, LNG) and boil-off gas, and is capable of delivering liquefied hydrocarbon gas from a liquefied hydrocarbon gas tank in the block to a ship.
  • the method for manufacturing a floating liquefied hydrocarbon gas plant is characterized in that the floating structure portion has an upper structure for living or working.
  • the method for manufacturing a floating liquefied hydrocarbon gas plant is characterized in that the floating structure portion includes propulsion equipment.
  • FIG. 1 is a side view and a top view illustrating a configuration example of an LNG ship 1 including LNG tanks 2A to 2D to be reused according to an embodiment of the present invention.
  • the terms (front and rear, left and right, up and down) indicating directions used in the following description are determined based on the LNG ship 1 shown in FIG. (For example, the right bow direction is “front” and the left stern direction is “rear”.)
  • the LNG ship 1 is an existing ship used for LNG sea transportation, and a plurality of (here, four) LNG tanks 2A to 2D (hereinafter, particularly, LNG can be filled and stored). When there is no need to distinguish between them, they are collectively referred to as “LNG tank 2”.), Propulsion equipment 3 and hull 4 on which they are mounted.
  • the existing ship to be reused is a ship whose aging of the hull 4 (at least a part excluding the LNG tank 2 and including the outer shell of the ship) has progressed due to long-term use or the like.
  • the present invention is not limited to this, and it may be a ship that is no longer necessary.
  • an example in which the LNG ship 1 is reused as a liquefied hydrocarbon gas transport ship to be reused is shown, but not limited to this, storage for liquefied hydrocarbon gas at least similar to the LNG tank 2
  • a ship that transports another liquefied hydrocarbon gas such as an LPG ship that transports LPG can be similarly reused.
  • the LNG ship can be reused for a floating liquefied natural gas plant and a floating liquefied petroleum gas plant, and the LPG ship can be reused for a floating liquefied petroleum gas plant.
  • FIG. 2 is an explanatory diagram showing a manufacturing example of the floating liquefied hydrocarbon gas plant 5 based on the reuse of the LNG ship 1 shown in FIG.
  • the LNG tank 2 of the LNG ship 1 and the hull 4 located around the LNG tank 2 A new floating liquefied hydrocarbon gas plant 5 is manufactured by reusing a part of the structural member.
  • the LNG ship 1 is divided into a plurality of blocks (here, the first) at an appropriate place such as a construction dog for a ship (not shown). 1st to 4th blocks 11, 12, 13, 14). Each of the first to fourth blocks 11, 12, 13, and 14 includes a structural member such as one LNG tank 2A to 2D and a divided hull 4 positioned in the vicinity thereof.
  • the LNG ship 1 is divided along a plurality (here, three) of dividing surfaces 16, 17, 18 (see also FIG. 1) that are substantially perpendicular to the front-rear direction.
  • the floating structure portions 22 and 23 respectively connected to the front and rear of the second block 12 are newly constructed.
  • corresponding structural members are provided in the second block 12 so as to be continuous in the front-rear direction with respect to the hull outer shell and other main structural members extending in the front-rear direction.
  • the front floating structure 22 is a protective structure for protecting the front of the second block 12 (LNG tank 2B)
  • the rear floating structure 23 is the floating structure shown in FIG. Similar to the part 21, it is a structure for plant installation.
  • the rear floating body structure portion 23 is provided with a cabin 31 used for an operation room or the like of the plant facility 30 as necessary.
  • the floating liquefied hydrocarbon gas plant 5 shown in FIG. 2B does not have an existing propulsion facility, the floating liquefied hydrocarbon gas plant 5 moves over the sea to a desired location using a known tugboat or the like. However, a configuration in which propulsion equipment is newly provided in the floating structure portion 23 is also possible.
  • a floating structure portion 24 connected to the rear of the fourth block 14 is newly constructed.
  • corresponding structural members are provided in the fourth block 14 so as to be continuous in the front-rear direction with respect to the hull outer shell and other main structural members extending in the longitudinal direction.
  • the floating structure portion 24 is a structure for plant installation, like the floating structure portion 23 of FIG.
  • one LNG ship 1 having four LNG tanks 2A to 2D is divided into four first to fourth blocks 11, 12, and 13, and all these blocks are used to provide four floating liquefactions. Since the hydrocarbon gas plant 5 is manufactured, substantially the entire LNG ship 1 can be reused. However, the present invention is not limited to this, and in the production of the floating liquefied hydrocarbon gas plant 5, only a part of a plurality of separated blocks can be reused.
