CN117677791A - Method for producing electric power by means of a device intended to be placed in a body of water - Google Patents

Method for producing electric power by means of a device intended to be placed in a body of water Download PDF

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Publication number
CN117677791A
CN117677791A CN202280048772.5A CN202280048772A CN117677791A CN 117677791 A CN117677791 A CN 117677791A CN 202280048772 A CN202280048772 A CN 202280048772A CN 117677791 A CN117677791 A CN 117677791A
Authority
CN
China
Prior art keywords
regasification
power production
unit
gas
module
Prior art date
Legal status (The legal status 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 status listed.)
Pending
Application number
CN202280048772.5A
Other languages
Chinese (zh)
Inventor
R·勒德韦哈特
P-E·古尔德齐尔
P·祖尔加雷
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Technip Energies France SAS
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Technip Energies France SAS
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Filing date
Publication date
Application filed by Technip Energies France SAS filed Critical Technip Energies France SAS
Publication of CN117677791A publication Critical patent/CN117677791A/en
Pending legal-status Critical Current

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
    • F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
    • F17C9/04—Recovery of thermal energy
    • 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
    • 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
    • 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
    • B63B27/30—Arrangement of ship-based loading or unloading equipment for transfer at sea between ships or between ships and off-shore structures
    • B63B27/34—Arrangement of ship-based loading or unloading equipment for transfer at sea between ships or between ships and off-shore structures using pipe-lines
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63J—AUXILIARIES ON VESSELS
    • B63J3/00—Driving of auxiliaries
    • B63J3/04—Driving of auxiliaries from power plant other than propulsion power plant
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D15/00—Adaptations of machines or engines for special use; Combinations of engines with devices driven thereby
    • F01D15/10—Adaptations for driving, or combinations with, electric generators
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D25/00—Component parts, details, or accessories, not provided for in, or of interest apart from, other groups
    • F01D25/32—Collecting of condensation water; Drainage ; Removing solid particles
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C7/00—Features, components parts, details or accessories, not provided for in, or of interest apart form groups F02C1/00 - F02C6/00; Air intakes for jet-propulsion plants
    • F02C7/12—Cooling of plants
    • F02C7/14—Cooling of plants of fluids in the plant, e.g. lubricant or fuel
    • F02C7/141—Cooling of plants of fluids in the plant, e.g. lubricant or fuel of working fluid
    • 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
    • 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
    • B63B2035/4486—Floating storage vessels, other than vessels for hydrocarbon production and storage, e.g. for liquid cargo
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2205/00—Vessel construction, in particular mounting arrangements, attachments or identifications means
    • F17C2205/03—Fluid connections, filters, valves, closure means or other attachments
    • F17C2205/0302—Fittings, valves, filters, or components in connection with the gas storage device
    • F17C2205/0352—Pipes
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2205/00—Vessel construction, in particular mounting arrangements, attachments or identifications means
    • F17C2205/03—Fluid connections, filters, valves, closure means or other attachments
    • F17C2205/0302—Fittings, valves, filters, or components in connection with the gas storage device
    • F17C2205/0352—Pipes
    • F17C2205/0364—Pipes flexible or articulated, e.g. a hose
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/03—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the pressure level
    • F17C2223/033—Small pressure, e.g. for liquefied gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0311—Air heating
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0311—Air heating
    • F17C2227/0313—Air heating by forced circulation, e.g. using a fan
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0316—Water heating
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0316—Water heating
    • F17C2227/0318—Water heating using seawater
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0323—Heat exchange with the fluid by heating using another fluid in a closed loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0327—Heat exchange with the fluid by heating with recovery of heat
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0388—Localisation of heat exchange separate
    • F17C2227/0393—Localisation of heat exchange separate using a vaporiser
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/04—Indicating or measuring of parameters as input values
    • F17C2250/0404—Parameters indicated or measured
    • F17C2250/0443—Flow or movement of content
    • 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
    • F17C2265/05—Regasification
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0105—Ships
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/011—Barges
    • F17C2270/0113—Barges floating
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0118—Offshore
    • F17C2270/0123—Terminals
    • 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
    • F17C2270/05—Applications for industrial use
    • F17C2270/0581—Power plants

Abstract

The invention relates to a method for producing electric power by means of a device (10), comprising: -a floating storage unit (16) comprising a main tank (28) for storing liquefied natural gas; a floating regasification and power generation unit (18) comprising a regasification module (30) and a power generation module (32); -a transfer unit (20) for transferring liquefied natural gas between the two units (16, 18). The production method comprises the following steps: -transferring the liquefied natural gas from the main tank (28) to the regasification and power generation unit (18) via the transfer unit (20); -regasifying the liquefied natural gas by the regasification module (30); -transferring the gas from the regasification module (30) to the power generation module (32); -generating electricity by the electricity generation module (32).

