WO2024018579A1 - Système de production d'énergie à turbine à gaz utilisant de la chaleur froide - Google Patents

Système de production d'énergie à turbine à gaz utilisant de la chaleur froide Download PDF

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WO2024018579A1
WO2024018579A1 PCT/JP2022/028307 JP2022028307W WO2024018579A1 WO 2024018579 A1 WO2024018579 A1 WO 2024018579A1 JP 2022028307 W JP2022028307 W JP 2022028307W WO 2024018579 A1 WO2024018579 A1 WO 2024018579A1
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gas
nitrogen
oxygen
liquid
power generation
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PCT/JP2022/028307
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English (en)
Japanese (ja)
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健次 渡邉
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株式会社Ｎａｙｕｔａテクノロジー
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Publication of WO2024018579A1 publication Critical patent/WO2024018579A1/fr

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    • 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
    • F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
    • F02C6/14—Gas-turbine plants having means for storing energy, e.g. for meeting peak loads

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  • the present invention relates to a gas turbine power generation system that utilizes the cold energy of liquid hydrogen.
  • Non-Patent Document 1 performs an exergy analysis of the Graz cycle using the characteristics of hydrogen-oxygen combustion.
  • the Graz cycle is a semi-closed combination of the Brayton cycle and the Rankine cycle, using only water vapor as the working fluid through hydrogen-oxygen combustion.
  • the combustion exergy loss of a state-of-the-art 1600°C class gas turbine is 26.8%, and the exergy efficiency at the transmission end of a gas turbine combined cycle (GTCC) is 56.5%.
  • GTCC gas turbine combined cycle
  • the exergy loss of the combustor with a turbine inlet temperature of 1450°C and combustion pressure of 13.8 MPa is 16.9%, and the exergy efficiency at the transmission end is 61.4%, which is higher than that of a 1600°C class gas turbine. It can be greatly improved.
  • liquefied hydrogen has exergy of 116.8 MJ/kg as a calorific value and exergy as cold energy of 13.3 MJ/kg. If this cold energy is used for cryogenic separation of air, the exergy efficiency at the transmission end of the Graz cycle can be further improved by 2.1%.
  • Non-Patent Document 2 states that the oxygen-hydrogen combustion power generation cycle has a thermal efficiency that is 2-11% higher than that of the air-hydrogen combustion GTCC. However, when oxygen production power is taken into account, the transmission net efficiency decreases by 4-6% compared to the generation net efficiency. Therefore, the transmission net efficiency is likely to be on the same level as air-hydrogen combustion GTCC. Furthermore, Non-Patent Document 2 assumes oxygen-hydrogen stoichiometric complete combustion, but states that complete combustion is not actually possible at an equivalence ratio of 1.
  • FIG. 1 is an overall configuration diagram of a hydrogen-oxygen combustion turbine power generation system disclosed in Non-Patent Document 3.
  • A is a cryogenic separation oxygen production plant
  • B is a hydrogen-oxygen combustion turbine.
  • Cryogenic separation oxygen production plant A uses two distillation columns (called double columns) with different pressures to lower air to a low temperature, concentrating easily evaporable nitrogen into a gas and hard-to-evaporate oxygen into a liquid. Separates oxygen and nitrogen using the vapor-liquid equilibrium of air.
  • the separated oxygen gas is supplied to the hydrogen-oxygen combustor (hereinafter referred to as combustor) of the hydrogen-oxygen combustion turbine B.
  • combustor hydrogen-oxygen combustor
  • Liquid hydrogen is carried in by a hydrogen transport ship and stored in a liquefied hydrogen tank, and hydrogen gas vaporized in a vaporizer is supplied to a combustor.
  • the combustor of the hydrogen-oxygen combustion turbine B is supplied with hydrogen gas, oxygen gas, and water.
  • hydrogen is combusted to generate high-temperature steam, which drives a turbine and generates electricity.
  • a portion of the water vapor is extracted from the turbine, compressed by a compressor, and recycled to the combustor.
  • the remaining water vapor leaving the turbine is cooled in a condenser and becomes water (condensed water), part of which is supplied to the combustor by a condensate pump and a feed water pump, and the remainder is discharged to the outside.