  • the length of the newly produced floating liquefied hydrocarbon gas plant 5 in the front-rear direction needs to be set smaller than the length of the LNG ship 1 to be reused. Accordingly, even when it is difficult to continue using the existing LNG ship 1 from the viewpoint of the required strength (for example, the required longitudinal strength value) for the structural member (particularly the hull), the floating type liquefaction with a shorter length is difficult.
  • the required strengths of the structural members (particularly, the hull portion) that form the periphery of the LNG tank in each of the blocks 11, 12, 13, and 14 are reduced, so that the required strengths can be satisfied.
  • the floating liquefied hydrocarbon gas plant 5 not only the LNG tank 2, but also structural members (at least a part thereof) such as the hull 4 located in the vicinity thereof can be reused.
  • the floating liquefied hydrocarbon gas plant 5 can reuse the existing ship efficiently (that is, including a part of the hull other than the LNG tank 2).
  • the plant equipment 30 that uses LNG is installed.
  • the plant equipment 30 may be other liquefied hydrocarbon gas such as LPG (liquefied petroleum gas) ( Alternatively, a configuration using hydrocarbon gas) is also possible.
  • LPG liquefied petroleum gas
  • a configuration using hydrocarbon gas is also possible.
  • LPG ship 1 LPG ship
  • LPG tank LPG ship
  • plant equipment 30 that uses LPG.
  • FIG. 3 is a cross-sectional view showing the LNG tank 2 of the floating liquefied hydrocarbon gas plant 5 and its surroundings.
  • the LNG tank 2 employs a moss system (spherical independent tank system) as the tank system, and the LNG tank 2 includes a spherical tank body 41 and a hull 4 (foundation). It has a known structure such as a skirt 42, a tank cover 43, etc., which are fixed to the deck) and form a cylindrical support structure.
  • a moss system spherical independent tank system
  • the LNG tank 2 includes a spherical independent tank system (spherical independent tank system) as the tank system, and the LNG tank 2 includes a spherical tank body 41 and a hull 4 (foundation). It has a known structure such as a skirt 42, a tank cover 43, etc., which are fixed to the deck) and form a cylindrical support structure.
  • the floating liquefied hydrocarbon gas plant 5 not only the tank body 41 but also the surrounding structural members including a part of the hull 4 that supports the tank body 41 are reused.
  • some of them may be reused after being
  • a partition wall 45 (see FIG. 1) is provided as a structural member around the LNG tank 2 to partition the installation space of the LNG tank 2 back and forth.
  • the partition surfaces 45, 17, and 18 are set so as to be located at positions (front or rear) that do not overlap with the partition walls 45, so that the partition wall 45 is blocked by the block 11. , 12, 13, and 14 can be reused.
  • the LNG tank 2 is not limited to the moss method, and other methods (for example, a membrane method) capable of forming a plurality of independent tanks can be employed.
  • 4 and 5 are a cross-sectional view and a plan view of each part showing the arrangement of the plant equipment 30 in the floating structure portion 23 shown in FIG. 2 (B), respectively.
  • the floating structure portion 23 can be provided with a plurality of layers in the vertical direction.
  • the floating structure portion 23 is provided with an upper deck 51 located at the top, an intermediate deck 52 located below the upper deck 51, and a foundation deck 53 located at the bottom as three levels.
  • a BOG compressor, a vertical LNG storage tank, a heat exchanger for regasification of LNG, a heater, and the like can be arranged on the upper deck 51.
  • a gas turbine for power generation using LNG as fuel can be arranged in the intermediate deck 52.
  • a steam turbine, a generator, etc. can be arrange
  • Such a structure of the floating structure portion 23 can be similarly adopted in the other floating structure portions 21 and 24 where the plant equipment 30 is provided.
  • the plant equipment 30 provided in the floating liquefied hydrocarbon gas plant 5 includes a liquefied natural gas plant, a gas processing plant, an acid gas injection plant, a regasification plant, a power plant, and a liquefied petroleum gas plant, or those It is possible to employ a part of the plant as appropriate.
  • a tank that stores plant wastewater, plant liquid, fuel oil, lubricating oil, and the like may be disposed in the floating structure portion 23.
