JP6906381B2 - Combustion equipment and gas turbine - Google Patents

Description

Embodiments of the present invention relate to combustion equipment and gas turbines.

The combined cycle thermal power generation facility is provided with a combination of a gas turbine and a steam turbine driven by steam generated in an exhaust heat recovery steam generator. In this thermal power generation facility, a gas turbine and a steam turbine are connected to a generator, and each turbine is driven to convert kinetic energy into electric energy.

Gas turbines are generally open to the atmosphere, with compressors that compress the air in the atmosphere, combustors that burn the air and fuel sent by the compressors, and high-temperature, high-pressure combustion gas produced by the combustors. It is equipped with a turbine driven by. Then, the combustion gas that drives the turbine is released into the atmosphere via the exhaust heat recovery boiler.

Regarding the combustion gas discharged from the gas turbine, the establishment of technology for reducing dust, NOx, and SOx is being promoted from the viewpoint of the Air Pollution Control Act. Furthermore, as a measure against global warming, it is a social obligation to reduce the amount of _{CO 2} generated when burning fossil fuels in order to suppress the rise in atmospheric temperature.

_{The amount of CO 2} emitted from thermal power generation is enormous. Therefore, as an alternative to fossil fuels as natural gas and coal and the like for discharging the CO _2, in recent years, hydrogen does not generate CO ₂ has attracted attention.

Hydrogen is a clean energy, but it is a low-density gas at normal temperature and pressure. Therefore, the development of an energy carrier for storing and transporting a large amount of hydrogen becomes an issue. Currently, studies are underway on the storage and transportation of liquefied hydrogen at extremely low temperatures, or the storage and transportation of hydrogen in methylcyclohexane combined with petroleum. However, when aiming for the realization of a hydrogen-based society, the characteristics of hydrogen also become an obstacle from the viewpoint of safety and economy.

On the other hand, it has been proposed to use ammonia, which is easy to store and transport and has already developed infrastructure, as an energy carrier. Ammonia is inexpensive and is distributed in large quantities. In addition, ammonia can be stored as a liquid at room temperature. Ammonia is also excellent in safety against explosion. _{Furthermore, CO 2} is not generated in the combustion of ammonia. Therefore, ammonia is a clean fuel.

Moreover, the calorific value of ammonia is larger than the calorific value of hydrogen. Therefore, if ammonia can be used as a fuel in a conventional gas turbine, it is effective in reducing _{CO 2.} However, since the development of a gas turbine using ammonia as a fuel is currently being attempted, there is no gas turbine commercially available using ammonia as a fuel.

Japanese Patent No. 5024460

Soot that pollutes the air contains NOx. This NOx adversely affects the human body. Therefore, the amount of NOx emitted from power generation facilities is regulated by the Air Pollution Control Act. For example, if the gas turbine power generation facility, NOx concentration in the exhaust gas discharged from the chimney, 70 ppm: is regulated in the following _(O 2 16% conversion).

For example, in the current combined cycle power generation facility that uses natural gas as fuel, a gas turbine having a combustion gas temperature of 1600 ° C. is adopted in order to generate high-efficiency power generation. In this gas turbine, the concentration of thermal NOx (NOx generated by oxidation of nitrogen in the atmosphere) generated from the combustor is suppressed to several tens of ppm.

Further, by installing a denitration catalyst device that reduces NOx in the exhaust flow path of the gas turbine, the thermal NOx concentration can be reduced to about 1/10.

As described above, NOx reduction technology has been established for gas turbines that use natural gas as fuel.

On the other hand, as described above, in the combustion of ammonia, CO ₂ is not emitted, but the nitrogen component of ammonia is oxidized, and fuel NOx is generated by the following reactions (formulas (1) and (2)).
4NH ₃ + 5O ₂ → 4NO + 6H ₂ O… Equation (1)
4NH ₃ + 7O ₂ → 4NO ₂ + 6H ₂ O… Equation (2)

A technical challenge in the combustion of ammonia is that the emitted combustion gas meets environmental standards even when fuel NOx is generated by combustion.

However, when ammonia is used as a fuel in a conventional gas turbine having a combustion gas temperature of 1600 ° C., a part of nitrogen in the ammonia undergoes an oxidation reaction in a high temperature combustion state, and the NOx concentration may reach several thousand ppm. is expected. In order to reduce this high concentration of NOx in the denitration catalyst device, a large-scale denitration catalyst device or the like is required. Therefore, the product cost increases and the economy is inferior.

As described above, it is practically difficult to use ammonia as fuel in a conventional gas turbine.

An object to be solved by the present invention is to provide a combustion device and a gas turbine capable of suppressing the generation of _{NOx and CO 2.}

The combustion apparatus of the embodiment includes a first combustor liner in which air and ammonia are introduced, hydrogen generated by thermal decomposition of ammonia is burned, and the temperature of the combustion gas is maintained at 800 to 1100 ° C. It is connected to the downstream end of the combustor liner of the above and includes a second combustor liner into which gas fuel and air, which are mainly free of nitrogen compounds, are introduced.

It is a figure which showed typically the thermal power generation facility which includes the gas turbine of 1st Embodiment. It is a figure which showed typically the gas turbine of 1st Embodiment. It is a figure which shows the relationship between the characteristic of thermal decomposition and oxidation of ammonia, and temperature. It is a figure which showed the relationship between the power generation output of the thermal power generation facility in 1st Embodiment, and the fuel flow rate supplied to the combustor of a gas turbine. It is a figure which showed typically the gas turbine of the 2nd Embodiment. It is a figure which showed the relationship between the denitration rate and temperature in the catalyst-free selective reduction method which uses ammonia as a reducing agent. It is a figure which showed typically the thermal power generation facility which includes the gas turbine of the 3rd Embodiment. It is a figure which showed typically the cooling air system of the stationary blade in the gas turbine of the 3rd Embodiment. It is a figure which shows the AA cross section of FIG.

Hereinafter, embodiments of the present invention will be described with reference to the drawings.

(First Embodiment)
FIG. 1 is a diagram schematically showing a thermal power generation facility 10 including the gas turbine 20A of the first embodiment. Note that FIG. 1 illustrates a combined cycle thermal power generation facility 10 in which a gas turbine 20A and a steam turbine 40 driven by steam generated in the exhaust heat recovery boiler 30 are combined.

As shown in FIG. 1, the thermal power generation facility 10 includes a gas turbine 20A, an exhaust heat recovery boiler 30, a steam turbine 40, a condenser 50, and a control device 80. Further, the thermal power generation facility 10 includes, for example, a generator 60 uniaxially connected to a gas turbine 20A and a steam turbine 40.

The gas turbine 20A includes a compressor 21, a combustor 22A, and a turbine 23. Further, the gas turbine 20A includes an air filter 24 for purifying the air sucked by the compressor 21 in the suction system of the compressor 21.

Further, the combustor 22A includes an ammonia supply pipe 25 for introducing ammonia into the combustor 22A and a gas fuel supply pipe 26 for introducing gas fuel into the combustor 22A. Here, the ammonia supplied to the combustor 22A is a gas.

The gas fuel is a gaseous fuel that mainly contains no nitrogen compound. That is, as the gas fuel, a fuel that does not mainly generate fuel NOx by burning the gas fuel is used. Specifically, as the gas fuel, for example, hydrocarbons such as natural gas and methane, and hydrogen are used. Further, as the gas fuel, for example, coal gasification gas fuel containing carbon monoxide, hydrogen and the like can be used.

The gas fuel mainly containing no nitrogen compound means a gas fuel in which the volume ratio of the nitrogen compound in the fuel is 0.3% or less. For example, nitrogen compounds contained in the coal gasification gas fuels are primarily NH _3.

Here, as described above, when the gas turbine power generation facility, NOx concentration in the exhaust gas discharged from the chimney, 70 ppm: is regulated in the following _(O 2 16% conversion). A further reduction of the emission concentration of NOx is promoted, for example, the concentration of NO discharged from the chimney 15 ppm: Assume _(O 2 16% conversion) degree. In this case, when the denitration efficiency in the denitration apparatus 90%, the concentration of NO at the outlet (inlet of the denitrification apparatus) of a gas turbine, 150 ppm: the _(O 2 16% conversion).