  • the hydrogen-oxygen combustion turbine power generation system described above has the following problems.
  • (1) Energy loss due to oxygen production plants is large. Hydrogen-oxygen combustion turbines require 1 mole of oxygen gas for every 2 moles of hydrogen gas for complete combustion. Therefore, in terms of weight ratio, hydrogen:oxygen 1:8 for complete combustion, and a larger amount of oxygen gas is required for stable combustion.
  • even if air is liquefied and separated by the cold heat of 1 kg of liquefied hydrogen only about 2 kg of oxygen gas is obtained. For this reason, oxygen production plants require power sources other than cold energy for the most part, resulting in large energy losses. Furthermore, large amounts of nitrogen gas (by-product nitrogen) generated in oxygen production plants do not contribute to power generation.
  • a first object of the present invention is to provide a cold energy gas turbine power generation system that can completely burn hydrogen and increase power generation efficiency by using the cold energy of liquid hydrogen.
  • a second object of the present invention is to provide a gas turbine power generation system using cold heat that can be installed inland where a large amount of cooling water is not available.
  • an air liquefaction separation device that liquefies air using the cold heat of liquid hydrogen to produce a required amount of hydrogen gas, as well as liquid oxygen and liquid nitrogen; a gas turbine generator that generates electricity by oxygen-enriching combustion of the hydrogen gas; a reheating combustor that burns the hydrogen gas with residual oxygen and heats the exhaust gas of the gas turbine generator; a nitrogen cycle that includes a nitrogen gas cooler that cools low-pressure nitrogen gas by exchanging heat with the liquid oxygen and the liquid nitrogen, and that circulates the nitrogen gas and recovers power generation; Pressurizing the liquid oxygen produced in the air liquefaction separation device in a liquid state, heating the pressurized liquid oxygen in the nitrogen gas cooler, and supplying pressurized oxygen to the gas turbine generator as pressurized oxygen gas.
  • a cold energy gas turbine power generation system having a pressurized nitrogen supply line.
  • the air is liquefied by the cold heat of liquid hydrogen in the air liquefaction separation device to produce the necessary amount of hydrogen gas, so that energy loss in the air liquefaction separation device can be minimized.
  • the liquid oxygen produced in the air liquefaction separator along with the hydrogen gas is less than the amount of oxygen required by the gas turbine generator.
  • this liquid oxygen is pressurized in a liquid state by a pressurized oxygen supply line, heated by a nitrogen gas cooler, and then supplied to the gas turbine generator as pressurized oxygen gas.
  • the compression power it is possible to reduce the compression power by an amount equivalent to about five times the amount of pressurized oxygen gas out of the amount of air compressed by the gas turbine generator.
  • the hydrogen gas produced by the air liquefaction separation device is subjected to oxygen-enriched combustion using compressed air and pressurized oxygen gas, so that the hydrogen gas can be stably and completely combusted with a sufficient amount of oxygen.
  • the liquid nitrogen produced by the air liquefaction separation device is pressurized in a liquid state by a pressurized nitrogen supply line, heated by a nitrogen gas cooler, and additionally supplied to the high-pressure nitrogen gas of the nitrogen cycle as pressurized nitrogen gas.
  • the compression power in the nitrogen cycle can be reduced, and the amount of power generated by the nitrogen cycle can be increased.
  • the reheating combustor burns the hydrogen gas produced by the air liquefaction separation device using residual oxygen to heat the exhaust gas temperature, so this high-temperature exhaust gas can sufficiently heat the high-pressure nitrogen gas in the nitrogen cycle, and the nitrogen Cycle efficiency can be increased.
  • liquid oxygen produced together with the necessary amount of hydrogen gas in the air liquefaction separation device contributes to reducing the power of the gas turbine generator and oxygen-enriched combustion
  • liquid nitrogen contributes to increasing the amount of power generated by the nitrogen cycle.
  • the cold heat of liquid hydrogen can be used to produce oxygen for combustion and increase power generation efficiency.
  • FIG. 2 is an overall configuration diagram of a hydrogen-oxygen combustion turbine power generation system disclosed in Non-Patent Document 3.
  • FIG. 1 is a diagram of a first embodiment of a gas turbine power generation system using cold energy according to the present invention.