  • a tank or the like for holding an amine that absorbs acidic components in natural gas associated with the plant equipment 30, Produced Water (oil contaminated water), diesel oil, or the like can be provided.
  • the liquefied natural gas plant may include a liquefaction facility (such as a heat exchanger) for liquefying natural gas from a gas field.
  • a liquefaction facility such as a heat exchanger
  • the gas processing plant may include facilities for processing gas from gas fields such as slag catchers, acid gas (CO 2 , H 2 S, mercaptan, etc.) removal equipment, dehydration equipment, and mercury removal equipment. .
  • gas fields such as slag catchers, acid gas (CO 2 , H 2 S, mercaptan, etc.) removal equipment, dehydration equipment, and mercury removal equipment.
  • the acidic gas injection plant includes a plant for injecting into a layer other than a gas layer such as a gas field when it is difficult to process an acidic gas such as H 2 S.
  • the regasification plant includes a heat exchanger as a regasification facility, a hydrocarbon gas delivery facility that sends hydrocarbon gas from a floating liquefied hydrocarbon gas plant on the shore to a hydrocarbon gas consumption facility, and the like. May be included.
  • the power plant may include a turbine generator and a gas engine generator that use liquefied hydrocarbon gas as fuel, a power transmission facility that transmits power generated by a power plant on the shore to an existing power grid, and the like.
  • a turbine generator and a gas engine generator that use liquefied hydrocarbon gas as fuel
  • a power transmission facility that transmits power generated by a power plant on the shore to an existing power grid, and the like.
  • hydrocarbon gas regasified at the same time by the regasification plant while performing power generation by the gas engine generator or gas turbine generator in the power plant.
  • the liquefied petroleum gas plant may include a liquefaction facility (such as a compressor) for liquefying the gas.
  • a liquefaction facility such as a compressor
  • the plant equipment placement area (installation space) in the floating structure 23 is preferably separated from seawater by at least two longitudinal partition walls. Furthermore, the arrangement area of the plant equipment may be isolated from seawater by a double bottom.
  • the floating structure portion 23 may be provided with a block 12 and a longitudinal partition wall that is structurally continuous with the block 12. Further, the floating structure 23 can be configured not to be closed by an upper deck or the like.
  • the floating structure portion 23 may be provided with a plurality of sections separated by at least one partition wall having the same configuration as the partition wall 45.
  • the block 12 and the floating structure portion 23 connected to the block 12 may be configured to have buoyancy (float on the sea).
  • At least one of the block 12 and the floating structure portion 23 connected to the block 12 has a ballast tank, and hull attitude control (trim and heel adjustment) is possible.
  • at least one of the block 12 and the floating structure 23 can be provided with a mooring facility with a jetty or the seabed.
  • the floating body (floating body type liquefied hydrocarbon gas plant 5) constituted by the block 12 and the floating structure portion 23 connected to the block 12 is moored with the liquefied hydrocarbon gas transport ship, and the liquefied hydrocarbon gas.
  • a loading facility for exchanging (for example, LNG) and boil-off gas may be provided, and the liquefied hydrocarbon gas may be received from the liquefied hydrocarbon gas transport ship into the liquefied hydrocarbon gas tank in the block 12.
  • the floating body (floating body type liquefied hydrocarbon gas plant 5) constituted by the block 12 and the floating structure portion 23 connected to the block 12 is moored with the liquefied hydrocarbon gas transport ship, and the liquefied hydrocarbon gas.
  • a loading facility for exchanging (for example, LNG) and boil-off gas may be provided to receive the liquefied hydrocarbon gas from the liquefied hydrocarbon gas tank in the block 12 with respect to the liquefied hydrocarbon gas transport ship.
  • the floating structure portion 23 can be provided with an upper structure for living or working. Further, the plant equipment 30 can be provided with equipment for liquefying liquefied hydrocarbons stored in a liquefied hydrocarbon gas tank. Further, the floating structure portion 23 can be provided with a propulsion facility.
  • the degree of freedom of installation of the equipment and devices constituting the plant equipment 30 is increased, and the production of the floating liquefied hydrocarbon gas plant is increased.
  • the floating type is used. An increase in the length of the liquefied hydrocarbon gas plant 5 in the front-rear direction can be suppressed.
  • FIG. 6 is a configuration diagram showing a first example of plant equipment 30 provided in the floating liquefied hydrocarbon gas plant 5.