The concentration of thermal NO discharged from the current of the gas turbine, for example, about 10 ppm: an _(O 2 16% conversion). Therefore, if the NH ₃ as a nitrogen compound containing the gas fuel, the remaining 140 ppm: is NO equivalent to _(O 2 16% conversion), in which NH ₃ contained in the fuel is converted as fuel NO all.

In the current 1600 ° C class gas turbine, the volume ratio (exhaust gas: air: fuel) of the exhaust gas, the air supplied to the entire combustor, and the fuel supplied to the entire combustor is 1: 0.958: It becomes 0.042. In this case, _{the volume concentration of NH 3 in} the fuel is 0.33% ((140/10000 / 0.042) × 100).

As described above, in the gas fuel, by setting the volume ratio of the nitrogen compounds in the fuel to 0.3% or less, even if all the nitrogen compounds in the fuel are converted to fuel NO, the fuel NO is 140 ppm (O). _The concentration is lower than (2: 16% conversion).

Therefore, when the gas fuel contains a nitrogen compound, the volume ratio of the nitrogen compound in the fuel is set to 0.3% or less.

A flow rate adjusting valve 25a, a shutoff valve 25b, and a flow meter 25c are interposed in the ammonia supply pipe 25. The flow rate adjusting valve 25a is a valve that adjusts the flow rate of ammonia supplied to the combustor 22A. The shutoff valve 25b is a valve that shuts off the supply of ammonia to the combustor 22A. The flow meter 25c is a device that detects the flow rate of ammonia supplied to the combustor 22A. Ammonia is supplied to the ammonia supply pipe 25 from a supply source (not shown).

A flow rate adjusting valve 26a, a shutoff valve 26b, and a flow meter 26c are interposed in the gas fuel supply pipe 26. The flow rate adjusting valve 26a is a valve that adjusts the flow rate of the gas fuel supplied to the combustor 22A. The shutoff valve 26b is a valve that shuts off the supply of gas fuel to the combustor 22A. The flow meter 26c is a device that detects the flow rate of the gas fuel supplied to the combustor 22A. The gas fuel is supplied to the gas fuel supply pipe 26 from a supply source (not shown).

The combustor 22A includes a temperature detector 27 that detects the temperature of the combustion gas generated by introducing ammonia. The combustor 22A functions as a combustion device, and the temperature detector 27 functions as a temperature detection unit. The configuration of the combustor 22A will be described in detail later.

The air purified in the air filter 24 is sucked into the compressor 21 and compressed. The compressed air is supplied to the combustor 22A and burns with ammonia and gas fuel.

The combustion gas generated in the combustor 22A is, for example, a high-temperature and high-pressure gas of about 1600 ° C. This combustion gas is introduced into the turbine 23 and drives the turbine 23. The combustion gas that drives the turbine 23 is introduced into the exhaust heat recovery boiler 30. The temperature of the combustion gas introduced into the exhaust heat recovery boiler 30 is, for example, about 600 ° C.

The exhaust heat recovery boiler 30 includes a superheater 31, an ammonia ejection nozzle 32, a denitration catalyst 33, an evaporator 34, and an economizer 35 in this order from the inlet side in the direction in which the combustion gas flows.

The economizer 35 is provided on the outlet side of the exhaust heat recovery boiler 30 to preheat the boiler water supply. That is, the economizer 35 has a function as a heat exchanger that gives the amount of heat obtained from the combustion gas to the boiler water supply flowing inside the economizer 35. Then, the boiler water supply heated by the economizer 35 is guided to the evaporator 34.

The evaporator 34 heats the boiler feed water heated by the economizer 35 to generate steam. That is, the evaporator 34 has a function as a heat exchanger that gives the amount of heat obtained from the combustion gas to the boiler water supply flowing inside the evaporator 34. Then, the steam generated in the evaporator 34 is guided to the superheater 31.

The superheater 31 superheats the steam generated in the evaporator 34 to a saturation temperature or higher to obtain superheated steam. That is, the superheater 31 has a function as a heat exchanger that gives the amount of heat obtained from the combustion gas to the steam generated by the evaporator 34 flowing inside the superheater 31. Then, the steam that has become superheated steam in the superheater 31 is introduced into the steam turbine 40.

An ammonia ejection nozzle 32 and a denitration catalyst 33 are provided between the superheater 31 and the evaporator 34.

The ammonia ejection nozzle 32 is provided, for example, in a passage through which the combustion gas that has passed through the superheater 31 flows. A plurality of ammonia ejection nozzles 32 may be provided in the cross section of the passage through which the combustion gas passes. Further, a flow rate adjusting valve 36a, a shutoff valve 36b, and a flow meter 36c are interposed in a pipe 36 for guiding ammonia to the ammonia ejection nozzle 32.

The flow rate adjusting valve 36a is a valve that adjusts the flow rate of ammonia supplied to the ammonia ejection nozzle 32. The shutoff valve 36b is a valve that shuts off the supply of ammonia to the ammonia ejection nozzle 32. The flow meter 36c is a device that detects the flow rate of ammonia supplied to the ammonia ejection nozzle 32. Ammonia is supplied to the pipe 36 from a supply source (not shown).

The ammonia ejection nozzle 32 ejects ammonia into the combustion gas that has passed through the superheater 31. Then, the combustion gas containing ammonia passes through the denitration catalyst 33. At this time, ammonia functions as a reducing agent and is used when NOx contained in the combustion gas is reduced by the selective catalytic reduction method in the denitration catalyst 33.

As described above, the ammonia ejection nozzle 32 and the denitration catalyst 33 constitute a denitration device by the selective contact reduction method.

As the denitration catalyst 33, for example, a catalyst in which the main component is titanium dioxide and vanadium, tungsten or the like is added can be used. The denitration catalyst 33 has a porous structure such as a honeycomb structure or a porous body in order to increase the contact area with the combustion gas.

Here, the reduction of NOx by the selective catalytic reduction method using ammonia as a reducing agent is represented by the following formula (3). Here, it is assumed that most of the NOx in the combustion gas is NO, and the reaction of the formula (3) is shown.
4NO + 4NH ₃ + O ₂ → 4N ₂ + 6H ₂ O… Equation (3)

In this way, NO is decomposed into water vapor (H ₂ O) and nitrogen (N _{2 ) by the reaction with ammonia (NH 3).} This reduction provides high activation when the surface temperature of the catalyst is about 350 ° C., and has high denitration efficiency. Therefore, the denitration catalyst 33 is arranged at a position where the combustion gas having a temperature of 300 to 400 ° C. flows. Within this temperature range, the denitration catalyst 33 is preferably arranged at a position where the combustion gas having a temperature of 350 ° C. flows.

The temperature of the combustion gas that has passed through the exhaust heat recovery boiler 30 reaches about 100 ° C., and the combustion gas is discharged from the chimney 70 into the atmosphere.

Further, a sampling probe 37 for collecting a part of the combustion gas discharged from the turbine 23 is provided at the inlet of the exhaust heat recovery boiler 30. Combustion gas at one or more positions in the cross section of the inlet of the exhaust heat recovery boiler 30 is sampled by the sampling probe 37.

The sampling probe 37 communicates with, for example, a gas analyzer (not shown). The NOx concentration is detected by this gas analyzer. When detecting the NOx concentration, for example, a gas analyzer using a chemiluminescent method is used. The gas analyzer is not particularly limited as long as it can detect the concentration of the component to be measured. In addition to NOx, the gas analyzer can also analyze other components such as _{O 2} and CO _2.

The steam turbine 40 is driven by superheated steam introduced from the superheater 31. Then, the generator 60 connected to the steam turbine 40 and the turbine 23 of the gas turbine 20A is driven to generate electricity.

The steam that drives the steam turbine 40 flows into the condenser 50. In the condenser 50, steam is condensed into water. Then, the water is pressurized by the water supply pump 51 and supplied to the economizer 35 of the exhaust heat recovery boiler 30 as boiler water supply.