  • FIG. 1 is an overall configuration diagram of an air liquefaction separation device.
  • FIG. 1 is an overall configuration diagram of a nitrogen cycle. It is a 2nd embodiment figure of the cold heat utilization gas turbine power generation system by this invention.
  • FIG. 1 is an overall configuration diagram of a carbon dioxide gas cycle.
  • the main specifications of the hydrogen-oxygen combustion turbine power generation system under development are as follows.
  • Hydrogen gas is supplied in the form of liquefied hydrogen, and the liquefied hydrogen is compressed and then vaporized for use.
  • Oxygen gas is separated from air using three types of air separation methods: cryogenic air separation method (CAS), pressure swing adsorption method (PSA), and high temperature oxygen separation membrane (OTM). use.
  • CAS cryogenic air separation method
  • PSA pressure swing adsorption method
  • OTM high temperature oxygen separation membrane
  • hydrogen gas will be referred to as H2, liquefied hydrogen as LH2, oxygen gas as O2, liquid oxygen as LO2, nitrogen gas as N2, and liquid nitrogen as LN2.
  • FIG. 2 is a diagram of a first embodiment of a gas turbine power generation system 100 utilizing cold energy according to the present invention.
  • a cold energy gas turbine power generation system 100 includes an air liquefaction separation device 10, a gas turbine generator 20, and a bottoming cycle 30.
  • the air liquefaction separation device 10 liquefies air Air using the cold heat of liquid hydrogen LH2 to produce liquid oxygen LO2 and liquid nitrogen LN2 along with the required amount of hydrogen gas H2.
  • the gas turbine generator 20 generates electricity by oxygen-enriching combustion of hydrogen gas H2.
  • gas turbine generator 20 includes a gas turbine compressor 22, a gas turbine combustor 24, and a gas turbine 26.
  • the gas turbine compressor 22 compresses air Air. That is, air as an oxidizer is compressed in the same manner as the existing GTCC (normal pressure air is compressed by the gas turbine compressor 22 at the pressure ratio of the existing GTCC) and sent to the gas turbine combustor 24. In this example, a pressure ratio of 23 for 1600°C class GTCCII is adopted.
  • the gas turbine combustor 24 performs oxygen-enriched combustion of the hydrogen gas H2 vaporized in the air liquefaction separation device 10 using compressed air and pressurized oxygen gas (pressurized oxygen gas O2). That is, in the gas turbine combustor 24, pressurized oxygen gas that has been liquefied and separated from the air is mixed with compressed air and used as oxygen-enriched air. The amount of compressed air will be adjusted so that the residual oxygen concentration after combustion is 16%, which is the same as in the existing LNG combined cycle.
  • the gas turbine 26 obtains power generation from the combustion gas G1 and drives a generator (not shown) to generate electricity.
  • the fuel of the gas turbine generator 20 is hydrogen gas H2
  • the oxidizing agent is air and oxygen gas O2
  • combustion is performed using the same method as the existing GTCC (LNG combined cycle), with the residual oxygen concentration in the exhaust gas being 16% (dry). Burn at the fuel ratio.
  • the bottoming cycle 30 recovers power generated from the exhaust gas G2 of the gas turbine 26.
  • the bottoming cycle 30 includes a reheating combustor 32, a nitrogen gas turbine cycle (hereinafter referred to as nitrogen cycle 40), and a steam turbine cycle (hereinafter referred to as steam cycle 60). That is, in this example, a combined cycle with a two-stage bottoming cycle is adopted, in which a nitrogen cycle 40 using the combustion gas of the reheating combustor 32 as a heat source is added between the gas turbine generator 20 and the steam cycle 60.
  • the reheating combustor 32 burns the hydrogen gas H2 with residual oxygen in the exhaust gas of the gas turbine 26, and heats the exhaust gas G2 of the gas turbine 26.
  • the heating temperature at the entrance of the bottoming cycle 30 is preferably 650 to 700°C.
  • the amount of hydrogen to be reheated is preferably a small amount (approximately 4% of the amount of hydrogen fuel in the gas turbine generator 20) corresponding to the amount of heating of nitrogen gas N2 in the nitrogen cycle 40.
  • the nitrogen cycle 40 circulates nitrogen gas N2 and recovers power generation.