  • the case where a gas engine combined power plant is applied is shown as a preferred example of the plant equipment 30.
  • the gas engine combined power plant operates a gas engine (reciprocating engine) 61, which is an internal combustion engine using LNG as fuel, and a hydrocarbon-based refrigerant boiling at a low temperature (a temperature lower than water).
  • the refrigerant turbine 62 is a fluid, and power is generated by a generator 64 and a generator 65 driven by the gas engine 61 and the refrigerant turbine 62, respectively.
  • the gas engine 61 and the generator 64 can be configured to be integrated as a gas engine generator. At least a part of the generated electric power is supplied to the outside from the floating liquefied hydrocarbon gas plant 5 in a berthing state.
  • the gas engine 61 is supplied with a natural gas obtained by regasifying the LNG stored in the LNG tank 2 and a boil-off gas (hereinafter referred to as BOG) generated there, as a fuel, and a relatively high temperature (410 here) after combustion.
  • BOG boil-off gas
  • ° C) gas engine exhaust gas is discharged toward the heat exchanger 71 for exhaust heat recovery.
  • the gas engine 61 is provided with a cooling engine jacket (not shown), and jacket cooling water at a relatively low temperature (88 ° C. in this case) is discharged from the engine jacket.
  • the discharged jacket cooling water is circulated through a water circulation line 73 provided with a water circulation pump 72 in the direction indicated by the arrow in FIG.
  • the natural gas and boil-off gas can also be used as engine fuel for propulsion of the hull.
  • the generator 64 After the output of the gas engine 61 is converted into electric power by the generator 64, at least a part of the electric power is used to rotate the propeller 10 for propulsion through a motor or the like (not shown). Further, when the floating liquefied hydrocarbon gas plant 5 does not require a propulsion function, it is possible to supply all of the electric power generated by the generator 64 to the outside of the floating liquefied hydrocarbon gas plant 5. . In some cases, the generator 64 is omitted, while the output shaft of the gas engine 61 is connected to the propeller 10 via a known gear mechanism or the like, so that the output of the gas engine 61 is supplied to the floating liquefied hydrocarbon gas plant. It is also possible to use it for the promotion of 5.
  • a mixed refrigerant of methane and propane (here, methane 50 to 55% by weight, propane 45 to 50% by weight) is used as a working fluid.
  • This working fluid is heated by the gas engine exhaust gas in the heat exchanger 71 before being introduced into the refrigerant turbine 62.
  • the heat exchanger 71 is provided with a plurality of heating units composed of heat transfer tube groups, so that efficient heat exchange between the gas engine exhaust gas and the working fluid is possible.
  • a working fluid gas having a predetermined temperature and pressure (here, 103 ° C., 4.9 MPaG) is introduced into the refrigerant turbine 62, and turbine blades (not shown) are rotated by the kinetic energy of the working fluid.
  • the output is converted into electric power by the generator 65.
  • carbon dioxide may be used as the working fluid in addition to the hydrocarbon.
  • carbon dioxide recovered at a gas processing plant in the plant or carbon dioxide in the combustion exhaust gas of a gas engine or gas turbine can be used.
  • the working fluid (here, temperature: ⁇ 5 ° C., pressure: 0.4 MPaG gas) discharged from the refrigerant turbine 62 is sent to the condenser 82 through the refrigerant circulation line 81 in the direction indicated by the arrow in FIG.
  • a discharge line 83 from the LNG tank 2 is connected to the condenser 82, and the cold heat of the LNG having a temperature below the introduced freezing point (here, temperature: ⁇ 160 ° C., pressure: 7.0 MPaG) is the working fluid. Used for cooling.
  • the condenser 82 functions as a regasification device that vaporizes LNG by the heat of the working fluid.
  • the LNG stored in the LNG tank 2 is temporarily stored in the LNG storage tank 66 and then sent to the condenser 82 side via the discharge line 83 by the discharge pump 67.
  • the BOG generated in the LNG tank 2 is mixed with the LNG in the LNG storage tank 66 via the BOG compressor 68.
  • the working fluid condensed in the condenser 82 is temporarily stored in a circulating refrigerant storage tank 85 provided in the refrigerant circulation line 81. Thereafter, the working fluid (here, ⁇ 128 ° C., 5.0 MPaG, 99.4 t / hr) pressurized by the refrigerant pump 86 provided in the refrigerant circulation line 81 is sent to the refrigerant evaporator 87.