Description

Method for producing electric power by means of a device intended to be placed in a body of water
The present invention relates to a method of producing electricity by means of a device intended to be placed in a body of water.
In particular, the plant is capable of receiving liquefied natural gas (often referred to by the acronym "LNG") and producing electrical energy from the liquefied natural gas once it has been regasified.
The natural gas is produced from a reservoir located below the body of water or on land and then liquefied and delivered to the plant.
Several methods for producing electricity from liquefied natural gas are known.
Conventionally, a terminal for receiving liquefied natural gas is installed at a receiving terminal. LNG carriers deliver liquefied natural gas that is stored in storage tanks and then regasified. The gas power plant then uses some of the generated gas to generate electricity that is distributed over an electrical power network.
It is also known to use a floating storage and regasification unit (referred to by the acronym "FSRU") that receives liquefied natural gas from an LNG carrier. The liquefied natural gas is then temporarily stored on the FSRU and then returned to gaseous form before being sent to an onshore gas power plant.
Alternatively, the gas produced by the FSRU is sent to a floating barge, which receives the gas and then produces electricity. This solution allows flexible and mobile power production compared to land-based power plants. This solution thus enables a certain area to be electrified quickly and with reduced investment.
However, FSRU is a new ship or a former LNG carrier converted into FSRU. The cost of FSRU accounts for a very large proportion of the cost of such power production projects. For example, the cost of a newly built FSRU is typically over 2 hundred million euros. For the use of previous LNG carriers this makes it possible to achieve a certain degree of savings, but the cost of converting it into FSRU is still about 1 million euros, as significant modifications to the LNG carrier are necessary.
It is also known to use fully integrated floating storage, regasification and power generation barges (referred to by the acronym "FSRP"). The fully integrated design makes it possible to combine the storage and regasification functions with the power generation functions on a single float, thereby providing operational flexibility and rapid deployment. However, the complexity and cost of the design and construction of such structures detracts from their competitiveness.
It is therefore an object of the present invention to provide a method for producing electricity with reduced design and installation costs, while maintaining the flexibility of storing liquefied natural gas and producing electricity on water.
To this end, the invention relates to a method of producing electricity by means of a device intended to be placed in a body of water, the device comprising:
-a floating storage unit comprising an inner volume having a main tank for storing liquefied natural gas;
-a floating regasification and power generation unit separate from the storage unit, the regasification and power generation unit comprising a regasification module and a power generation module;
-a unit for transporting liquefied natural gas between the storage unit and the regasification and power generation unit;
the production method at least comprises the following steps:
-transferring liquefied natural gas from the main tank of the storage unit to the regasification and power generation unit via the transfer unit;
-regasifying the liquefied natural gas to a gas in the gaseous state by means of the regasification module;
-transferring the gas from the regasification module to the power generation module;
-generating electricity from the gas by means of the electricity generation module.