  • the nitrogen cycle 40 is located immediately downstream of the reheating combustor 32 and includes a nitrogen gas compressor 42, a nitrogen gas heater 44, a nitrogen gas turbine 46, and a nitrogen gas cooler 48.
  • the nitrogen gas compressor 42 compresses low pressure nitrogen gas (low pressure nitrogen gas N2).
  • the nitrogen gas heater 44 heats high-pressure nitrogen gas (high-pressure nitrogen gas N2) with high-temperature exhaust gas (high-temperature exhaust gas G2) from the reheating combustor 32.
  • the nitrogen gas turbine 46 drives a generator (not shown) and recovers power generated from the heated high-pressure nitrogen gas.
  • the nitrogen gas cooler 48 cools the low-pressure nitrogen gas (intake air cooling) by exchanging heat with liquid oxygen LO2 and liquid nitrogen LN2 supplied from the air liquefaction separation device 10. That is, the nitrogen gas cooler 48 is a heat exchanger that heats the liquid oxygen LO2 and the liquid nitrogen LN2 and cools the low-pressure nitrogen gas.
  • the cold energy gas turbine power generation system 100 further includes a pressurized oxygen supply line 52 and a pressurized nitrogen supply line 54.
  • the pressurized oxygen supply line 52 has a liquid oxygen pump 52a that pressurizes the liquid oxygen LO2 produced in the air liquefaction separation device 10 in a liquid state, and heats the pressurized liquid oxygen LO2 with the nitrogen gas cooler 48 and pressurizes it. It is supplied to the gas turbine combustor 24 as pressurized oxygen gas.
  • the pressurizing pressure by the liquid oxygen pump 52a is set to be higher than the internal pressure of the gas turbine combustor 24. Since the oxygen obtained by the air liquefaction separation device 10 is liquid oxygen LO2, by compressing it in a liquefied state, the pressurizing power up to the combustor inlet pressure is negligibly small.
  • the pressurized nitrogen supply line 54 has a liquid nitrogen pump 54a that pressurizes the liquid nitrogen LN2 produced by the air liquefaction separation device 10 in a liquid state, and heats the pressurized liquid nitrogen LN2 with the nitrogen gas cooler 48 and pressurizes it. It is supplied to the outlet side of the nitrogen gas compressor 42 as pressurized nitrogen gas.
  • the pressurizing pressure by the liquid nitrogen pump 54a is set to be higher than the outlet pressure of the nitrogen gas compressor 42.
  • Steam cycle 60 includes a pressure pump 62, a steam heater 64, a steam turbine 66, and a condenser 68.
  • the pressurizing pump 62 pressurizes the condensed water W1.
  • the steam heater 64 heats the pressurized water W2 with the high-temperature exhaust gas from the nitrogen gas heater 44 to generate high-pressure, high-temperature steam (high-pressure, high-temperature steam S).
  • the steam turbine 66 recovers power generation from the high-pressure, high-temperature steam S.
  • the condenser 68 cools the low-pressure steam S to obtain condensed water W1.
  • nitrogen gas heater 44 and steam heater 64 described above are installed in the exhaust path of the reheating combustor 32, and function as a heat recovery heat exchanger (HRHEX) as a whole.
  • HRHEX heat recovery heat exchanger
  • FIG. 3 is an overall configuration diagram of the air liquefaction separation device 10.
  • the air is liquefied and separated by pretreatment using the thermal regeneration method (TSA) and heat exchange between LH2 and air.
  • TSA thermal regeneration method
  • An advantage of this method is that the power consumption is as low as about 1/2 of the conventional cryogenic air separation method.
  • the air liquefaction separation device 10 includes an air compressor 11, a nitrogen gas cooler 12, a helium gas cooler 14, an expansion valve 15, a gas-liquid separator 16, and a gas compressor 17.
  • the air compressor 11 compresses supply air (air) to a predetermined pressure (for example, 600 kPa).
  • the nitrogen gas cooler 12 includes a cold heat exchanger 12a and a N2 circulator 12b, and indirectly cools the air by circulating nitrogen gas N2 between the liquid hydrogen LH2 and the air.
