Compressed air energy storage system and method for hydrogen afterburning

Abstract

The invention discloses a hydrogen afterburning compressed air energy storage system and method, and belongs to the field of energy storage, the hydrogen afterburning compressed air energy storage system comprises a compression module, an expansion power generation module, a heat storage module, a heat release module, a performance heating module, a steam-water thermodynamic cycle module and a cooling module, the expansion power generation module is used for releasing compressed air to enter a turbine to do work through expansion, the heat storage module is used for absorbing and storing heat generated in the air compression process, the heat release module is used for releasing the stored heat to the air and hydrogen, and the performance heater module is used for heating the hydrogen. And the steam-water thermodynamic cycle module is used for absorbing flue gas heat to further expand to do work. Compared with a non-afterburning system, the compressed air energy storage system and the compressed air energy storage method for hydrogen afterburning have the advantages that the flow of compressed air is greatly reduced, the parameters of a gas storage are reduced, the circulating efficiency of long-time energy storage is improved, and the system is more flexible and adapts to the requirements of a novel power system.

Description

Technical Field

[0001] The present invention belongs to the field of energy storage, and in particular relates to a hydrogen supplementary combustion compressed air energy storage system and method. Background Art

[0002] At present, energy storage technology is developing vigorously, especially non-supplementary combustion compressed air energy storage systems are constantly developing towards large capacity and high parameters. Due to geographical restrictions, the development of large-scale non-supplementary combustion compressed air energy storage technology has also encountered bottlenecks, and long-term energy storage has led to reduced efficiency. Conventional compressed air energy storage systems that use supplementary combustion of natural gas use a mixture of high-pressure air and natural gas to produce high-temperature and high-pressure flue gas that expands in a gas turbine to generate external power. This process requires the use of natural gas supplementary combustion, and therefore faces the pressure of carbon emissions. At the same time, the dependence on natural gas limits the application of the system.

[0003] Existing patents include energy storage systems that combine compressed air energy storage technology with hydrogen energy technology. This system combines the large-scale energy storage capacity of compressed air energy storage technology with the environmentally friendly characteristics of hydrogen. Compared with traditional natural gas refueling systems, hydrogen refueling systems perform better in terms of discharge time, energy storage density and efficiency, and do not produce greenhouse gas emissions. However, since the cost of hydrogen is higher than that of natural gas, the average product cost of pure hydrogen refueling compressed air energy storage systems is also higher, which limits their commercial application.

[0004] In the existing hydrogen regenerative compressed air energy storage system, after the turbine expands to generate electricity, the flue gas still has a high temperature and the energy utilization rate is not high. During the compression process, part of the heat cannot be absorbed during the expansion process, resulting in heat waste. Most importantly, the existing regenerative energy storage system separates the compression and expansion processes, and cannot respond to the grid's requirements for flexible operation of power stations, and cannot quickly change the operating mode, such as from energy storage to energy release operation. Summary of the invention

[0005] The purpose of the present invention is to provide a compressed air energy storage system and method for hydrogen refueling, so as to solve the problems of large gas storage capacity, high parameters, large capacity of main and auxiliary equipment, and poor long-term energy storage effect in large-scale compressed air energy storage power stations, and also solve the problem that the existing hydrogen refueling compressed air energy storage system cannot quickly change the operating mode.

[0006] To achieve the above purpose, the technical solution adopted by the present invention is: A compressed air energy storage system for hydrogen supplementary combustion comprises a compression module, an expansion power generation module, a heat storage module, a heat release module, a performance heating module, a steam-water thermodynamic cycle module, and a cooling module. The compression module comprises a first air compressor, a first heat exchanger, a second air compressor, and a second heat exchanger connected in series in sequence. The expansion power generation module comprises a gas storage reservoir, a third heat exchanger, a mixed combustion chamber, a flue gas turbine, and a flue gas heat exchanger connected in series in sequence. The gas storage reservoir is connected to the second heat exchanger. The heat storage module comprises a cold water tank, a cold water pump, a first heat exchanger, a second heat exchanger, and a hot water tank connected in sequence. The heat release module comprises a hot water tank, a hot water pump, a third heat exchanger, a fifth heat exchanger, and a cold water tank. The performance heating module comprises a flue gas heat exchanger, a first circulation pump, and a fourth heat exchanger connected in a ring. The steam-water thermodynamic cycle module comprises a flue gas heat exchanger, a steam turbine, a condenser, and a second circulation pump connected in a ring. The cooling module comprises a condenser, a cooling tower, and a third circulation pump connected in a ring.