The control device 80, for example, acquires and processes information from each device and each device of the thermal power generation facility 10 to control the operation of each device and each device. The control device 80 mainly includes, for example, an arithmetic unit (CPU), storage means such as a read-only memory (ROM) and a random access memory (RAM), input / output means, and the like. The CPU executes various arithmetic processes using, for example, a program or data stored in a storage means.

The input / output means inputs an electric signal from an external device or outputs an electric signal to the external device. Input / output means are, for example, flow control valves 25a, 26a, 36a, shutoff valves 25b, 26b, 36b, flow meters 25c, 26c, 36c, temperature detector 27, gas analyzer (not shown), inlet of compressor 21. It is connected to a guide blade drive angle detection device (not shown), an output input controller, a generator 60, etc. so that various signals can be input and output.

The control device 80 can calculate, for example, the air flow rate sucked by the compressor 21 based on the output signal from the drive angle detection device of the inlet guide blade of the compressor 21. Further, the control device 80 can detect an output signal related to the concentration of various components of the combustion gas at the inlet (outlet of the turbine 23) of the exhaust heat recovery boiler 30 based on the output signal from the gas analyzer.

Further, the control device 80 adjusts the flow rate of gas fuel or ammonia as fuel, for example, based on the output request information in the thermal power generation facility 10 input by the output input controller. Further, the control device 80 adjusts, for example, the flow rate of ammonia as a fuel based on the output signal from the temperature detector 27. Further, the control device 80 can detect the actual power generation output based on the output signal from the generator 60.

The process executed by the control device 80 is realized by, for example, a computer device. Further, the control device 80 functions as a control unit.

Next, the configuration of the combustor 22A of the gas turbine 20A will be described in detail.

FIG. 2 is a diagram schematically showing the gas turbine 20A of the first embodiment. As described above, the gas turbine 20A includes a compressor 21, a combustor 22A, and a turbine 23.

As shown in FIG. 2, the combustor 22A includes a combustor casing 100 and two combustor liners 110 and 120 in the combustor casing 100. The combustor casing 100 surrounds the combustor liners 110 and 120 with a predetermined space 101.

A plurality of combustor liners 110 and 120 are installed in the circumferential direction of the combustor casing 100, for example, but FIG. 2 shows one combustor liner 110 and 120.

As shown in FIG. 2, in the space 101 between the combustor casing 100 and the combustor liners 110 and 120, air compressed by the compressor 21 (compressed air) is, for example, from the combustor liner 120 side. It flows toward the combustor liner 110 side.

The combustor liners 110 and 120 have a tubular shape. The combustor liner 110 is located on the upstream side, and the combustor liner 120 is connected to the downstream end of the combustor liner 110. That is, the combustor liner 110 and the combustor liner 120 are connected in series in the direction in which the combustion gas flows, and they communicate with each other. The combustor liner 110 functions as a first combustor liner, and the combustor liner 120 functions as a second combustor liner.

An ammonia supply pipe 25 is connected to the upstream end of the combustor liner 110. Further, on the side wall of the combustor liner 110, an air introduction port 111 for taking in compressed air flowing through the space 101 around the combustor liner 110 is formed. A plurality of the air introduction ports 111 are formed in the circumferential direction of the combustor liner 110, for example.

Here, FIG. 2 shows an example of introducing ammonia into the combustor liner 110 from the ammonia supply pipe 25, but the configuration is not limited to this.

For example, the ammonia supply pipe 25 between the combustor casing 100 and the combustor liner 110 may be provided with an air introduction port for introducing compressed air into the inside. A plurality of the air inlets may be formed in the circumferential direction of the ammonia supply pipe 25. By providing the air inlet in this way, the premixture of ammonia and compressed air is introduced into the combustor liner 110.

A gas fuel supply pipe 26 is connected to the side wall on the upstream side of the combustor liner 120. The gas fuel supply pipe 26 between the combustor casing 100 and the combustor liner 120 is formed with, for example, an air introduction port 121 for introducing compressed air into the inside. A plurality of the air introduction ports 121 are formed, for example, in the circumferential direction of the gas fuel supply pipe 26.

The compressed air introduced into the gas fuel supply pipe 26 from the air introduction port 121 is mixed with the gas fuel flowing through the gas fuel supply pipe 26 and introduced into the combustor liner 120.

Here, an example is shown in which the gas fuel supply pipe 26 is provided with an air introduction port 121 and a premixture of gas fuel and compressed air is introduced into the combustor liner 120, but the configuration is not limited to this. For example, the gas fuel may be introduced from the gas fuel supply pipe 26 to the combustor liner 120 without providing the air introduction port 121 in the gas fuel supply pipe 26.

Further, although FIG. 2 illustrates a configuration including one gas fuel supply pipe 26, a plurality of gas fuel supply pipes 26 may be provided around the combustor liner 120. By providing a plurality of gas fuel supply pipes 26, the mixed combustion state in the combustor liner 120 can be made more uniform.

Further, on the side wall of the combustor liner 120, an air introduction port 122 for taking in compressed air flowing through the space 101 around the combustor liner 120 is formed. As shown in FIG. 2, for example, the air introduction port 122 is formed on the downstream side of the connecting portion between the combustor liner 120 and the gas fuel supply pipe 26. A plurality of the air introduction ports 122 are formed in the circumferential direction of the combustor liner 120, for example.

The position of the air introduction port 122 is not particularly limited, and the air introduction port 122 may be formed on the upstream side of the connecting portion between the combustor liner 120 and the gas fuel supply pipe 26. That is, the air introduction port 122 may be provided at an optimum position for completely burning the gas fuel introduced from the gas fuel supply pipe 26 in the combustor liner 120.

Further, the combustor liner 110 into which ammonia is introduced as fuel is provided with a temperature detector 27 that detects the temperature of the combustion gas in the combustor liner 110. The temperature detector 27 is composed of, for example, a thermocouple or the like.

Here, ammonia is introduced into the combustor liner 110 from the ammonia supply pipe 25, and compressed air is introduced from the air introduction port 111. In this combustor liner 110, ammonia is thermally decomposed and burned. That is, the combustor liner 110 burns hydrogen (H ₂ ) generated by thermally decomposing ammonia.

An amount of air exceeding the amount of air required for complete combustion of hydrogen generated by the thermal decomposition of ammonia is introduced from the air introduction port 111 of the combustor liner 110. That is, the inside of the combustor liner 110 is in a so-called fuel lean state as a whole.

In order to promote the thermal decomposition of ammonia and efficiently burn hydrogen, the temperature of the combustion field in the combustor liner 110, that is, the temperature of the combustion gas is maintained at 800 to 1100 ° C. By burning the hydrogen produced by the thermal decomposition of ammonia, the temperature of the combustion gas in the combustor liner 110 can be maintained within the above range. The temperature of the combustion gas in the combustor liner 110 is maintained within the above range regardless of the load on the gas turbine.

In order to maintain the temperature of the combustion gas in the combustor liner 110 within the above range, the control device 80 controls the flow rate adjusting valve 25a of the ammonia supply pipe 25 based on the output signal from the temperature detector 27. ..

The temperature detector 27 is preferably installed so that, for example, the temperature in the region where the thermal decomposition of ammonia and the combustion of hydrogen are actively performed can be detected in the combustor liner 110.

On the other hand, the combustion gas from the combustor liner 110, the gas fuel from the gas fuel supply pipe 26, and the compressed air are introduced into the combustor liner 120 from the air introduction port 122. The combustion gas from the combustor liner 110 flows into the combustor liner 120 through the connection opening between the combustor liner 110 and the combustor liner 120.

The flow rate of the gas fuel introduced into the combustor liner 120 is adjusted based on, for example, the output request information in the thermal power generation facility 10. Specifically, for example, when the control device 80 detects an output signal related to the output request information in the thermal power generation facility 10 input by the output input controller, the control device 80 controls the flow rate adjusting valve 26a and responds to the output request. The gas fuel is introduced into the combustor liner 120.