  • the refrigerant evaporator 87 is connected with a seawater introduction pipe 88 for introducing seawater (here, 15 ° C.) existing around the floating liquefied hydrocarbon gas plant 5, and the working fluid exchanges heat with seawater.
  • the jacket cooling water is preheated to a temperature at which it does not freeze (here, 5 ° C.).
  • the working fluid from the refrigerant evaporator 87 is sent to the refrigerant heater 91, where it is heated by heat exchange with jacket cooling water (88 ° C., 270 t / hr here) (here, heated to 29 ° C.). )
  • the jacket cooling water is cooled to a temperature at which the gas engine 61 can be cooled in the refrigerant heater 91 (here, 50 to 80 ° C.).
  • the working fluid from the refrigerant heater 91 is sent to the heat exchanger 71, and the heated working fluid (103 ° C., 4.9 MPaG) is supplied to the refrigerant turbine 62.
  • the heat exchanger 71 is omitted and the working fluid from the refrigerant heater 91 is supplied to the refrigerant turbine 62 without passing through the heat exchanger 71 is also possible.
  • LNG from the LNG tank 2 is discharged from the condenser 82 and then sent to the LNG heater 92 through the discharge line 83.
  • the LNG heater 92 is connected to a seawater introduction pipe 93 for introducing seawater (here, 15 ° C.) existing around the floating liquefied hydrocarbon gas plant 5, and the working fluid exchanges heat with seawater. (In this case, the gas becomes 5 ° C.) and is sent to the gas engine 61 as fuel.
  • the refrigerant turbine 62 using a mixed refrigerant of methane and propane as a working fluid uses the gas engine exhaust gas and the jacket cooling water as a high heat source, while reducing the cold energy during LNG gasification.
  • Power is generated by the binary Rankine cycle method used as a heat source.
  • the exhaust heat recovery rate can be increased by effectively using the heat of the gas engine exhaust gas and jacket cooling water, which occupy a large proportion of the exhaust heat of the gas engine 61, and thus the power generation efficiency of the gas engine combined power plant can be improved. Can be improved.
  • the heating temperature in the heat exchanger 71 is preferably relatively low (for example, 130 ° C. or lower) from the viewpoint of system safety.
  • the working fluid is condensed using LNG in the condenser 82, it is possible to effectively use the cold heat of LNG discharged from the LNG tank 2 in the cooling process of the refrigerant. Furthermore, since BOG is used as a part of the fuel gas of the gas engine 61, BOG generated from the LNG tank 2 can be used effectively, and the cold heat of LNG can be used effectively in the cooling process of the working fluid. It becomes.
  • the refrigerant turbine 62 using a hydrocarbon or carbon dioxide refrigerant as a working fluid is configured to use the exhaust heat (heat of exhaust gas and coolant) of the gas engine 61.
  • the exhaust heat recovery rate of the engine 61 is increased, and as a result, the power generation efficiency of the plant equipment 30 can be improved.
  • the gas engine combined power plant shown in FIG. 6 is not limited to the floating liquefied hydrocarbon gas plant 5 that reuses the existing LNG ship 1, but a floating liquefied hydrocarbon gas plant that is newly manufactured as a whole, and It is also possible to install on a floating structure including a ship or the like similar to this. Furthermore, the gas engine combined power generation plant shown in FIG. 6 can be used not only at sea but also as land facilities. In that case, LNG as fuel is supplied to the gas engine 61 from an on-land LNG tank or the like.
  • FIG. 7 is a configuration diagram showing a second example of the plant equipment 30 provided in the floating type liquefied hydrocarbon gas plant 5.
  • the case where a gas turbine combined power plant is applied is shown as a preferred example of the plant equipment 30.
  • the same components as those of the plant facility 30 shown in FIG. Further, matters not particularly mentioned below for the same constituent elements are the same as those in the plant facility 30 shown in FIG. 6 described above.
  • the gas turbine combined power plant includes a gas turbine 161 that uses LNG as a fuel, and a refrigerant turbine 62 that uses a hydrocarbon-based refrigerant boiling at a low temperature (a temperature lower than water) as a working fluid.
  • the gas turbine 161 and the generator 164 can be configured to be integrated as a gas turbine generator. At least a part of the generated electric power is supplied to the outside from the floating liquefied hydrocarbon gas plant 5 in a berthing state.