[0007] A further improvement of the technical solution of the present invention is that a first shut-off door and a third shut-off door are respectively provided on the connecting pipe between the first air compressor and the first heat exchanger and the connecting pipe between the second air compressor and the air storage reservoir in the compression module.

[0008] A further improvement of the technical solution of the present invention is that the first air compressor and the third heat exchanger are connected by a pipeline, and a second shut-off door is provided on the pipeline.

[0009] A further improvement of the technical solution of the present invention is that the hydrogen source is connected to the fifth heat exchanger, and the fifth heat exchanger is connected to the fourth heat exchanger and the mixing combustion chamber in sequence.

[0010] A further improvement of the technical solution of the present invention is that a fourth shut-off door is provided on the connecting pipe between the gas storage reservoir and the third heat exchanger in the expansion power generation module, the flue gas turbine drives the generator, and the steam turbine of the steam-water thermal cycle module is connected to the generator.

[0011] A further improvement of the technical solution of the present invention is that the first circulating pump is interlocked with the power generation settings of the flue gas turbine and the steam turbine.

[0012] A further improvement of the technical solution of the present invention is that: the compression module is used to compress and store air, the expansion power generation module is used to release the compressed air into the turbine to expand and do work, the heat storage module is used to absorb and store the heat generated during the air compression process, the heat release module is used to release the stored heat to the air and hydrogen, the performance heater module is used to heat the hydrogen, and the steam-water thermal cycle module is used to absorb the heat of the flue gas to further expand and do work.

[0013] A method for storing compressed air energy with hydrogen supplementary combustion, comprising the following arrangement: S1, in the low-load phase, the temperature of the atmosphere increases after being compressed by the first air compressor, the first shut-off door and the third shut-off door are opened, and the second shut-off door and the fourth shut-off door are closed; the temperature of the high-temperature air decreases after passing through the first heat exchanger, increases after being compressed by the second air compressor, decreases after entering the second heat exchanger, and is finally stored in the gas storage; S2. During the above S1 process, the cold water pump increases the pressure of the water in the cold water tank, and then divides it into two paths, entering the first heat exchanger and the second heat exchanger respectively, absorbing the temperature released by the high-temperature air in the S1 process, and the water is heated to become high-temperature hot water and stored in the hot water tank; S3, at the peak of the electric load, the fourth shut-off door is opened and the third shut-off door is closed. At this time, the high-pressure and low-temperature air in the gas storage first passes through the third heat exchanger to absorb heat and heat up, and then enters the mixed combustion chamber to be mixed and burned with the hydrogen that has passed through the fifth heat exchanger and the fourth heat exchanger to heat up. The high-temperature flue gas generated enters the flue gas turbine to expand and do work, and then enters the flue gas heat exchanger to release heat and become low-temperature flue gas to be discharged into the atmosphere; S4. At the same time as the above S3 process, the hot water pump increases the pressure of the water in the hot water tank and enters the third heat exchanger to release the heat to the low-temperature air from the gas storage. The water after heat exchange enters the fifth heat exchanger to fully exchange heat with the low-temperature hydrogen, and then enters the cold water tank for storage; S5. At the same time as the above S3 process, the hot water after absorbing heat in the flue gas heat exchanger is supplied to the fourth heat exchanger through the first circulation pump, and the heat is released to the hydrogen. The water after heat exchange is returned to the flue gas heat exchanger. The circulation flow rate is controlled by controlling the speed of the first circulation pump, and then the temperature of the hydrogen entering the mixed combustion chamber is controlled to increase or decrease the power generation power of the flue gas turbine and the steam turbine. S6. At the same time as the above S3 process, the high-temperature steam generated after passing through the flue gas heat exchanger enters the steam turbine, expands and performs work, and the exhaust steam enters the condenser to condense into water, and then the condensed water is pumped into the flue gas heat exchanger through the second circulation pump; S7. At the same time as the above S3 process, the third circulating pump pumps the water condensed by the cooling tower into the condenser to exchange heat with the exhaust steam of the above S6 process, and the heated water returns to the cooling tower; S8. When the unit needs emergency peak operation, close the first shut-off door, the third shut-off door and the fourth shut-off door, and open the second shut-off door. At this time, the air pressurized by the first air compressor is no longer stored, bypasses the gas storage, and directly enters the mixing combustion chamber for mixed combustion with hydrogen. The unit enters a combined cycle operation mode similar to a gas turbine. At this time, steps S5 to S7 are performed simultaneously.