Depending on the output requirement, the temperature of the combustion gas in the combustor liner 120 may be, for example, about 1600 ° C.

From the air inlet 122 of the combustor liner 120, an amount of air that exceeds the amount of air required for complete combustion of the gas fuel is introduced. That is, the inside of the combustor liner 120 is in a so-called fuel lean state as a whole.

Here, the reason why the temperature of the combustion gas in the combustor liner 110 is set to the above-mentioned temperature range will be described.

FIG. 3 is a diagram showing the relationship between the thermal decomposition and oxidation characteristics of ammonia and the temperature. Note that FIG. 3 shows the results obtained by numerical analysis.

The relationship between ammonia, nitrogen and hydrogen is expressed by the following equation (4).
2NH ₃ → N ₂ + 3H ₂ … Equation (4)

Ammonia is decomposed into nitrogen and hydrogen by applying heat. This thermal decomposition is promoted at higher temperatures and lower pressures. As shown in FIG. 3, the thermal decomposition of ammonia is rapidly accelerated from a temperature of 350 ° C., and the residual ammonia concentration decreases as the temperature increases.

By applying heat in this way, ammonia is decomposed into nitrogen and hydrogen. That is, ammonia, which is a source of fuel NOx, is reduced.

On the other hand, ammonia is oxidized by oxygen in the atmosphere and mainly produces NO. As shown in FIG. 3, the concentration of this NO increases rapidly as the temperature rises. As shown in FIG. 3, when the temperature exceeds 1100 ° C, the oxidation of ammonia is promoted, and when the temperature is 2000 ° C, the concentration of NO reaches 10000 ppm (1%).

That is, when ammonia is ejected in a high temperature atmosphere having a temperature exceeding 1100 ° C., several thousand ppm of fuel NOx is generated.

Therefore, from the results shown in FIG. 3, it can be seen that by ejecting ammonia into a temperature field of 800 to 1100 ° C., the thermal decomposition of ammonia is promoted and the oxidation of ammonia is suppressed.

That is, by thermally decomposing ammonia and burning hydrogen, the production of fuel NOx by ammonia as a fuel is suppressed. Further, by ejecting ammonia into a temperature field of 800 to 1100 ° C., the formation of fuel NOx due to the oxidation of ammonia is suppressed.

For this reason, the temperature of the combustion gas in the combustor liner 110 is maintained at 800 to 1100 ° C.

Next, the operation of the combustor 22A of the gas turbine 20A will be described with reference to FIGS. 1, 2, and 4.

FIG. 4 is a diagram showing the relationship between the power generation output of the thermal power generation facility 10 and the fuel flow rate supplied to the combustor 22A of the gas turbine 20A in the first embodiment.

As shown in FIG. 4, the gas turbine 20A is required to operate in a wide range from the minimum output to the rated output. Therefore, the amount of heat input to the combustor 22A also changes greatly depending on the output request.

As described above, the temperature of the combustion gas in the combustor liner 110 is maintained within a predetermined range in order to suppress the formation of fuel NOx. From the minimum output (point A) to the predetermined output (point B), which can be adjusted within the temperature range of the combustion gas in the combustor liner 110, it can be handled by using only ammonia as the fuel. That is, in this output range, the output is controlled by adjusting the flow rate of ammonia supplied to the combustor liner 110. Therefore, gas fuel is not supplied to the combustor liner 120.

At the minimum output (point A), the temperature of the combustion gas in the combustor liner 110 is maintained at 800 ° C. Further, at a predetermined output (point B), the temperature of the combustion gas in the combustor liner 110 is maintained at 1100 ° C.

When the output is controlled by adjusting the flow rate of the ammonia, specifically, when the control device 80 detects the output signal related to the output request information in the thermal power generation facility 10 input by the output input controller, for example, Refer to the data that associates the output signal related to the output request information stored in the storage means with the ammonia flow rate.

Then, the control device 80 controls the flow rate adjusting valve 25a based on the output signal related to the output request information and the data thereof, and introduces the ammonia of the flow rate corresponding to the output request into the combustor liner 110. At this time, the shutoff valve 25b is open.

Further, the control device 80 refers to the data for associating the output signal related to the output request information stored in the storage means with the temperature of the combustion gas in the combustor liner 110. Then, the control device 80 controls the flow rate adjusting valve 25a based on the output signal from the temperature detector 27 and the data thereof to adjust the flow rate of ammonia to be introduced into the combustor liner 110.

For example, when the combustion gas temperature detected from the output signal from the temperature detector 27 is higher than the combustion gas temperature corresponding to the output request stored in the storage means, the control device 80 controls the flow rate adjusting valve 25a. Then, the flow rate of ammonia introduced into the combustor liner 110 is reduced.

In this case, when the ammonia flow rate corresponding to the output signal related to the output request information stored in the storage means and the ammonia flow rate adjusted based on the combustion gas temperature detected from the output signal from the temperature detector 27 are different. Ammonia flow rate control based on combustion gas temperature is applied to.

When an output higher than a predetermined output (point B) is required, the gas fuel is burned in the combustor liner 120. That is, in the range exceeding the predetermined output (point B) and up to the rated output (point C), ammonia is supplied to the combustor liner 110 and gas fuel is supplied to the combustor liner 120. At this time, the output is adjusted by adjusting the flow rate of the gas fuel supplied to the combustor liner 120. The temperature of the combustion gas in the combustor liner 110 is maintained at 1100 ° C.

When the output is controlled by adjusting the flow rate of the gas fuel, specifically, when the control device 80 detects the output signal related to the output request information in the thermal power generation facility 10 input by the output input controller, for example. , Refer to the data for associating the output signal related to the output request information stored in the storage means with the gas fuel flow rate and the ammonia flow rate.

Then, the control device 80 controls the flow rate adjusting valve 26a based on the output signal related to the output request information and the data thereof, and introduces the gas fuel of the flow rate corresponding to the output request into the combustor liner 120. At this time, the shutoff valve 26b is open.

Further, the control device 80 compares the required output based on the output request information in the thermal power generation facility 10 with the actual power generation output based on the output signal from the generator 60. Then, the control device 80 controls the flow rate adjusting valve 26a based on the comparison result to adjust the flow rate of the gas fuel to be introduced into the combustor liner 120.

For example, when the power generation output is lower than the required output, the control device 80 controls the flow rate adjusting valve 26a to increase the flow rate of the gas fuel introduced into the combustor liner 120.

Further, even when the output is controlled by adjusting the flow rate of the gas fuel, the control device 80 brings the combustion gas temperature in the combustor liner 110 to 1100 ° C. based on the output signal from the temperature detector 27. As described above, the flow rate adjusting valve 25a is controlled to adjust the flow rate of the ammonia introduced into the combustor liner 110.

As described above, the combustor 22A in the first embodiment includes a combustor liner 110 that thermally decomposes ammonia to burn hydrogen and a combustor liner 120 that burns gas fuel. In this way, by configuring the combustor liners of the combustor 22A with two combustor liners 110 and 120 connected in series, the action in each combustor liner can be classified.

In the combustor liner 110, the production of fuel NOx by ammonia as a fuel is suppressed by thermally decomposing ammonia and burning hydrogen. Further, by maintaining the temperature of the combustion gas in the combustor liner 110 within the above-mentioned range, the generation of thermal NOx when hydrogen is burned is also suppressed.

Further, it is possible to perform control for switching between output control by adjusting the flow rate of ammonia and output control by adjusting the flow rate of gas fuel. In the output control by adjusting the flow rate of ammonia, the temperature of the combustion gas in the combustor liner 110 can be maintained in the range of 800 to 1100 ° C. In the output control by adjusting the flow rate of the gas fuel, the power generation output can be adjusted while maintaining the combustion gas temperature in the combustor liner 110 at 1100 ° C.

Further, by thermally decomposing ammonia in the combustor liner 110 and burning hydrogen, carbon dioxide is not generated in the combustion in the combustor liner 110. When hydrocarbons are used as fuel in the combustor liner 120, carbon dioxide is produced. However, the combustor 22A of the present embodiment can significantly reduce carbon dioxide emissions at the same power generation output as compared with the combustor in which the supplied fuel is all hydrocarbons.