  • the gas turbine 161 is supplied with LNG stored in the LNG tank 2 and boil-off gas (hereinafter referred to as BOG) generated there as fuel, and the relatively high-temperature exhaust gas after combustion is directed to the exhaust heat recovery boiler 101. Discharged.
  • BOG boil-off gas
  • a part of the steam heated by the exhaust gas is introduced into the steam turbine 103 via the steam circulation line 102, and power is generated by the generator 104 driven by the steam turbine 103.
  • the generator 104 driven by the steam turbine 103.
  • the steam discharged from the steam turbine 103 is sent to the condenser 106.
  • the condenser 106 is connected to a seawater introduction pipe 107 for introducing seawater existing around the floating liquefied hydrocarbon gas plant 5, and steam from the steam turbine 103 is condensed by heat exchange with seawater.
  • the exhaust heat recovery boiler 101 is again supplied by the condensate pump 108.
  • the heat exchanger 71 shown in FIG. 6 is omitted, and the working fluid from the refrigerant heater 91 is supplied to the refrigerant turbine 62 without passing through the heat exchanger 71.
  • the refrigerant turbine 62 using a hydrocarbon or carbon dioxide refrigerant as a working fluid is configured to use the exhaust heat (heat of the coolant) of the gas turbine 161.
  • the power generation efficiency of the plant equipment 30 can be improved.
  • the gas turbine combined power plant shown in FIG. 7 is not limited to the floating liquefied hydrocarbon gas plant 5 that reuses the existing LNG ship 1, but a floating liquefied hydrocarbon gas plant that is newly manufactured as a whole, and It is also possible to install on a floating structure including a ship or the like similar to this. Moreover, the gas turbine combined power generation plant shown in FIG. 7 can be used not only on the sea but also on land. In that case, the gas turbine 161 is supplied with LNG as fuel from an on-shore LNG tank or the like.
  • the water engine 73 can be provided with the gas engine 61 shown in FIG.
  • the water engine 73 can be provided with the gas engine 61 shown in FIG.
  • the present invention has been described based on specific embodiments, these embodiments are merely examples, and the present invention is not limited to these embodiments.
  • the reuse of an existing ship by the method for manufacturing a floating liquefied hydrocarbon gas plant according to the present invention is not limited to the case where a part of an existing ship is used as it is in a floating liquefied hydrocarbon gas plant. This includes the case of reusing after repairing the structural members of some parts or exchanging some parts.
  • the manufacturing method of the above-mentioned floating type liquefied hydrocarbon gas plant should be used as a manufacturing method of a floating type liquefied hydrocarbon gas plant that reuses all types of liquefied hydrocarbon gas tanks of ships that transport liquefied hydrocarbon gas.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Ocean & Marine Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Water Supply & Treatment (AREA)
  • General Engineering & Computer Science (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Separation By Low-Temperature Treatments (AREA)

Abstract

Le problème décrit par la présente invention est de réutiliser efficacement un navire de transport d'hydrocarbures gazeux liquéfiés existant équipé d'un réservoir de GNL. La solution selon l'invention porte sur un procédé de fabrication d'une installation d'hydrocarbures gazeux liquéfiés de type flottante comprenant : une étape de division d'un navire de transport d'hydrocarbures gazeux liquéfiés (1) existant en une pluralité de blocs (11, 12, 13, 14) ayant chacun au moins un réservoir de GNL (2) ; et une étape de construction, par rapport à au moins un bloc de la pluralité de blocs (11, 12, 13, 14), d'une nouvelle section de structure flottante (21, 22, 23, 24) qui se raccorde à la direction avant et/ou arrière d'un tel bloc. La présente invention est conçue de telle sorte que la longueur combinée du bloc réutilisé (11, 12, 13, 14) et de la section de structure flottante (21, 22, 23, 24) raccordée à un tel bloc est inférieure à la longueur du navire de transport d'hydrocarbures gazeux liquéfiés (1).