[0014] A further improvement of the technical solution of the present invention is that the medium pressure after the first air compressor is 1.1 times the inlet pressure of the flue gas turbine.

[0015] Due to the adoption of the above technical solution, the technical progress achieved by the present invention is: By setting up a compressed air energy storage system and method with hydrogen supplementary combustion, the present invention greatly reduces the flow rate of compressed air, reduces the parameters of the gas storage reservoir, improves the cycle efficiency of long-term energy storage, and makes the system more flexible and adaptable to the requirements of new power systems compared to non-supplementary combustion systems.

[0016] The present invention realizes the transformation of the unit from a pure compression operation mode to a gas turbine combined cycle operation mode according to the dispatching instruction of the external grid power load by setting a switching valve.

[0017] The present invention provides a fifth heat exchanger to use the heat that cannot be fully utilized by the compression heat of the conventional non-supplementary combustion compressed air energy storage system to heat the low-temperature hydrogen from the storage tank, thereby achieving efficient use of energy.

[0018] The present invention further increases the temperature of hydrogen by setting a performance heating module to improve the output and efficiency of the turbine. The present invention is suitable for large-scale and large-capacity compressed air energy storage. BRIEF DESCRIPTION OF THE DRAWINGS

[0019] Figure 1 It is a schematic diagram of a compressed air energy storage system with hydrogen supplementary combustion according to the present invention; Among them: 1. the first air compressor, 2. the second air compressor, 3. the first heat exchanger, 4. the second heat exchanger, 5. the gas storage, 6. the hot water tank, 7. the cold water tank, 8. the hot water pump, 9. the cold water pump, 10. the third heat exchanger, 11. the mixing combustion chamber, 12. the fourth heat exchanger, 13. the fifth heat exchanger, 14. the flue gas turbine, 15. the flue gas heat exchanger, 16. the steam turbine, 17. the condenser, 18. the second circulation pump, 19. the first circulation pump, 20. the cooling tower, 21. the third circulation pump, 31. the first shut-off door, 32. the second shut-off door, 33. the third shut-off door, 34. the fourth shut-off door. DETAILED DESCRIPTION

[0020] The present invention is further described in detail below in conjunction with embodiments: like Figure 1As shown, a compressed air energy storage system for hydrogen supplementary combustion includes a compression module, an expansion power generation module, a heat storage module, a heat release module, a performance heating module, a steam-water thermodynamic cycle module, and a cooling module. The compression module includes a first air compressor 1, a first heat exchanger 3, a second air compressor 2, and a second heat exchanger 4 connected in series in sequence. The expansion power generation module includes a gas storage reservoir 5, a third heat exchanger 10, a mixed combustion chamber 11, a flue gas turbine 14, and a flue gas heat exchanger 15 connected in series in sequence. The gas storage reservoir 5 is connected to the second heat exchanger 4. The heat storage module includes a cold water tank connected in series in sequence. 7, a cold water pump 9, a first heat exchanger 3, a second heat exchanger 4 and a hot water tank 6, the heat release module includes a hot water tank 6, a hot water pump 8, a third heat exchanger 10, a fifth heat exchanger 13 and a cold water tank 7, the performance heating module includes a flue gas heat exchanger 15, a first circulation pump 19 and a fourth heat exchanger 12 connected in a ring, that is, the flue gas heat exchanger 15, the first circulation pump 19 and the fourth heat exchanger 12 form a circulation loop, the flue gas heat exchanger 15 is connected to the first circulation pump 19, the first circulation pump 19 is connected to the fourth heat exchanger 12, and the fourth heat exchanger 12 is connected to the flue gas heat exchanger 15; The steam-water thermal cycle module includes a flue gas heat exchanger 15, a steam turbine 16, a condenser 17 and a second circulating pump 18 connected in a ring, that is, the flue gas heat exchanger 15, the steam turbine 16, the condenser 17 and the second circulating pump 18 form a circulation loop, the flue gas heat exchanger 15 is connected to the steam turbine 16, the condenser 17 and the second circulating pump 18 in sequence, and the second circulating pump 18 is connected to the flue gas heat exchanger 15. The multi-stage heat exchange between the flue gas heat exchanger 15 and steam and water provided in the present application enables the heat of the flue gas to be utilized in stages, thereby recovering the heat to the maximum extent.