  • the helium gas cooler 14 includes a liquefaction heat exchanger 14a and a He circulator 14b, and indirectly cools the air by circulating helium gas He between the liquid hydrogen LH2 and the air. The air is cooled to -176° C. by the nitrogen gas cooler 12 and the helium gas cooler 14, for example.
  • the expansion valve 15 adiabatically expands the cooled air and further cools it to an extremely low temperature (for example, -194° C.).
  • the gas-liquid separator 16 uses, for example, a double column to separate liquid nitrogen LN2 and liquid oxygen LO2.
  • the gas compressor 17 compresses the remaining gas and mixes it into the air compressed by the air compressor 11.
  • hydrogen gas H2 is supplied in the form of liquid hydrogen LH2.
  • the liquid hydrogen LH2 is compressed in advance to 5.7 MPa (same as the existing GTCC), and then air is liquefied and separated using the cold heat of vaporization, and then sent to the combustion chamber of the gas turbine combustor 24.
  • Table 1 shows the material balance in the air liquefaction separation device 10. As shown in this table, according to the trial calculation results, 3.9 kg/s of liquid nitrogen LN2 and 1.2 kg/s of liquid oxygen LO2 can be liquefied and separated using the cold energy of 1 kg/s of liquid hydrogen LH2.
  • Table 2 shows the required power of the air liquefaction separation device 10 when using the cold energy of the liquid hydrogen LH2 at 1 kg/s. From this table, it can be seen that the power of the air compressor 11 that compresses the supply air (air) to a predetermined pressure (for example, 645 kPa) accounts for 95% or more. Additionally, it can be seen that the energy loss is significantly smaller than in conventional air separation devices that liquefy through adiabatic compression and expansion.
  • FIG. 4 is an overall configuration diagram of the nitrogen cycle 40.
  • the nitrogen cycle 40 has three stages of expansion, and a supercritical nitrogen turbine is used in the high pressure stage.
  • the nitrogen gas heater 44 includes a first gas heater 44a, a second gas heater 44b, and a third gas heater, which are located in order from the upstream side with respect to the high-temperature exhaust gas G2 exiting the reheating combustor 32. It has a container 44c.
  • the nitrogen gas turbine 46 includes a first expander 46a, a second expander 46b, and a third expander 46c, which are located in this order from the upstream side with respect to the high-temperature exhaust gas G2.
  • Nitrogen gas turbine 46 may be a supercritical nitrogen turbine.
  • the nitrogen cycle 40 includes a nitrogen gas heat exchanger 49 at the outlet of the first expander 46a, and further includes a nitrogen gas cooler 48 at the subsequent stage (downstream side).
  • the nitrogen gas heat exchanger 49 preheats the inlet gas of the third gas heater 44c using the outlet gas of the first expander 46a and recovers the heat.
  • the nitrogen gas cooler 48 cools the compressor inlet gas in order to reduce the compression power of the nitrogen gas compressor 42.
  • the nitrogen cycle 40 includes a replenishment port 43 for replenishing pressurized nitrogen gas (pressurized nitrogen gas N2) and an extraction port for extracting excess low-pressure nitrogen gas (low-pressure nitrogen gas N2) to the outside. 45.
  • the refill port 43 is provided between the outlet of the nitrogen gas compressor 42 and the inlet of the nitrogen gas heater 44 (in this example, the inlet of the nitrogen gas heat exchanger 49).
  • the extraction port 45 is provided between the outlet of the nitrogen gas turbine 46 (in this example, the outlet of the nitrogen gas heat exchanger 49) and the inlet of the nitrogen gas cooler 48.
  • the low temperature (for example, -12°C) nitrogen gas that has joined at the replenishment port 43 and the intermediate temperature (for example, 10°C) nitrogen gas before being discharged from the extraction port 45 are used. Heat exchanges with nitrogen gas.
  • the nitrogen gas cooler 48 of the nitrogen cycle 40 precools the refluxing nitrogen gas N2 using the cold heat of vaporization of the liquid nitrogen LN2 and liquid oxygen LO2 that have been air-separated by the air liquefaction separation device 10.
  • the nitrogen cycle 40 is a regenerative semi-closed gas turbine cycle in which vaporized pressurized nitrogen gas flows into the N2 circulation system of the nitrogen cycle 40 from a replenishment port 43, and the same amount of refluxed N2 is discharged from an extraction port 45. be.