The method for producing electric power according to the invention may comprise one or more of the following features considered alone or in any technically possible combination:
-the method further comprises the step of transferring the liquefied natural gas from the LNG carrier to the main tank of the storage unit;
the transport unit is advantageously at 10m 3 /h and 500m 3 A flow rate between/h directly supplying lng to the regasification module;
the regasification and power generation unit also comprises a buffer tank with a capacity smaller than the main tank, the delivery unit advantageously being at 500m 3 /h and 3000m 3 A flow rate between/h delivering the lng to the surge tank, the lng then being delivered from the surge tank to the regasification module;
-the storage unit and the regasification unit are moored to a common dock, which is connected to a dock on land;
-the storage unit and the regasification and power generation unit are arranged along the dock on either side of the dock;
the storage unit is moored to at least one floating buoy anchored
To the bottom of the body of water, the regasification and power generation unit moored along the storage unit;
-the storage unit is tethered by at least one anchoring line anchored to the bottom of the body of water, the
A regasification and power generation unit moored along the storage unit;
the transfer unit comprises a pipe arranged on the header for transferring the liquefied natural gas from the header
The storage unit is transported to the regasification and power generation unit;
the transport unit comprises a direct connection between the storage unit and the regasification and power production unit
A conduit for transporting the liquefied natural gas from the storage unit directly to the re-supply
A gasification and power generation unit;
-the pipe is an articulated rigid pipe and/or a cryogenic flexible pipe;
-the power generation module comprises a power generation device selected from:
the engine is a gas engine with a fuel gas,
a +gas-diesel or gas-fuel dual fuel engine,
a +open cycle gas turbine,
an + gas-diesel or gas-fuel open cycle dual fuel turbine,
a + combined cycle gas turbine and a steam turbine,
+combined cycle dual fuel gas-diesel or gas-fuel turbines, and steam turbines; the power generation module is a combined cycle turbine, the regasification and power generation unit comprising
A first heat exchanger arranged at the regasification module for heating the liquefied natural gas and at the outlet of the steam turbine of the combined cycle for condensing a vapor
Between the power generation modules of the steam;
the regasification and power generation unit comprises a second heat exchanger, the second heat exchanger being arranged
Is arranged in the regasification module for heating the liquefied natural gas and is used for cooling the engine
Or between the power generation modules of intake air in the gas turbine;
the power generation module is at least one combined cycle gas turbine and steam turbine, the power
The force-producing module includes a condenser that extracts water from the body of water to condense steam at the outlet of the steam turbine and at least one wet cooling tower that
Cooling the water at an outlet of the condenser before the water is discharged into the body of water; and-the regasification and power generation unit comprises means for measuring at the inlet of the regasification module
A system of circulating the liquefied natural gas and/or the gas circulating at the outlet of the regasification module.
The invention will be better understood upon reading the following description, given by way of example only, with reference to the accompanying drawings in which:
figure 1 is a top view of a device according to the invention,
figure 2 is a top view of a variant of the device of figure 1,
figure 3 is a top view of another variant of the device of figure 1,
figure 4 is a top view of another variant of the device of figure 1,
figure 5 is a schematic representation of the regasification and power generation unit of the plant of figure 1,
FIG. 6 is a partial schematic representation of a variant of the regasification and power generation unit of FIG. 5, and
fig. 7 is a partial schematic representation of another variant of the regasification and power generation unit of fig. 5.
Hereinafter, "liquefied natural gas" is understood to mean natural gas from which water, heavy compounds (e.g., c6+ compounds) and sulfur compounds have been partially extracted and then have been condensed into a liquid state. Liquefied natural gas consists mainly of methane, but in particular also of ethane, propane and butane. Methane becomes liquid at atmospheric pressure at a temperature of-161 ℃ and takes the form of a clear, transparent, odorless, non-corrosive and non-toxic liquid. In this form, the density of the liquefied natural gas is about six hundred times greater than the density of the gas at normal temperature and pressure.
"gas" is understood to mean natural gas in the gaseous state (in particular after regasification of liquefied natural gas).