Next, the operation of the denitration device provided with the ammonia ejection nozzle 32 and the denitration catalyst 33 installed in the exhaust heat recovery boiler 30 will be described.

As described above, the thermal power generation facility 10 includes an ammonia ejection nozzle 32 and a denitration catalyst 33 in the exhaust heat recovery boiler 30 (see FIG. 1).

The ammonia ejection nozzle 32 ejects ammonia into the combustion gas discharged from the turbine 23 and passed through the superheater 31. Then, when the combustion gas containing ammonia comes into contact with the denitration catalyst 33, the denitration action according to the above-mentioned formula (3) using ammonia as a reducing agent is mainly promoted. As a result, NOx contained in the combustion gas is decomposed into _{water vapor (H 2} O) and nitrogen (N _2).

By providing the ammonia ejection nozzle 32 and the denitration catalyst 33 in the exhaust heat recovery boiler 30 in this way, the NOx concentration in the combustion gas discharged from the turbine 23 can be reduced.

Here, the flow rate of ammonia ejected from the ammonia ejection nozzle 32 is set as follows, for example.

The control device 80 calculates the NOx concentration in the combustion gas collected by the sampling probe 37 provided at the inlet of the exhaust heat recovery boiler 30 based on the output signal of the gas analyzer. Further, the control device 80 calculates the air flow rate sucked by the compressor 21 based on the output signal from the drive angle detection device of the inlet guide blade of the compressor 21.

Further, the control device 80 calculates the flow rate of the ammonia introduced into the combustor liner 110 based on the output signal of the flow meter 25c, and is introduced into the combustor liner 120 based on the output signal of the flow meter 26c. Calculate the flow rate of gas fuel.

Then, the control device 80 calculates the flow rate of the combustion gas at the inlet of the exhaust heat recovery boiler 30 based on the calculated air flow rate, ammonia flow rate, and gas fuel flow rate. Then, the control device 80 calculates the amount of NOx contained in the combustion gas at the inlet of the exhaust heat recovery boiler 30 based on the NOx concentration and the calculated flow rate of the combustion gas.

Subsequently, the control device 80 controls the flow rate adjusting valve 36a so that the amount of ammonia equal to the amount of NOx is ejected from the ammonia ejection nozzle 32 based on the calculated amount of NOx. The flow rate of ammonia ejected from the ammonia ejection nozzle 32 is adjusted based on, for example, the output signal of the flow meter 36c.

In addition, in order to carry out the reaction of the above-mentioned formula (3), 1 mol of ammonia is required for 1 mol of NO (nitric oxide). Therefore, here, an amount of ammonia equal to the amount of NOx contained in the calculated combustion gas is ejected. Also here, as in the case of the equation (3), it is assumed that most of the NOx in the combustion gas is NO, and the flow rate of ammonia ejected from the ammonia ejection nozzle 32 is calculated.

This makes it possible to prevent ammonia as a reducing agent from remaining in the combustion gas after the denitration treatment.

By providing the ammonia ejection nozzle 32 and the denitration catalyst 33 in the exhaust heat recovery boiler 30 in this way, NOx generated in the combustor liner 120, which is a high-temperature combustion field, can be reduced. As a result, the NOx concentration in the combustion gas discharged from the chimney 70 can be reduced.

(Second Embodiment)
FIG. 5 is a diagram schematically showing the gas turbine 20B of the second embodiment. In the following embodiments, the same components as those of the first embodiment are designated by the same reference numerals, and duplicate description will be omitted or simplified.

The gas turbine 20B of the second embodiment has a different combustor configuration from the gas turbine 20A of the first embodiment. Therefore, here, this different configuration will be mainly described.

As shown in FIG. 5, the gas turbine 20B includes a compressor 21, a combustor 22B, and a turbine 23.

As shown in FIG. 5, the combustor 22B includes a combustor casing 100 and combustor liners 110 and 120 inside the combustor casing 100. Further, the combustor liner 110 includes an upstream combustor liner 110A and a downstream combustor liner 110B. That is, the combustor 22B includes three combustor liners, an upstream combustor liner 110A, a downstream combustor liner 110B, and a combustor liner 120.

The combustor casing 100 surrounds the combustor liners 110 and 120 with a predetermined space 101.

The upstream combustor liner 110A, the downstream combustor liner 110B, and the combustor liner 120 have a tubular shape. The upstream combustor liner 110A is located on the most upstream side, and the downstream combustor liner 110B is connected to the downstream end of the upstream combustor liner 110A. Further, the combustor liner 120 is located on the most downstream side and is connected to the downstream end of the downstream combustor liner 110B.

That is, the upstream combustor liner 110A, the downstream combustor liner 110B, and the combustor liner 120 are connected in series in the direction in which the combustion gas flows, and are communicated with each other. The combustor liner 110 functions as a first combustor liner, and the combustor liner 120 functions as a second combustor liner.

An ammonia supply pipe 25 is connected to the upstream end of the upstream combustor liner 110A. Further, on the side wall of the upstream combustor liner 110A, an air introduction port 112 for taking in compressed air flowing through the space 101 around the upstream combustor liner 110A is formed. A plurality of the air introduction ports 112 are formed, for example, in the circumferential direction of the upstream combustor liner 110A.

Here, FIG. 5 shows an example of introducing ammonia from the ammonia supply pipe 25 into the upstream combustor liner 110A, but the configuration is not limited to this.

For example, an air introduction port for introducing compressed air may be formed in the ammonia supply pipe 25 between the combustor casing 100 and the upstream combustor liner 110A. A plurality of the air inlets may be formed in the circumferential direction of the ammonia supply pipe 25. By providing the air inlet in this way, the premixture of ammonia and compressed air is introduced into the upstream combustor liner 110A.

An air introduction port 113 for taking in compressed air flowing through the space 101 around the downstream combustor liner 110B is formed on the side wall of the downstream combustor liner 110B. The air introduction port 113 is formed on the upstream end side of the downstream combustor liner 110B, for example, as shown in FIG. In other words, the air introduction port 113 is formed on the side wall of the downstream combustor liner 110B on the immediate downstream side of the connection portion between the upstream combustor liner 110A and the downstream combustor liner 110B, for example. A plurality of the air introduction ports 113 are formed, for example, in the circumferential direction of the downstream combustor liner 110B.

The configuration of the combustor liner 120 is the same as the configuration in the first embodiment.

The positions of the air inlets 112 and 113 are not particularly limited. That is, the air inlets 112 and 113 are provided at positions where the upstream combustor liner 110A and the downstream combustor liner 110B can thermally decompose ammonia and hydrogen generated by this thermal decomposition can be completely burned. Just do it.

Further, the downstream combustor liner 110B is provided with a temperature detector 27 that detects the temperature of the combustion gas in the downstream combustor liner 110B.

Here, ammonia is introduced into the upstream combustor liner 110A from the ammonia supply pipe 25, and compressed air is introduced from the air introduction port 112.

The flow rate of air introduced into the upstream combustor liner 110A from the air introduction port 112 is the air forming a theoretical mixture with hydrogen generated by thermal decomposition of ammonia introduced into the upstream combustor liner 110A. Is less than the flow rate of. Here, the theoretical air-fuel mixture is an air-fuel mixture of a fuel and the minimum amount of air theoretically required for complete combustion of the fuel.

That is, for example, an amount of air smaller than the minimum amount of air required for complete combustion of hydrogen generated by thermal decomposition of ammonia is introduced from the air introduction port 112. Therefore, the inside of the upstream combustor liner 110A is in a so-called fuel-rich state as a whole.

In the upstream combustor liner 110A, ammonia is thermally decomposed and burned. That is, the upstream combustor liner 110A burns hydrogen generated by thermally decomposing ammonia.