  • Table 3 shows the main shaft power and power generation output of the nitrogen cycle 40 when the reheating combustor 32 burns hydrogen gas H2 at 0.22 kg/s. From this table, it can be seen that in the nitrogen cycle 40, the power generation output obtained by multiplying the difference between the expander shaft power and the compressor shaft power by the generator efficiency and the mechanical efficiency is large. That is, expander shaft power/compressor shaft power is approximately 5.7, which is larger than that of a general rotary generator (for example, 2.0 or less in a gas turbine).
  • the liquid nitrogen LN2 is pressurized in a liquid state, and the pressurized liquid nitrogen LN2 is heated in the nitrogen gas cooler 48 and is additionally supplied as pressurized nitrogen gas to the high pressure nitrogen gas of the nitrogen cycle 40. As will be described later, high thermal efficiency can be obtained.
  • Table 4 shows calculation conditions and trial calculation results for the cold energy gas turbine power generation system 100 of the first embodiment (WET type).
  • the efficiency of each device when calculating power generation performance is: compressor efficiency: 89.5%, gas turbine (GT) efficiency: 91%, steam turbine (ST) efficiency: 90%, mechanical efficiency: 94%, Machine efficiency: 98%, LH2/LO2/LN2 compression pump efficiency: 70%.
  • GT gas turbine
  • ST steam turbine
  • mechanical efficiency 94%
  • Machine efficiency 98%
  • LH2/LO2/LN2 compression pump efficiency 70%.
  • mechanical efficiency it is necessary to consider losses in the steam condenser cooling water pump, water quality control equipment, lubrication and cooling of various rotating machines, measurement control management equipment, etc. in the actual machine. 94% of them were adopted.
  • FIG. 5 is a diagram of a second embodiment of a gas turbine power generation system 100 utilizing cold energy according to the present invention.
  • the system of the second embodiment will be referred to as a DRY type.
  • the bottoming cycle 30 has a carbon dioxide cycle 70 instead of the steam cycle 60 on the downstream side of the reheating combustor 32 and the nitrogen cycle 40 described above.
  • the carbon dioxide cycle 70 circulates carbon dioxide gas and recovers power generation.
  • the carbon dioxide cycle 70 includes a carbon dioxide compressor 72, a carbon dioxide heater 74, a carbon dioxide expander 76, and a carbon dioxide cooler 78.
  • the carbon dioxide compressor 72 compresses carbon dioxide.
  • the carbon dioxide gas heater 74 heats pressurized carbon dioxide gas with the high temperature exhaust gas from the nitrogen gas heater 44 to generate high pressure and high temperature carbon dioxide gas.
  • the carbon dioxide expander 76 drives a generator (not shown) and recovers power generated from the high-pressure, high-temperature carbon dioxide gas.
  • the carbon dioxide cooler 78 cools the carbon dioxide gas at the inlet of the carbon dioxide compressor 72.
  • the cooling tower 73 which does not require a large amount of cooling water.
  • FIG. 6 is an overall configuration diagram of the carbon dioxide cycle 70.
  • the carbon dioxide gas cycle 70 has three stages of expansion, and a supercritical carbon dioxide gas turbine is used in the high pressure stage.
  • the carbon dioxide gas heater 74 includes a first gas heater 74a, a second gas heater 74b, and a third gas heater 74a, which are located in order from the upstream side with respect to the high-temperature exhaust gas G2 that has exited the nitrogen gas heater 44. It has a container 74c.
  • the carbon dioxide expander 76 includes a first expander 76a, a second expander 76b, and a third expander 76c, which are located in order from the upstream side with respect to the high-temperature exhaust gas G2.
  • the carbon dioxide expander 76 is preferably a supercritical carbon dioxide gas turbine.
  • the carbon dioxide compressor 72 includes a first gas compressor 72a, a second gas compressor 72b, and a third gas compressor 72c located in order from the low pressure side of carbon dioxide gas.
  • the carbon dioxide cooler 78 includes a first cooler 78a, a second cooler 78b, and a third cooler 78c, which are located in order from the low pressure side of carbon dioxide. That is, a carbon dioxide gas cooler 78 using a cooling tower 73 is provided upstream of the first gas compressor 72a, the second gas compressor 72b, and the third gas compressor 72c, respectively.