In the following, the terms "upstream" and "downstream" are understood as the normal direction of circulation with respect to the flow in the pipe.
An apparatus 10 is shown in fig. 1-4.
The apparatus 10 is intended to be placed on a body of water 12.
The body of water 12 is, for example, a lake, sea or ocean. The depth of the body of water 12 directly below the device 10 is for example between 5m and 3000 m.
The apparatus 10 is configured to produce and supply electrical power to an electrical grid, an onshore infrastructure 14 (such as the plant shown in fig. 1), or alternatively an offshore infrastructure (such as an oil platform).
Here, the device 10 is supplied to the land infrastructure 14 via an electric line 15.
The apparatus 10 includes a storage unit 16, a regasification and power generation unit 18, and a delivery unit 20 between the storage unit 16 and the regasification and power generation unit 18.
As can be seen in fig. 1 and 2, the storage unit 16 and the regasification unit are moored to a common dock 22 that is connected to a dock 24 on land.
Dock 22 is a rigid building structure that projects into body of water 12 from dock 24 on land. Dock 24 on land is a road located at the edge of body of water 12 (e.g., at a port).
In the example of fig. 1, the storage unit 16 and the regasification and power generation unit 18 are disposed along the dock 22 on either side of the dock 22.
In one variation, in the example of fig. 2, the storage unit 16 and the regasification and power generation unit 18 are disposed on the same side of the dock 22 along the dock 22. The storage unit 16 and the regasification and power generation unit 18 are then arranged in tandem one after the other.
In another variation, as shown in fig. 3, the apparatus 10 is not moored to the dock 22. The storage unit 16 is moored to at least one float 26 (in this case three floats 26). Each floating buoy 26 is anchored to the bottom of the body of water 12. Regas and power generation unit 18 is moored along storage unit 16.
In another variant, as shown in fig. 4, the storage unit 16 is moored by means of at least one anchor line 27 (in this case three anchor lines 27) directly anchored to the bottom of the body of water 12. Regas and power generation unit 18 is moored along storage unit 16.
The storage unit 16 and the regasification and power generation unit 18 are units that float on the body of water 12. They have in particular a floating hull on which a plurality of pieces of interconnection equipment are arranged.
The storage unit 16 and the regasification and power generation unit 18 are separate from each other. In other words, the storage unit 16 and the regasification and power generation unit 18 each include their own floating hulls and are capable of moving on the body of water 12 independently of each other when they are not moored to each other.
The storage unit 16 comprises a floating hull 17 defining an interior volume which itself comprises at least one lng storage tank 28.
In the embodiment shown in the figures, three tanks 29a, 29b and 29c are in fluid connection with each other.
As can be seen in fig. 1, LNG can be supplied to the main tank 28 from LNG carriers 31 (also referred to as liquefied natural gas or LNG tanks) that are sailing on the body of water 12 and moored along the storage unit 16.
The main tank 28 can store 5000m 3 And 300,000m 3 In between the amounts of lng.
The regasification and power generation unit 18 includes a regasification module 30 and a power generation module 32.
The example apparatus 10 of fig. 1 does not have a lng storage tank, and lng is directly delivered from the main tank 28 of the storage unit 16 to the regasification module 30.
In the variant shown in fig. 2, the regasification and power generation unit 18 also comprises a buffer tank 33 capable of storing lng.
The storage capacity of the buffer tank 33 is smaller than that of the main tank 28.
In particular, the buffer tank 33 can store at 500m 3 And 30,000m 3 In between the amounts of lng.
The regasification module 30 is configured to convert liquefied natural gas to a gaseous state to obtain the gas again.
Regasification module 30 includes an evaporator configured to boil the liquefied natural gas by heat exchange with ambient air and/or with water from body of water 12 or by combustion of a portion of the liquefied natural gas, thereby enabling the heat required for its evaporation to be supplied.
The regasification module 30 is configured to transfer the gas produced thereby to the power generation module 32.