[0021] The cooling module includes a condenser 17, a cooling tower 20 and a third circulating pump 21 connected in a ring. Similarly, the condenser 17, the cooling tower 20 and the third circulating pump 21 form a circulation loop.

[0022] In the compression module, the first shutoff door 31 and the third shutoff door 33 are respectively provided on the connecting pipes between the first air compressor 1 and the first heat exchanger 3 and the connecting pipes between the second air compressor 2 and the gas storage 5. The first air compressor 1 and the third heat exchanger 10 are connected by a pipeline, and the second shutoff door 32 is provided on the pipeline. A pipeline to the expansion power generation module is provided after the first air compressor 1, bypassing the gas storage 5. When the unit needs emergency peak operation, the operation mode can be quickly changed to meet the flexible operation requirements. The medium pressure after the first air compressor (1) is 1.1 times the inlet pressure of the flue gas turbine (14).

[0023] The hydrogen source is connected to the fifth heat exchanger 13, and the fifth heat exchanger 13 is connected to the fourth heat exchanger 12 and the mixing combustion chamber 11 in sequence. The hydrogen fully absorbs the heat stored in the air compression stage, and the water temperature can be reduced to the water storage temperature of the cold water tank, thereby avoiding heat loss. The hydrogen source can be a hydrogen storage tank. The hydrogen is heated by two-stage heat exchangers and enters the mixing combustion chamber 11, thereby improving the turbine output and efficiency in the expansion stage.

[0024] A fourth shutoff door 34 is provided on the connecting pipe between the gas storage reservoir 5 and the third heat exchanger 10 in the expansion power generation module, the flue gas turbine 14 drives the generator, and the steam turbine 16 of the steam-water thermal cycle module is connected to the generator.

[0025] The present application provides a performance heating module, and interlocks it with the turbine output, and can effectively adjust the turbine output by controlling the operation of the pump.

[0026] A compressed air energy storage system with hydrogen supplementary combustion, wherein the compression module is used to compress and store air, the expansion power generation module is used to release the compressed air into the turbine for expansion and work, the heat storage module is used to absorb and store the heat generated during the air compression process, the heat release module is used to release the stored heat to the air and hydrogen, the performance heater module is used to heat the hydrogen, and the steam-water thermal cycle module is used to absorb the heat of the flue gas for further expansion and work.

[0027] A method for storing compressed air energy with hydrogen supplementary combustion, comprising the following arrangement: S1. In the low-load stage, the air temperature rises to about 300°C after being compressed by the first air compressor 1. At this time, the first shutoff door 31 and the third shutoff door 33 are opened, and the second shutoff door 32 and the fourth shutoff door 34 are closed. The high-temperature air has a lower temperature after passing through the first heat exchanger 3, and has a higher temperature after entering the second air compressor 2 for compression, and has a lower temperature after entering the second heat exchanger 4, and is finally stored in the gas storage 5.

[0028] S2. At the same time as the above S1 process, the cold water pump 9 increases the pressure of the water in the cold water tank 7, and then divides it into two paths, entering the first heat exchanger 3 and the second heat exchanger 4 respectively, absorbing the temperature released by the high-temperature air in the S1 process, and the water is heated to become high-temperature hot water and stored in the hot water tank 6.

[0029] S3. During the peak period of electric load, the fourth shut-off door 34 is opened and the third shut-off door 33 is closed. At this time, the high-pressure and low-temperature air in the gas storage reservoir 5 first passes through the third heat exchanger 10 to absorb heat and heat up, and then enters the mixing combustion chamber 11, where it is mixed and burned with the hydrogen that has been heated up by the fifth heat exchanger 13 and the fourth heat exchanger 12, generating high-temperature flue gas of about 600°C, which enters the flue gas turbine 14 to expand and do work, and then enters the flue gas heat exchanger 15 to release heat and becomes low-temperature flue gas to be discharged into the atmosphere.

[0030] S4. At the same time as the above S3 process, the hot water pump 8 increases the pressure of the water in the hot water tank 6 and enters the third heat exchanger 10 to release the heat to the low-temperature air from the gas storage 5. Due to the existence of the heat exchange end difference, the water temperature after heat exchange is higher than the water temperature in the cold water tank 7, so the water after heat exchange enters the fifth heat exchanger 13, fully exchanges heat with the low-temperature hydrogen from the hydrogen storage tank, and then enters the cold water tank 7 for storage.