All of the ammonia introduced from the ammonia supply pipe 25 is not thermally decomposed in the upstream combustor liner 110A. Therefore, a part of ammonia flows into the downstream combustor liner 110B in the state of ammonia. Further, since the inside of the upstream combustor liner 110A is in a fuel-rich state, a part of the hydrogen generated by thermal decomposition does not completely burn in the upstream combustor liner 110A, and the downstream combustor liner does not completely burn. It may flow into 110B.

Combustion gas from the upstream combustor liner 110A, ammonia, and compressed air are introduced into the downstream combustor liner 110B from the air introduction port 113.

Here, in order for the combustor liner 110, that is, the upstream combustor liner 110A and the downstream combustor liner 110B to completely burn the hydrogen generated by the thermal decomposition of the ammonia introduced from the ammonia supply pipe 25 as a whole. An amount of air that exceeds the required amount of air is introduced. Here, the amount of air exceeding the amount of air required for complete combustion of hydrogen generated by the thermal decomposition of ammonia is referred to as an excess amount of air.

Therefore, the amount of air obtained by subtracting the amount of air introduced into the upstream combustor liner 110A from this excess air amount is introduced into the downstream combustor liner 110B from the air introduction port 113. In the downstream combustor liner 110B, an amount of air exceeding the amount of air required for complete combustion of hydrogen generated by thermal decomposition in the downstream combustor liner 110B is introduced.

In the downstream combustor liner 110B, ammonia is thermally decomposed and burned in the same manner as in the upstream combustor liner 110A. That is, the downstream combustor liner 110B burns hydrogen generated by thermally decomposing ammonia.

Further, the downstream combustor liner 110B reduces NOx produced by the upstream combustor liner 110A by a catalytic-free selective reduction method using ammonia as a reducing agent. The reducing agent ammonia is ammonia that has flowed into the downstream combustor liner 110B without being thermally decomposed by the upstream combustor liner 110A.

In the upstream combustor liner 110A and the downstream combustor liner 110B (in the combustor liner 110) in order to promote the thermal decomposition of ammonia, promote the combustion of hydrogen, and reduce NOx in the downstream combustor liner 110B. The temperature of the combustion field, that is, the temperature of the combustion gas is maintained at 800 to 1100 ° C.

By burning the hydrogen produced by the thermal decomposition of ammonia, the temperature of the combustion gas in the combustor liner 110 can be maintained within the above range. The temperature of the combustion gas in the combustor liner 110 is maintained within the above range regardless of the load on the gas turbine.

In order to maintain the temperature of the combustion gas in the combustor liner 110 within the above range, the control device 80 controls the flow rate adjusting valve 25a of the ammonia supply pipe 25 based on the output signal from the temperature detector 27. ..

On the other hand, the combustion gas from the downstream combustor liner 110B, the gas fuel from the gas fuel supply pipe 26, and the compressed air from the air introduction port 122 are introduced into the combustor liner 120. The flow rate and the amount of air of the gas fuel introduced into the combustor liner 120 are as described in the first embodiment.

Here, the reason why the temperature of the combustion gas in the combustor liner 110 is set to the above-mentioned temperature range will be described.

From the viewpoint of promoting the thermal decomposition of ammonia and suppressing the oxidation of ammonia, the above-mentioned temperature range is as described in the first embodiment.

Here, it will be described that the above temperature range is preferable from the viewpoint of non-catalytic selective reduction of NOx using ammonia as a reducing agent.

FIG. 6 is a diagram showing the relationship between the denitration rate and the temperature in the non-catalytic selective reduction method using ammonia as the reducing agent. Note that FIG. 6 also shows these relationships in the selective catalytic reduction method using ammonia as the reducing agent for comparison.

A reduction catalyst is used in the selective catalytic reduction method, and no reduction catalyst is used in the non-catalyst selective reduction method. In the catalyst-free selective reduction method, ammonia is injected into the combustion gas to reduce the above formula (3).

As shown in FIG. 6, in the catalyst-free selective reduction method, the denitration rate is high in the temperature range of 800 to 1100 ° C. On the other hand, in the selective catalytic reduction method, the denitration rate is high mainly at 350 ° C.

As described above, it can be seen that the temperature range of 800 to 1100 ° C. is preferable from the viewpoint of the catalytically selective reduction method.

For this reason, the temperature of the combustion gas in the combustor liner 110 is maintained at 800 to 1100 ° C.

The operation of the combustor 22B of the gas turbine 20B is the same as the operation of the combustor 22A in the first embodiment.

As described above, in the combustor 22B of the second embodiment, the combustor liner 110 is composed of the upstream combustor liner 110A and the downstream combustor liner 110B. Then, in the downstream combustor liner 110B, NOx is reduced by the catalyst-free selective reduction method.

In the combustor 22B of the second embodiment, the same effect as that of the combustor 22A of the first embodiment can be obtained.

That is, in the combustor liner 110, by thermally decomposing ammonia and burning hydrogen, the generation of fuel NOx by ammonia as a fuel is suppressed. Further, by maintaining the temperature of the combustion gas in the combustor liner 110 within the above-mentioned range, the generation of thermal NOx when hydrogen is burned is also suppressed. By thermally decomposing ammonia in the combustor liner 110 and burning hydrogen, carbon dioxide is not generated by combustion in the combustor liner 110.

Further, in the combustor 22B of the second embodiment, in the downstream combustor liner 110B, NOx generated in the upstream combustor liner 110A can be reduced by the catalyst-free selective reduction method.

(Third Embodiment)
FIG. 7 is a diagram schematically showing a thermal power generation facility 11 including the gas turbine 20C of the third embodiment. FIG. 8 is a diagram schematically showing a cooling air system of a stationary blade in the gas turbine 20C of the third embodiment. FIG. 9 is a diagram showing a cross section taken along the line AA of FIG.

The gas turbine 20C of the third embodiment is different from the gas turbine 20A of the first embodiment in the denitration method for the combustion gas discharged from the combustor. Therefore, here, this different configuration will be mainly described.

The combustor 22C used in the gas turbine 20C may be the combustor 22A in the first embodiment or the combustor 22B in the second embodiment.

In the gas turbine 20C of the third embodiment, the ammonia supply system for supplying ammonia is connected to the cooling air system for introducing the cooling air into the vanes 130, 131, 132. Further, the gas turbine 20C is not provided with the ammonia ejection nozzle 32, the pipe 36, the flow rate adjusting valve 36a, the shutoff valve 36b, and the flow meter 36c provided in the first and second embodiments.

Further, the gas turbine 20C includes a temperature detector 170 that detects the temperature of the compressed air in the discharge portion of the compressor 21. Further, the gas turbine 20C includes a temperature detector 171 that detects the temperature of the combustion gas at the outlet of the turbine 23.

As shown in FIGS. 7 and 8, the gas turbine 20C is cooled to introduce cooling air for cooling the vanes 130, 131, 132, 133 of the turbine 23 into the vanes 130, 131, 132, 133. It has an air system.

In the turbine 23, the moving blades 140, 141, 142, and 143 are arranged downstream of the stationary blades 130, 131, 132, and 133. Then, for example, the stationary blade 130 and the moving blade 140 constitute the turbine paragraph of the first stage (first stage). Here, a turbine 23 having a four-stage turbine paragraph is illustrated.

Here, the stationary blade structure will be described with reference to the cross section of the stationary blade 130 shown in FIG. The structures of the other stationary blades 131, 132, 133 are also the same as the structures of the stationary blades 130 shown in FIG.

As shown in FIG. 9, the stationary blade 130 has a hollow portion 135 inside. Further, a ejection hole 136 such as a slit or a hole is formed in the blade effective portion of the stationary blade 130.

The ejection hole 136 is a hole that communicates the hollow portion 135 with the outside of the stationary blade 130. A plurality of ejection holes 136 are formed. Cooling air is ejected from the ejection hole 136 along the surface of the vane 130, for example, to protect the blade surface from high-temperature combustion gas.

Air extracted from the compressor 21 is introduced into the stationary blades 130, 131, 132, 133 through the bleed pipes 150, 151, 152, and 153 that form the cooling air system. The cooling air is introduced into the stationary blades 130, 131, 132, 133 through, for example, through holes (not shown) formed in the outer peripheral wall supporting the stationary blades 130, 131, 132, 133.