The floating regasification and power generation unit 18 advantageously also includes a system for measuring the lng circulating at the inlet of the regasification module 30 and/or the gas circulating at the outlet of the regasification module 30.
The power generation module 32 is configured to generate power from the supplied gas. In particular, the power generation module 32 is configured to generate power between 15mW and 1500 mW.
The power generation module 32 includes a power generation device selected from the group consisting of:
the gas engine is operated in a gas-fired mode,
a gas-diesel or gas-fuel dual fuel engine,
an open-cycle gas turbine,
gas-diesel or gas-fuel open cycle dual fuel turbine,
a combined cycle gas turbine and a steam turbine,
-a combined cycle dual fuel gas-diesel or gas-fuel turbine, and a steam turbine;
in particular, an example of a regasification and power generation unit 18 that includes a combined cycle is shown in FIG. 5.
The power generation module 32 includes: an air compressor 34 configured to compress intake air; a combustion chamber 38 supplied with compressed air and gas by the regasification module 30; and a supplied gas turbine 40 that allows the first alternator 41 to rotate to produce electric power. The production module 32 may also have a plurality of compressors 34, combustors 38, gas turbines 40, and alternators 41 connected to other components of the production module 32.
The power generation module 32 also includes a steam generation heat exchanger 42 disposed between the outlet of the gas turbine 34 and a closed cycle, such as water circulating therein. The steam generating heat exchanger 42 is configured to evaporate water before the water enters the steam turbine 44. The steam turbine 44 allows the second alternator 46 to rotate so as to also produce electricity.
The steam at the outlet is sent to a condenser 48 configured to condense the steam into liquid water. The condenser 48 is supplied with water taken from the body of water 12. The pump 49 is configured to circulate water in a closed cycle.
As can be seen in fig. 5, the regasification and power generation unit 18 then advantageously includes a first heat exchanger 50 that is arranged between the regasification module 30 for heating the lng and the power generation module 32 for condensing steam at the outlet of the combined cycle steam turbine.
Thus, the first exchanger 50 enables the overall efficiency of the apparatus 10 to be increased by using the regasification module 30 as a source of cold to facilitate condensing steam in a closed cycle, thereby reducing the amount of water from the body of water 12 required to condense all of the steam.
According to fig. 5, an exchanger 50 is inserted in series at the outlet of the condenser 48. However, other architectures may be advantageously used, particularly by using a bypass that supplies only some of the water circulating in the condenser 48 to the exchanger 50. This architecture has the advantage of being able to more easily adapt to different heat exchange needs, in particular during the start-up phase or part-load operation when only some of the gas turbines are operating.
FIG. 6 illustrates an open cycle of an open cycle gas turbine 44 or an open cycle of a combined cycle.
As can be seen in fig. 6, the regasification and power generation unit 18 advantageously includes a second heat exchanger 52 that is arranged between the regasification module 30 for heating the lng and the power generation module 32 for cooling the intake air in the gas turbine 40. Here, the second exchanger 52 is arranged upstream of the compressor 34.
In a variant not shown, when the electricity generating device is an engine, the second heat exchanger 52 is arranged between the regasification module 30 for heating the liquefied natural gas and the electricity generating module 32 for cooling the inlet air to the engine.
Advantageously, the second exchanger 52 comprises a secondary circuit in which the intermediate fluid circulates, so as to avoid the risk of gas leakage at the inlet of the gas turbine 40 or of the engine in case of failure of the second exchanger 52.
The second exchanger 52 enables cooling of the intake air supplied to the gas turbine 40 or the gas engine in order to increase their efficiency.
FIG. 7 only shows the closed cycle of the combined cycle when the power plant includes a combined cycle gas turbine 40 and a steam turbine 44.
As can be seen in fig. 7, the power generation module 32 advantageously includes at least one wet cooling tower 54 that cools the water at the outlet of the condenser 48 before the water is discharged into the body of water 12.