  • the carbon dioxide cycle 70 includes a carbon dioxide heat exchanger 79 that exchanges heat between the carbon dioxide gas expanded in the first expander 76a and the carbon dioxide gas at the outlet of the third gas compressor 72c.
  • the other configurations are the same as those in the first embodiment.
  • Table 5 shows the main shaft power and power generation output of the carbon dioxide cycle 70 when the temperature of the exhaust gas discharged from the nitrogen cycle 40 provided upstream of the carbon dioxide cycle 70 is 603° C. and the amount of exhaust gas is 742 kg/s. . From this table, it can be seen that in the carbon dioxide cycle 70, the power generation output obtained by multiplying the difference between the expander shaft power and the compressor shaft power by the generator efficiency and mechanical efficiency is large. That is, expander shaft power/compressor shaft power ⁇ 2.5, which is larger than a general rotary generator (for example, 2.0 or less in a gas turbine).
  • Table 6 shows calculation conditions and trial calculation results for the cold energy gas turbine power generation system 100 of the second embodiment (DRY type). From this table, it can be seen that the total power generation output when using liquid hydrogen LH2 of about 6.2 kg/s is about 487 MW, and high power generation efficiency can be obtained.
  • the cold heat utilization gas turbine power generation system 100 of the first and second embodiments described above has the following advantages over the hydrogen-oxygen combustion turbine power generation system.
  • the hydrogen-oxygen combustion turbine power generation system is a combined cycle of a Brayton cycle and a Rankine cycle, and no other bottoming cycle can be applied upstream of the Rankine cycle.
  • the bottoming cycle that utilizes the exhaust gas of the gas turbine can be freely set, and in particular, the above-mentioned nitrogen cycle 40 can achieve a power generation efficiency of 97% or more.
  • the air is liquefied by the cold heat of the liquid hydrogen LH2 in the air liquefaction separation device 10 to produce the necessary amount of hydrogen gas H2, so that the energy loss of the air liquefaction separation device 10 is reduced. can be kept to a minimum.
  • the liquid oxygen LO2 produced together with the hydrogen gas H2 in the air liquefaction separation device 10 is smaller than the amount of oxygen required by the gas turbine generator 20.
  • this liquid oxygen LO2 is pressurized in a liquid state by the pressurized oxygen supply line 52, heated by the nitrogen gas cooler 48, and supplied to the gas turbine generator 20 as pressurized oxygen gas.
  • the compression power of the amount of air compressed by the gas turbine generator 20 can be reduced by an amount equivalent to about five times the amount of pressurized oxygen gas.
  • the hydrogen gas H2 produced by the air liquefaction separation device 10 is oxygen-enriched and combusted using compressed air and pressurized oxygen gas, so that the hydrogen gas H2 can be stably combusted with a sufficient amount of oxygen. .
  • liquid nitrogen LN2 produced by the air liquefaction separation device 10 is pressurized in a liquid state by the pressurized nitrogen supply line 54, heated by the nitrogen gas cooler 48, and converted into pressurized nitrogen gas to be used as high-pressure nitrogen gas in the nitrogen cycle 40. Additional supply will be provided. Thereby, the compression power in the nitrogen cycle 40 can be reduced, and the amount of power generated by the nitrogen cycle 40 can be increased.
  • the reheating combustor 32 burns the hydrogen gas H2 produced by the air liquefaction separation device 10 using residual oxygen to heat the exhaust gas temperature, the high-pressure nitrogen gas in the nitrogen cycle 40 can be sufficiently heated with this high-temperature exhaust gas. This makes it possible to improve the efficiency of the nitrogen cycle 40.
  • liquid oxygen LO2 produced together with the necessary amount of hydrogen gas H2 in the air liquefaction separation device 10 contributes to power reduction and oxygen-enriched combustion of the gas turbine generator 20, and the liquid nitrogen LN2 contributes to the amount of power generated by the nitrogen cycle 40. Contribute to increase.