Here, the pressure of the flow field (passage in the turbine) for ejecting the cooling air differs depending on the turbine paragraph. Therefore, as shown in FIG. 8, the cooling air system is provided independently corresponding to each turbine paragraph. Then, cooling air having a pressure suitable for each turbine paragraph extracted from the compressor 21 is introduced into the vanes 130, 131, 132, 133 from each cooling air system.

The pressure of the cooling air introduced is highest in the first-stage stationary blade 130 and lowest in the fourth-stage stationary blade 133. For example, the first-stage stationary blade 130 is supplied with the highest pressure compressed air extracted from the discharge portion of the compressor 21.

In this way, the paragraph of the compressor 21 to be bleeded is changed according to the pressure of the cooling air introduced into the stationary blades 130, 131, 132, 133 of each turbine paragraph. As a result, the power loss of the compressor 21 is suppressed. The pressure of the cooling air introduced into each of the stationary blades 130, 131, 132, 133 is higher than the pressure of the flow field from which the cooling air is ejected.

As shown in FIG. 8, for example, the bleed pipes 150, 151, 152 of each cooling air system are connected to the pipes 160, 161 and 162 of the ammonia supply system for supplying ammonia.

Flow control valves 160a, 161a, 162a, shutoff valves 160b, 161b, 162b, and flow meters 160c, 161c, 162c are interposed in the pipes 160, 161 and 162. Ammonia is supplied to the pipes 160, 161 and 162 from a supply source (not shown).

The flow rate adjusting valves 160a, 161a, 162a are valves that adjust the flow rate of ammonia supplied to the bleeding pipes 150, 151, 152. The shutoff valves 160b, 161b, 162b are valves that shut off the supply of ammonia to the bleed pipes 150, 151, 152. The flow meters 160c, 161c, 162c are devices for detecting the flow rate of ammonia supplied to the bleed pipes 150, 151, 152.

Although not shown in FIG. 8, the piping of the ammonia supply system may be connected to the bleeding pipe 153 in the final stage. Even in this case, a flow rate adjusting valve, a shutoff valve, and a flow meter are interposed in the piping.

Ammonia introduced into the bleeding pipes 150, 151 and 152 flows into the hollow portions 135 of the stationary blades 130, 131 and 132 together with the cooling air. Then, the air-fuel mixture of ammonia and cooling air cools the vanes 130, 131, and 132 from the inside. Further, the air-fuel mixture is ejected from the ejection holes 136 of the stationary blades 130, 131 and 132 into the combustion gas flowing in the turbine 23.

Here, the system for ejecting ammonia into the combustion gas functions as an ammonia ejection unit. Here, the ammonia supply system, the air extraction pipe into which ammonia is introduced, the stationary blade into which ammonia is introduced, and the ejection hole 136 of the stationary blade into which ammonia is introduced function as an ammonia ejection portion.

Here, by ejecting ammonia into the combustion gas, denitration in the above-mentioned non-catalytic selective reduction method is attempted. Therefore, in order to increase the denitration rate, as described above, it is preferable that ammonia is ejected into the combustion gas having a temperature of 800 to 1100 ° C. The temperature of 800 to 1100 ° C. functions as the first temperature.

Therefore, the stationary blade to which ammonia is supplied together with the cooling air is a stationary blade of the turbine paragraph in which the temperature of the combustion gas is in the above range. That is, ammonia is introduced into the bleeding pipe that supplies cooling air to the vanes of the turbine paragraph where the temperature of the combustion gas is in the above range.

Here, the input / output means in the control device 80 is, for example, a flow control valve 25a, 26a, 160a, 161a, 162a, a shutoff valve 25b, 26b, 160b, 161b, 162b, a flow meter 25c, 26c, 160c, 161c, 162c. , Temperature detectors 27, 170, 171, gas analyzer (not shown), drive angle detector for inlet guide blade of compressor 21 (not shown), output input controller, generator 60, etc. It is connected as possible.

Here, the turbine paragraph in which the temperature of the combustion gas is 800 to 1100 ° C. is specified, for example, as follows.

The control device 80 calculates the air flow rate sucked by the compressor 21 based on the output signal from the drive angle detection device of the inlet guide blade of the compressor 21. Further, the control device 80 detects the temperature of the compressed air in the discharge portion of the compressor 21 based on the output signal from the temperature detector 170.

Further, the control device 80 determines the flow rate of ammonia introduced into the combustor liner 110 based on the output signal of the flow meter 25c, and the gas fuel introduced into the combustor liner 120 based on the output signal of the flow meter 26c. Calculate the flow rate. Further, the control device 80 detects the temperature of the combustion gas at the outlet of the turbine 23 based on the output signal from the temperature detector 171.

The control device 80 calculates the temperature of the combustion gas at the inlet of the turbine 23 based on the calculated air flow rate, the temperature of the compressed air at the discharge portion of the compressor 21, the flow rate of ammonia, and the flow rate of the gas fuel.

Subsequently, the control device 80 determines the temperature distribution of the combustion gas in each turbine paragraph in the turbine 23 based on the calculated temperature of the combustion gas at the inlet of the turbine 23 and the detected temperature of the combustion gas at the outlet of the turbine 23. Is calculated. The temperature distribution of the combustion gas also changes depending on the operating state of the gas turbine.

Then, the control device 80 identifies the turbine paragraph in which the temperature of the combustion gas is 800 to 1100 ° C. from the calculated temperature distribution of the combustion gas.

The control device 80 opens a flow control valve and a shutoff valve provided in a pipe that supplies ammonia to the identified turbine paragraph. At that time, the control device 80 controls the flow rate adjusting valve to adjust the ammonia introduced into the bleeding pipe to a predetermined flow rate.

For example, when the control device 80 determines in the first stage turbine paragraph that the combustion gas is in the above temperature range, the control device 80 opens the shutoff valve 160b and controls the flow rate control valve 160a.

At this time, the flow rate of ammonia introduced into the bleeding pipe 150 is calculated by the same method as when setting the flow rate of ammonia ejected from the ammonia ejection nozzle 32 described in the first embodiment.

That is, the control device 80 calculates the amount of NOx contained in the combustion gas at the inlet of the exhaust heat recovery boiler 30. Then, the control device 80 controls the flow rate adjusting valve 160a so as to introduce the calculated amount of NOx and the equimolar amount of ammonia into the bleeding pipe 150. The flow rate of ammonia introduced into the bleeding pipe 150 is adjusted based on, for example, the output signal of the flow meter 160c.

Here, the action of the combustion gas discharged from the combustor 22C will be described.

Here, a case where the turbine paragraph in which the temperature of the combustion gas is 800 to 1100 ° C. is the first stage turbine paragraph will be described.

The combustion gas discharged from the combustor 22C is guided into the turbine 23. The combustion gas guided into the turbine 23 drives the turbine 23.

At this time, ammonia is introduced together with the cooling air into the hollow portion 135 of the stationary blade 130 of the turbine paragraph where the temperature of the combustion gas becomes 800 to 1100 ° C. The cooling air and ammonia are ejected from the ejection holes 136 of the vane 130 into the combustion gas flowing in the turbine.

As described above, in the gas turbine 20C, ammonia can be ejected into the combustion gas in the temperature range where the denitration rate is high in the catalytically selective reduction method. As a result, NOx contained in the combustion gas can be reduced to nitrogen and water.

Here, as shown in FIG. 6, the denitration rate in the catalyst-free selective reduction method is about 60% at the highest. Therefore, the combustion gas discharged from the turbine 23 contains NOx. Further, from the turbine 23, along with the combustion gas, ammonia that could not contribute to the reduction is also discharged.

The combustion gas and ammonia discharged from the turbine 23 flow into the exhaust heat recovery boiler 30, which also functions as an exhaust passage. The combustion gas and ammonia that have flowed into the exhaust heat recovery boiler 30 are heat-exchanged by the superheater 31 to lower the temperature. As described above, the denitration catalyst 33 is arranged at a position where the combustion gas having a temperature of 300 to 400 ° C. flows. This temperature is a temperature at which denitration by the selective catalytic reduction method is promoted. The temperature of 300 to 400 ° C. functions as a second temperature.