Cooling tower 54 is configured to cool the water cooled in the ambient air stream circulating in the tower by spraying the water exiting condenser 48 in the tower, and then collecting the water before discharging it into body of water 12.
The cooling tower 54 allows water to drain into the body of water 12 at substantially the same temperature as water taken from the body of water and thereby reduces the effect on the temperature of the body of water 12 and, thus, on aquatic populations in the body of water 12.
The transfer unit 20 is configured to transfer liquefied natural gas between the storage unit 16 and the regasification and power generation unit 18, in particular by means of at least one transfer pump arranged on the storage unit 16.
In the example of fig. 1, the conveying unit 20 is configured to be advantageously at 10m 3 /h and 500m 3 The flow rate between/h directly supplies lng to the regasification module 30.
In the variant of fig. 2, when the regasification and power generation unit 18 includes a buffer tank 33, the delivery unit 20 is configured to advantageously distribute lng at 500m 3 /h and 3000m 3 The flow rate between/h is fed to the buffer tank 33. This allows the use of standard transfer pumps and does not require the installation of a continuously operating low flow pump.
As can be seen in fig. 1, the transfer unit 20 comprises a pipeline arranged on the quay 22 for transferring lng from the storage unit 16 to the regasification and power generation unit 18.
Advantageously, the conduit is an articulated rigid tube.
Alternatively, the tubing is a cryogenic flexible tube.
During the transportation of lng, a large amount of ice may form around the transportation unit 20. Thus, a rigid articulated tube is preferred over a flexible tube, which tends to remain rigid in the presence of an ice layer.
Advantageously, each pipe is reworked for operational safety.
In the variant of fig. 2, the transport unit 20 comprises a pipe directly connecting the storage unit 16 and the regasification power generation unit 18. "directly" is understood to mean that the pipe is not located at the quay 22 or at another intermediate support between the two units 16, 18.
Advantageously, the delivery unit 20 is configured to deliver gas present in the regasification module 30 or in the buffer tank 33 back to the storage unit 16 to compensate for the liquid volume delivered from the main tank to the regasification module 30 or the buffer tank 33, respectively. The gas transfer is advantageously performed in parallel with the lng transfer by means of at least one separate dedicated pipeline.
A method of producing electricity by means of the device 10 will now be described.
Initially, the storage unit 16 and the regasification and power generation unit 18 float on the body of water 12 and are moored to a dock 22 as seen in fig. 1 and 2 and/or at least one floating buoy 26 as seen in fig. 3 and/or at least one anchor line 27 as seen in fig. 4.
LNG carrier 26 is onshore and then moored at storage unit 16.
The LNG carrier 26 then transfers the liquefied natural gas to a main tank 28 of the storage unit 16.
The storage unit 16 thus stores a large quantity of liquefied natural gas, in particular at 5000m 3 And 300,000m 3 In between the amounts of lng.
The method then includes the step of transferring the liquefied natural gas from the main tank 28 of the storage unit 16 to the regasification and power generation unit 18 via the transfer unit 20.
In the example of fig. 1, the delivery unit 20 advantageously delivers lng at 10m 3 /h and 500m 3 The flow rate between/h is directly supplied to the regasification module 30.
Thus, in this example, the delivery unit 20 continuously supplies lng to the regasification module 30 as long as electricity must be produced.
In the variant of fig. 2, the delivery unit 20 advantageously delivers lng at 500m 3 /h and 3000m 3 The flow rate between/h is fed to the buffer tank 33. In particular, the transfer unit 20 transfers the liquefied natural gas to the buffer tank 33 until the buffer tank 33 is full. When the capacity of the buffer tank 33 is again smaller than the threshold value, the transfer unit 20 transfers the liquefied natural gas to the buffer tank 33. Thus, the transfer unit 20 periodically transfers lng to ensure that a sufficient amount of lng is present in the buffer tank 33.