[0031] S5. At the same time as the above S3 process, the hot water after absorbing heat in the flue gas heat exchanger 15 is supplied to the fourth heat exchanger 12 through the first circulation pump 19, and the heat is released to the hydrogen, so as to improve the output and efficiency of the flue gas turbine 14, and the water after heat exchange is returned to the flue gas heat exchanger 15. The first circulation pump 19 is interlocked with the power generation setting of the flue gas turbine 14 and the steam turbine 16. By controlling the rotation speed of the first circulation pump 19, the circulation flow rate is controlled, and then the temperature of the hydrogen entering the mixed combustion chamber 11 is controlled to increase or decrease the power generation of the flue gas turbine 14 and the steam turbine 16.

[0032] S6. At the same time as the above S3 process, the high-temperature steam generated after passing through the flue gas heat exchanger 15 enters the steam turbine 16, expands and does work, and the exhaust steam enters the condenser 17 to condense into water, and then the condensed water is pumped into the flue gas heat exchanger 15 through the second circulation pump 18.

[0033] S7. At the same time as the above S3 process, the third circulation pump 21 pumps the water condensed by the cooling tower 20 into the condenser 17 to exchange heat with the exhaust steam of the above S6 process, and the heated water returns to the cooling tower 20.

[0034] S8, when the unit needs emergency peak operation, close the first shutoff door 31, the third shutoff door 33 and the fourth shutoff door 34, open the second shutoff door 32, at this time, the air pressurized by the first air compressor 1 is no longer stored, bypasses the gas storage 5, and directly enters the mixed combustion chamber 11 to mix and burn with hydrogen, and the unit enters a similar gas turbine combined cycle operation mode. At this time, steps S5 to S7 are performed simultaneously.

Claims

1. A hydrogen supplementary combustion compressed air energy storage system, characterized in that: The invention comprises a compression module, an expansion power generation module, a heat storage module, a heat release module, a performance heating module, a steam-water thermodynamic cycle module, and a cooling module. The compression module comprises a first air compressor (1), a first heat exchanger (3), a second air compressor (2), and a second heat exchanger (4) connected in series in sequence. The expansion power generation module comprises a gas storage reservoir (5), a third heat exchanger (10), a mixed combustion chamber (11), a flue gas turbine (14), and a flue gas heat exchanger (15) connected in series in sequence. The gas storage reservoir (5) is connected to the second heat exchanger (4). The heat storage module comprises a cold water tank (7), a cold water pump (9), a first heat exchanger (11), and a second heat exchanger (15) connected in series in sequence. The heat release module comprises a hot water tank (6), a hot water pump (8), a third heat exchanger (10), a fifth heat exchanger (13) and a cold water tank (7); the performance heating module comprises a flue gas heat exchanger (15), a first circulation pump (19) and a fourth heat exchanger (12) connected in a ring; the steam-water thermodynamic cycle module comprises a flue gas heat exchanger (15), a steam turbine (16), a condenser (17) and a second circulation pump (18) connected in a ring; and the cooling module comprises a condenser (17), a cooling tower (20) and a third circulation pump (21) connected in a ring.

2. A hydrogen supplementary combustion compressed air energy storage system according to claim 1, characterized in that: In the compression module, a first shutoff door (31) and a third shutoff door (33) are respectively provided on the connecting pipe between the first air compressor (1) and the first heat exchanger (3) and the connecting pipe between the second air compressor (2) and the air storage reservoir (5).

3. A hydrogen supplementary combustion compressed air energy storage system according to claim 2, characterized in that: The first air compressor (1) and the third heat exchanger (10) are connected via a pipeline, and a second shutoff door (32) is provided on the pipeline.

4. A hydrogen supplementary combustion compressed air energy storage system according to claim 1, characterized in that: The hydrogen source is connected to the fifth heat exchanger (13), and the fifth heat exchanger (13) is connected in sequence to the fourth heat exchanger (12) and the mixing combustion chamber (11).

5. A hydrogen supplementary combustion compressed air energy storage system according to claim 1, characterized in that: A fourth shutoff door (34) is provided on the connecting pipe between the gas storage reservoir (5) and the third heat exchanger (10) in the expansion power generation module, the flue gas turbine (14) drives the generator, and the steam turbine (16) of the steam-water thermal cycle module is connected to the generator.