  • power generation efficiency is estimated to be 70.2% (LHV) under the same turbine inlet temperature/pressure conditions as a 1600°C class LNG-fired GTCC, and a hydrogen-oxygen combustion turbine
  • the power generation efficiency is 5.5 to 8 points higher than the approximately 62% to 65% of power generation systems.
  • the cold heat utilization gas turbine power generation system 100 of the second embodiment does not use a steam turbine, and therefore has the following advantages.
  • the nitrogen cycle 40 and carbon dioxide cycle 70 of the first embodiment operate at high pressure and can therefore be made smaller.
  • the second embodiment can also be said to be a compact and highly efficient power generation system with a high degree of freedom in installing a power plant.
  • Air Air, G1 Combustion gas, G2 Exhaust gas, He Helium gas, H2 Hydrogen gas, LH2 Liquid hydrogen, LO2 Liquid oxygen, LN2 Liquid nitrogen, N2 Nitrogen gas, O2 Oxygen gas, S Water vapor, W1 Condensed water, W2 Pressurized water, 10 Air Liquefaction separation device, 11 air compressor, 12 nitrogen gas cooler, 12a cold heat exchanger, 12b N2 circulator, 14 helium gas cooler, 14a liquefaction heat exchanger, 14b He circulator, 15 expansion valve, 16 gas-liquid separator, 17 gas compressor, 20 gas turbine generator, 22 gas turbine compressor, 24 gas turbine combustor, 26 gas turbine, 30 bottoming cycle, 32 reheating combustor, 40 nitrogen cycle, 42 nitrogen gas compressor, 44 nitrogen gas heater, 44a first gas heater, 44b second gas heater, 44c third gas heater, 46 nitrogen gas turbine, 46a first expander, 46b second expander, 46c third expander, 48 Nitrogen gas cooler, 52 Pressur

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  • Separation By Low-Temperature Treatments (AREA)

Abstract

La présente invention concerne un système de production d'énergie à turbine à gaz utilisant de la chaleur froide 100, lequel système comporte : un dispositif de liquéfaction et de séparation de l'air 10, un groupe électrogène à turbine à gaz 20, un cycle de limitation absolue 30, une conduite d'alimentation en oxygène sous pression 52 et une conduite d'alimentation en azote sous pression 54. Le dispositif de liquéfaction et de séparation de l'air 10 liquéfie l'air, Air, par la chaleur froide de l'hydrogène liquide, LH2, pour fabriquer, en plus d'une quantité requise d'hydrogène gazeux, H2, de l'oxygène liquide, LO2, et de l'azote liquide, LN2. Le groupe électrogène à turbine à gaz 20 effectue une combustion enrichie en oxygène de l'hydrogène gazeux, H2, pour produire de l'énergie. Le cycle de limitation absolue 30 a un dispositif de post-combustion 32 et un cycle d'azote 40. La conduite d'alimentation en oxygène sous pression 52 met sous pression l'oxygène liquide, LO2, dans un état liquide, et fournit l'oxygène liquide, LO2, sous pression au dispositif de combustion de turbine à gaz 24 sous forme d'oxygène gazeux sous pression après avoir chauffé celui-ci à l'aide d'un refroidisseur d'azote gazeux 48. La conduite d'alimentation en azote sous pression 54 met sous pression l'azote liquide, LN2, dans un état liquide, et fournit l'azote liquide, LN2, sous pression à un côté de sortie d'un compresseur d'azote gazeux 42 sous forme d'azote gazeux sous pression après avoir chauffé celui-ci à l'aide du refroidisseur d'azote gazeux 48.
PCT/JP2022/028307 2022-07-21 2022-07-21 Système de production d'énergie à turbine à gaz utilisant de la chaleur froide WO2024018579A1 (fr)

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Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20220059400A (ko) * 2020-11-02 2022-05-10 양기와 수소-순산소연소 가스터빈 운전방법 및 배기열 회수장치
WO2022138615A1 (fr) * 2020-12-21 2022-06-30 日揮グローバル株式会社 Système complexe de traitement de gaz naturel

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20220059400A (ko) * 2020-11-02 2022-05-10 양기와 수소-순산소연소 가스터빈 운전방법 및 배기열 회수장치
WO2022138615A1 (fr) * 2020-12-21 2022-06-30 日揮グローバル株式会社 Système complexe de traitement de gaz naturel

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