When electricity is required, lng is transferred from the surge tank 33 to the regasification module 30.
The method then includes the step of regasifying the liquefied natural gas to a gas in the gaseous state with the aid of a regasification module 30.
In particular, the liquefied natural gas is circulated in a vaporizer that allows for regasification, so as to obtain the gas again in the gaseous state.
The gas is then transported from the regasification module 30 to the power generation module 32.
The method then includes the step of producing electricity from the gas by means of the electricity production module 32.
In particular, the gas is used as fuel in a gas engine or gas turbine 40.
In the example of FIG. 5, gas is injected into combustion chamber 38 for supply to gas turbine 40. The rotation of the gas turbine 40 drives a first alternator 41, which then produces electricity.
When the power plant is a combined cycle as shown in fig. 5, a steam generating heat exchanger 42 arranged between the outlet of the gas turbine 34 and the closed cycle enables water to be evaporated before it enters a steam turbine 44. The steam turbine 44 drives a second alternator 46, which then also produces electricity.
The produced electricity is then sent out via the electric line 15 for supply to the electric power network, the onshore infrastructure 14 or alternatively the offshore infrastructure.
It can then be seen that the present invention has a number of advantages.
The present invention has the same flexibility to store lng and to produce electricity on water as the prior art solutions. Indeed, by the production method according to the invention, it is possible to easily move the device 10 over the body of water 12 and thereby rapidly supply the infrastructure or network requiring this power. Furthermore, the structural and environmental impact on the coast is limited.
In addition, the method according to the invention enables the production of electricity from natural gas in a much cheaper way than with the architecture of the prior art. For example, a saving of about 20% is possible over a fully integrated FSRP architecture or FSRU architecture with motorized floating barges.
In fact, in the present invention, existing and converted LNG carriers can be used to act as storage units 16, with few modifications and at a very competitive cost.
In contrast to FSRU architecture in combination with motorized floating barges, where the configuration or conversion of FSRU must be managed, the present invention makes it possible to manage with a single project, i.e. the configuration of regasification and power generation unit 18.
Furthermore, the absence of a substantial storage of liquefied natural gas on the regasification and power generation unit 18 makes it possible to avoid the use of ballasts and makes it possible to use hulls with shallow draft, similar to a simple flat top barge and thereby significantly reduce the construction costs of such units.
In addition, the absence of substantial storage of lng on the regasification unit also makes it possible to greatly facilitate the construction of the regasification and power generation unit 18, as the shipyard selected for construction does not need experience in storing lng. Thus, a large number of competing shipyards can be envisaged for the construction of several of these units 18.
Finally, the possibility of using heat integration between the regasification module 30 and the power generation module 32 to increase the overall efficiency of the device also contributes to overall competitiveness and to reducing the environmental impact of the device 10. This thermal optimization is not possible for FSRU architecture combined with motorized barges and requires much higher costs for fully integrated FSRP units.

Claims (17)

1. A method for producing electricity by means of a device (10) placed on a body of water (12), the device (10) comprising:
-a floating storage unit (16), the storage unit (16) comprising a hull (17) defining an interior volume comprising a main tank (28) for storing liquefied natural gas;
-a floating regasification and power generation unit (18) separate from the storage unit (16), the regasification and power generation unit (18) comprising a regasification module (30) and a power generation module (32);
-a unit (20) for transporting liquefied natural gas between the storage unit (16) and the regasification and power generation unit (18);
the production method at least comprises the following steps:
-transferring liquefied natural gas from the main tank (28) of the storage unit (16) to the regasification and power generation unit (18) via the transfer unit (20);
-regasifying the liquefied natural gas to a gas in the gaseous state by means of the regasification module (30);
-transferring the gas from the regasification module (30) to the power generation module (32);
-producing electricity from the gas by means of the electricity production module (32).
2. The power production method according to claim 1, further comprising the step of transporting liquefied natural gas from an LNG carrier (31) to the main tank (28) of the storage unit (16).