6. A hydrogen supplementary combustion compressed air energy storage system according to claim 4, characterized in that: The first circulation pump (19) is interlocked with the power generation settings of the flue gas turbine (14) and the steam turbine (16).

7. A hydrogen supplementary combustion compressed air energy storage system according to claim 1, characterized in that: The compression module is used to compress and store air, the expansion power generation module is used to release the compressed air into the turbine for expansion and work, the heat storage module is used to absorb and store the heat generated during the air compression process, the heat release module is used to release the stored heat to the air and hydrogen, the performance heater module is used to heat the hydrogen, and the steam-water thermal cycle module is used to absorb the heat of the flue gas for further expansion and work.

8. A method for storing compressed air energy with hydrogen supplementary combustion, characterized in that The following arrangements are included: S1, in the low-load phase, the temperature of the atmosphere increases after being compressed by the first air compressor (1), the first shutoff door (31) and the third shutoff door (33) are opened, and the second shutoff door (32) and the fourth shutoff door (34) are closed; the temperature of the high-temperature air decreases after passing through the first heat exchanger (3), the temperature increases after entering the second air compressor (2) for compression, the temperature decreases after entering the second heat exchanger (4), and finally is stored in the gas storage reservoir (5); S2. At the same time as the above process S1, the cold water pump (9) increases the pressure of the water in the cold water tank (7), and then divides it into two paths, entering the first heat exchanger (3) and the second heat exchanger (4) respectively, absorbing the temperature released by the high-temperature air in the process of S1, and the water is heated to become high-temperature hot water and is stored in the hot water tank (6); S3, during the peak period of electric load, the fourth shutoff door (34) is opened and the third shutoff door (33) is closed. At this time, the high-pressure and low-temperature air in the gas storage reservoir (5) first passes through the third heat exchanger (10) to absorb heat and then enters the mixed combustion chamber (11) to be mixed and burned with the hydrogen that has been heated by the fifth heat exchanger (13) and the fourth heat exchanger (12). The generated high-temperature flue gas enters the flue gas turbine (14) to expand and do work, and then enters the flue gas heat exchanger (15) to release heat and become low-temperature flue gas to be discharged into the atmosphere; S4. At the same time as the above S3 process, the hot water pump (8) increases the pressure of the water in the hot water tank (6), and the water enters the third heat exchanger (10), and releases the heat to the low-temperature air from the gas storage reservoir (5). The water after heat exchange enters the fifth heat exchanger (13), fully exchanges heat with the low-temperature hydrogen, and then enters the cold water tank (7) for storage; S5. At the same time as the above-mentioned S3 process, the hot water after absorbing heat in the flue gas heat exchanger (15) is supplied to the fourth heat exchanger (12) through the first circulation pump (19), and the heat is released to the hydrogen. The water after heat exchange is returned to the flue gas heat exchanger (15). The circulation flow rate is controlled by controlling the rotation speed of the first circulation pump (19), and the temperature of the hydrogen entering the mixed combustion chamber (11) is controlled, so as to increase or decrease the power generation power of the flue gas turbine (14) and the steam turbine (16); S6. At the same time as the above S3 process, the high-temperature steam generated after passing through the flue gas heat exchanger (15) enters the steam turbine (16), expands to do work, and the exhaust steam enters the condenser (17) to condense into water, and then the condensed water is pumped into the flue gas heat exchanger (15) through the second circulation pump (18); S7. At the same time as the above process S3, the third circulating pump (21) pumps the water condensed by the cooling tower (20) into the condenser (17) to exchange heat with the exhaust steam of the above process S6, and the heated water returns to the cooling tower (20); S8. When the unit needs to be operated at an emergency peak, the first shut-off door (31), the third shut-off door (33) and the fourth shut-off door (34) are closed, and the second shut-off door (32) is opened. At this time, the air pressurized by the first air compressor (1) is no longer stored, bypasses the gas storage reservoir (5), and directly enters the mixing combustion chamber (11) to be mixed with hydrogen for combustion. The unit enters a similar gas turbine combined cycle operation mode. At this time, steps S5 to S7 are performed simultaneously.

9. A method for storing compressed air energy with hydrogen supplementary combustion according to claim 7, characterized in that: The medium pressure after the first air compressor (1) is 1.1 times the inlet pressure of the flue gas turbine (14).

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