As a result, when the combustion gas containing ammonia comes into contact with the denitration catalyst 33, the denitration action according to the above-mentioned formula (3) using ammonia as a reducing agent is mainly promoted. As a result, the remaining ammonia and NOx are decomposed into water vapor and nitrogen.

Then, the combustion gas discharged from the exhaust heat recovery boiler 30 is discharged into the atmosphere from the chimney 70.

As described above, in the thermal power generation facility 11 including the gas turbine 20C of the third embodiment, denitration and exhaust heat recovery by a catalytically selective reducing method using ammonia as a reducing agent in a predetermined turbine section of the turbine 23. Denitration can be performed in the boiler 30 by a selective catalytic reduction method using ammonia as a reducing agent.

In this way, a part of NOx can be reduced in the denitration treatment in the turbine 23. As a result, the load of the denitration treatment using the denitration catalyst 33 in the exhaust heat recovery boiler 30 can be reduced. Therefore, the contact area of the denitration catalyst 33 can be reduced as compared with the case where all denitration is performed by the selective contact reduction method using the denitration catalyst 33. As a result, the product cost can be reduced and the product can be miniaturized.

Further, as the combustor 22C of the gas turbine 20C of the third embodiment, the combustor 22A of the first embodiment or the combustor 22B of the second embodiment is provided. Therefore, the action and effect of the combustor 22C is the same as the action and effect of the combustor 22A and the combustor 22B, respectively.

In the gas turbine 20C of the third embodiment, an example is shown in which ammonia is ejected together with the cooling air from the ejection holes 136 of the stationary blades 130, 131, 132, but the present invention is not limited to this configuration.

For example, in a gas turbine, cooling air is also introduced into the hollow blades 140, 141, 142, and 143, and the cooling air is ejected from the ejection holes. Therefore, ammonia may be introduced into the cooling air introduced into the moving blades 140, 141, 142, 143. Also in this case, ammonia is introduced into the rotor blades of the turbine paragraph where the temperature of the combustion gas is 800 to 1100 ° C.

Further, for example, an ejection hole for ejecting ammonia may be formed on the outer peripheral wall supporting the stationary blades 130, 131, 132, 133. In this case, for example, ammonia is ejected into the combustion gas flowing between the stationary blades.

In the above-described embodiment, a combined cycle thermal power generation facility in which a gas turbine and a steam turbine are combined has been described as an example, but the present invention is not limited to this configuration.

For example, it may be a thermal power generation facility provided with a gas turbine and a denitration device using a selective contact reduction method. In this case, the denitration device may be provided in the exhaust passage of the gas turbine. The denitration catalyst in the denitration device is preferably installed in a region where it comes into contact with the combustion gas having a temperature of 300 to 400 ° C.

According to the embodiment described above, it is possible to suppress the generation of _{NOx and CO 2.}

Although some embodiments of the present invention have been described, these embodiments are presented as examples and are not intended to limit the scope of the invention. These novel embodiments can be implemented in various other embodiments, and various omissions, replacements, and changes can be made without departing from the gist of the invention. These embodiments and modifications thereof are included in the scope and gist of the invention, and are also included in the scope of the invention described in the claims and the equivalent scope thereof.

10, 11 ... Thermal power generation equipment, 20A, 20B, 20C ... Gas turbine, 21 ... Compressor, 22A, 22B, 22C ... Combustor, 23 ... Turbine, 24 ... Air filter, 25 ... Ammonia supply pipe, 25a, 26a, 36a, 160a ... Flow control valve, 25b, 26b, 36b, 160b ... Shutoff valve, 25c, 26c, 36c, 160c ... Flow meter, 26 ... Gas fuel supply pipe, 27, 170, 171 ... Temperature detector, 30 ... Exhaust Heat recovery boiler, 31 ... Superheater, 32 ... Ammonia ejection nozzle, 33 ... Denitration catalyst, 34 ... Evaporator, 35 ... Combustor, 36, 160 ... Piping, 37 ... Sampling probe, 40 ... Steam turbine, 50 ... Restoration Water device, 51 ... water pump, 60 ... generator, 70 ... chimney, 80 ... control device, 100 ... combustor casing, 101 ... space, 110, 120 ... combustor liner, 110A ... upstream combustor liner, 110B ... Downstream combustor liner, 111, 112, 113, 121, 122 ... Air inlet, 130, 131, 132, 133 ... Static blade, 135 ... Hollow part, 136 ... Ejection hole, 140, 141, 142, 143 ... Dynamic Wings, 150, 151, 152, 153 ... Extraction tube.

Claims (8)

A first combustor liner, in which air and ammonia are introduced and the hydrogen produced by the thermal decomposition of ammonia is burned to maintain the temperature of the combustion gas at 800-1100 ° C.
A combustion apparatus including a second combustor liner connected to a downstream end of the first combustor liner and into which gas fuel and air, which are mainly free of nitrogen compounds, are introduced. A temperature detection unit that detects the temperature inside the first combustor liner, and
A flow rate adjusting valve that adjusts the flow rate of ammonia introduced into the first combustor liner, and
The combustion apparatus according to claim 1, further comprising a control unit that controls the flow rate adjusting valve based on an output signal from the temperature detection unit. The first combustor liner
With the upstream combustor liner,
A downstream combustor liner connected to the downstream end of the upstream combustor liner is provided.
In the upstream combustor liner, air and ammonia are introduced to burn hydrogen generated by the thermal decomposition of ammonia.
In the downstream combustor liner, air is introduced, Rutoto is burned hydrogen produced by the thermal decomposition of ammonia monitor of claim 1, wherein the reducing NOx by non-catalytic selective reduction combustion Device. A temperature detection unit that detects the temperature inside the downstream combustor liner, and
A flow rate adjusting valve that adjusts the flow rate of ammonia introduced into the upstream combustor liner,
The combustion apparatus according to claim 3, further comprising a control unit that controls the flow rate adjusting valve based on an output signal from the temperature detection unit. The flow rate of air introduced into the upstream combustor liner is smaller than the flow rate of air forming a theoretical mixture with hydrogen produced by thermal decomposition of ammonia introduced into the upstream combustor liner. The combustion apparatus according to claim 3 or 4. A first combustor liner, in which air and ammonia are introduced and the hydrogen produced by the thermal decomposition of ammonia is burned to maintain the temperature of the combustion gas at 800-1100 ° C.
A second combustor liner, which is connected to the downstream end of the first combustor liner and into which gas fuel and air mainly containing no nitrogen compound are introduced.
A turbine into which the combustion gas discharged from the second combustor liner is introduced, and
In the turbine paragraph of the turbine where the temperature of the combustion gas is the first temperature, an ammonia ejection part that ejects ammonia and an ammonia ejection part
A gas turbine comprising a denitration catalyst arranged in an exhaust passage in which the temperature of the combustion gas passing through the turbine becomes a second temperature. The gas turbine according to claim 6, wherein an ejection hole for ejecting ammonia is formed in a stationary blade in the ammonia ejection portion. A compressor that supplies air to the first combustor liner and the second combustor liner, and
An air flow rate detection unit that detects the air flow rate sucked from the inlet of the compressor, and
An air temperature detector that detects the air temperature at the outlet of the compressor,
An ammonia flow rate detector that detects the flow rate of ammonia introduced into the first combustor liner, and
A gas fuel flow rate detector for detecting the flow rate of the gas fuel introduced into the second combustor liner, and a gas fuel flow rate detector.
An outlet gas temperature detector that detects the temperature of the combustion gas at the outlet of the turbine, and
Based on the output signals from the air flow rate detection unit, the air temperature detection unit, the ammonia flow rate detection unit, the gas fuel flow rate detection unit, and the outlet gas temperature detection unit, the turbine paragraph for ejecting ammonia is determined. The gas turbine according to claim 6 or 7, further comprising a control unit for controlling the ammonia ejection unit.

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