PCT/JP2016/081425 2016-10-24 2016-10-24 Procédé de fabrication d'une installation d'hydrocarbures gazeux liquéfiés de type flottante WO2018078688A1 (fr)

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KR1020177029666A KR101929435B1 (ko) 2016-10-24 2016-10-24 부체식 액화 탄화수소 가스 플랜트의 제조 방법
JP2017536980A JP6337213B1 (ja) 2016-10-24 2016-10-24 浮体式液化炭化水素ガスプラントの製造方法
CN201680024072.7A CN108473180B (zh) 2016-10-24 2016-10-24 浮动液化烃气处理装置的制造方法
SG11201803401TA SG11201803401TA (en) 2016-10-24 2016-10-24 Manufacturing method of floating liquefied hydrocarbon gas plant
PCT/JP2016/081425 WO2018078688A1 (fr) 2016-10-24 2016-10-24 Procédé de fabrication d'une installation d'hydrocarbures gazeux liquéfiés de type flottante

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JP2020059396A (ja) * 2018-10-10 2020-04-16 三菱造船株式会社 船舶の製造方法
WO2020075631A1 (fr) * 2018-10-10 2020-04-16 三菱造船株式会社 Procédé d'utilisation de navires existants
WO2020075633A1 (fr) * 2018-10-10 2020-04-16 三菱造船株式会社 Procédé d'utilisation pour navires existants, procédé de production pour installation de stockage flottante, et installation de stockage flottante
WO2020115804A1 (fr) * 2018-12-03 2020-06-11 日揮グロ－バル株式会社 Procédé de production d'une installation flottante équipée d'un appareil de liquéfaction de gaz naturel
JP2020192895A (ja) * 2019-05-28 2020-12-03 株式会社 商船三井 水上浮体式設備
JP2022515700A (ja) * 2018-10-10 2022-02-22 サイペム・ソチエタ・ペル・アツィオーニ Ｌｎｇとｌｐｇの混合から得られる流体を使用するパワーサイクルにて電気エネルギーおよび熱エネルギーを製造するための方法
JP2022538725A (ja) * 2019-05-10 2022-09-06 ミツビシ パワー アメリカズ インコーポレイテッド コンバインドサイクル発電プラント用のデュアルサイクルシステム
WO2023102595A1 (fr) * 2021-12-07 2023-06-15 Charlie Six Pty Ltd Navire à gaz liquéfié
US11732644B2 (en) 2018-06-27 2023-08-22 Mitsubishi Power Americas, Inc. Organic Rankine Cycle for combined-cycle power plant
WO2023244182A1 (fr) * 2022-06-17 2023-12-21 Twenty20 Energy Systems Pte Ltd Système de production d'énergie flottant

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CN112648033B (zh) * 2020-12-25 2022-07-22 西安石油大学 一种利用lng冷能的bog燃气轮机、超临界co2布雷顿、卡琳娜联合循环发电系统

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US11732644B2 (en) 2018-06-27 2023-08-22 Mitsubishi Power Americas, Inc. Organic Rankine Cycle for combined-cycle power plant
WO2020075631A1 (fr) * 2018-10-10 2020-04-16 三菱造船株式会社 Procédé d'utilisation de navires existants
JP2020059399A (ja) * 2018-10-10 2020-04-16 三菱造船株式会社 既存船舶の利用方法
WO2020075633A1 (fr) * 2018-10-10 2020-04-16 三菱造船株式会社 Procédé d'utilisation pour navires existants, procédé de production pour installation de stockage flottante, et installation de stockage flottante
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JP2022515700A (ja) * 2018-10-10 2022-02-22 サイペム・ソチエタ・ペル・アツィオーニ Ｌｎｇとｌｐｇの混合から得られる流体を使用するパワーサイクルにて電気エネルギーおよび熱エネルギーを製造するための方法
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WO2020115804A1 (fr) * 2018-12-03 2020-06-11 日揮グロ－バル株式会社 Procédé de production d'une installation flottante équipée d'un appareil de liquéfaction de gaz naturel
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JP2020192895A (ja) * 2019-05-28 2020-12-03 株式会社 商船三井 水上浮体式設備
WO2023102595A1 (fr) * 2021-12-07 2023-06-15 Charlie Six Pty Ltd Navire à gaz liquéfié
WO2023244182A1 (fr) * 2022-06-17 2023-12-21 Twenty20 Energy Systems Pte Ltd Système de production d'énergie flottant

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CN108473180B (zh) 2020-04-03
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SG11201803401TA (en) 2019-01-30
JP6337213B1 (ja) 2018-06-06
CN108473180A (zh) 2018-08-31
JPWO2018078688A1 (ja) 2018-10-25

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