3. The power production method according to claim 1 or 2, wherein the transport unit (20) is advantageously arranged at 10m 3 /h and 500m 3 The flow rate between/h directly supplies lng to the regasification module (30).
4. The power production method according to claim 1 or 2, wherein the regasification and power production unit (18) further comprises a buffer tank (33) having a smaller capacity than the main tank (28),
the conveying unit (20) is advantageously arranged at a distance of 500m 3 /h and 3000m 3 A flow rate between/h delivering said lng to said buffer tank (33),
the lng is then transferred from the buffer tank (33) to the regasification module (30).
5. The power production method according to any of the preceding claims, wherein the storage unit (16) and the regasification unit (18) are moored to a common dock (22) that is connected to an above ground dock (24).
6. The power production method according to claim 5, wherein the storage unit (16) and the regasification and power production unit (18) are arranged along the quay (22) on either side of the quay (22).
7. The power production method according to claim 5, wherein the storage unit (16) and the regasification and power production unit (18) are arranged on the same side of the dock (22) along the dock (22).
8. The power production method according to any one of claims 1 to 4, wherein the storage unit (16) is moored to at least one floating buoy (26) anchored to the bottom of the body of water (12), the regasification and power production unit (18) being moored along the storage unit (16).
9. The power production method according to any one of claims 1 to 4, wherein the storage unit (16) is moored by at least one anchor line (27) anchored to the bottom of the body of water (12), the regasification and power production unit (18) being moored along the storage unit (16).
10. The power production method according to any one of claims 5 to 7, wherein the transport unit (20) comprises a pipeline arranged on the quay (22) for transporting the liquefied natural gas from the storage unit (16) to the regasification and power production unit (18).
11. The power production method according to any one of claims 1 to 8, wherein the transportation unit (20) comprises a pipeline directly connecting the storage unit (16) and the regasification and power production unit (18) for transporting the liquefied natural gas directly from the storage unit (16) to the regasification and power production unit (18).
12. The power production method according to claim 10 or 11, wherein the pipe is an articulated rigid pipe and/or a cryogenic flexible pipe.
13. The power production method according to any one of the preceding claims, wherein the power production module (32) comprises a power production device selected from:
the gas engine is operated in a gas-fired mode,
a gas-diesel or gas-fuel dual fuel engine,
-an open-cycle gas turbine (40),
gas-diesel or gas-fuel open cycle dual fuel turbine,
a combined cycle gas turbine (40) and a steam turbine (44),
-a combined cycle dual fuel gas-diesel or gas-fuel turbine, and a steam turbine (44).
14. The power production method according to claim 13, wherein the power production module (32) is a combined cycle turbine, the regasification and power production unit (18) comprising a first heat exchanger (50) arranged between the regasification module (30) for heating the liquefied natural gas and the power production module (32) for condensing steam at an outlet of the steam turbine (44) of the combined cycle.
15. The power production method according to claim 13 or 14, wherein the regasification and power production unit (32) comprises a second heat exchanger (52) arranged between the regasification module (30) for heating the liquefied natural gas and the power production module (32) for cooling intake air in the engine or gas turbine (44).
16. The power production method according to any one of claims 13 to 15, wherein the power production module (32) is at least one combined cycle gas turbine (40) and a steam turbine (44), the power production module (32) comprising a condenser (48) sampling water from the body of water (12) so as to condense steam at the outlet of the steam turbine (44), and at least one wet cooling tower (54) cooling the water at the outlet of the condenser (48) before the water is discharged into the body of water (12).
17. The power production method according to any one of the preceding claims, wherein the regasification and power production unit (18) comprises a system for measuring the liquefied natural gas circulating at the inlet of the regasification module (30) and/or the gas circulating at the outlet of the regasification module (30).
CN202280048772.5A 2021-06-03 2022-06-02 Method for producing electric power by means of a device intended to be placed in a body of water Pending CN117677791A (en)

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