Operating method for a gas turbine facility, control device for executing this operating method, and control program

Abstract

A device for controlling gas turbine equipment comprises: a combustion load command generator that determines a combustion load command value, which is a parameter having a positive correlation with an inlet temperature, which is the temperature of combustion gas at an inlet of a turbine; a flow rate ratio calculator that determines a flow rate ratio of fuel supplied to each of a plurality of types of nozzles of a combustor in accordance with the combustion load command value; and a valve opening degree calculator that determines the valve opening degree of a fuel valve for each of the plurality of types of nozzles on the basis of the flow rate ratio of the fuel supplied to each of the plurality of types of nozzles. The combustion load command generator has: a first load command calculation unit that determines the combustion load command value for a first fuel, which is a fuel type indicated by a fuel type command; and a second load command calculation unit that determines the combustion load command value for a second fuel, which is a fuel type indicated by a fuel type command.

Description

Technical Field

[0001] The present disclosure relates to an operation method of a gas turbine facility, a control device, and a control program for executing this operation method. This application claims priority based on Japanese Patent Application No. 2022-050338 filed in Japan on March 25, 2022, and incorporates the content herein by reference.

Background Art

[0002] A gas turbine includes a compressor capable of compressing air to generate compressed air, a combustor capable of burning fuel in the compressed air to generate combustion gas, a turbine drivable by the combustion gas, and a fuel valve for adjusting the flow rate of fuel supplied to the combustor. The combustor has a nozzle for injecting fuel.

[0003] Patent Document 1 below discloses a gas turbine and its control method. The combustor of this gas turbine has a plurality of types of nozzles for injecting fuel such as natural gas. For each of these plurality of types of nozzles, a fuel valve for adjusting the flow rate of fuel flowing through each nozzle is provided.

[0004] In the control method described in this Patent Document 1, from the viewpoints of protecting the gas turbine and stabilizing the gas turbine output, a combustion load command value (CLCSO), which is a parameter having a positive correlation with the turbine inlet temperature, is obtained, and based on this combustion load command value, the flow rate ratio of fuel supplied to each of the plurality of types of nozzles is determined.

[0005] Also, Patent Document 2 below discloses a nozzle of a combustor capable of ejecting natural gas and oil.

Prior Art Documents

Patent Documents

[0006]

Patent Document 1

Patent Document 2

Summary of the Invention

Problems to be Solved by the Invention

[0007] In recent years, from the viewpoint of stable power supply, it has been required to enable a gas turbine to supply a plurality of types of fuels.

[0008] Therefore, an object of the present disclosure is to provide a technique capable of stably burning fuel even when the performance of a gas turbine deteriorates when a plurality of types of fuels are used.

Means for Solving the Problems

[0009] A control device for a gas turbine facility as one aspect for achieving the above object is applied to the following gas turbine facility. This gas turbine facility includes a compressor capable of compressing air to generate compressed air, a combustor capable of burning fuel in the compressed air to generate combustion gas, a gas turbine having a turbine drivable by the combustion gas, and a plurality of types of fuel valves for adjusting the flow rate of fuel supplied to the combustor. The combustor has a plurality of types of nozzles for injecting fuel. Each of the plurality of types of fuel valves is provided for each of the plurality of types of nozzles. This control device includes a combustion load command generator for obtaining a combustion load command value which is a parameter having a positive correlation with the inlet temperature which is the temperature of the combustion gas at the inlet of the turbine, a flow rate ratio calculator for obtaining a flow rate ratio of fuel supplied to each of the plurality of types of nozzles according to the combustion load command value, a valve opening calculator for obtaining a valve opening of the fuel valve for each of the plurality of types of nozzles based on the flow rate ratio of fuel supplied to each of the plurality of types of nozzles, and a control signal outputter for outputting a control signal indicating the valve opening to the fuel valve for each of the plurality of types of nozzles. The combustion load command generator includes a first load command calculation unit that obtains the combustion load command value for a first fuel, which is the fuel type indicated by a fuel type command from the outside, and a second load command calculation unit that obtains the combustion load command value for a second fuel, which is the fuel type indicated by a fuel type command from the outside. Both the first load command calculation unit and the second load command calculation unit include a maximum temperature output calculation unit that obtains a maximum temperature output, which is a planned output corresponding to the fuel type, with respect to an inlet maximum temperature, which is the highest temperature at which the inlet temperature is predetermined; a minimum temperature output calculation unit that obtains a minimum temperature output, which is a planned output corresponding to the fuel type, with respect to an inlet minimum temperature, which is the lowest temperature at which the inlet temperature is predetermined; a deterioration coefficient calculation unit that obtains a deterioration coefficient for correcting the maximum temperature output; a deterioration correction unit that corrects the maximum temperature output using the deterioration coefficient; and a combustion load command value calculation unit that obtains the combustion load command value using the minimum temperature output, the corrected maximum temperature output, which is the maximum temperature output corrected by the deterioration correction unit, and the actual output, which is the actual output of the gas turbine. The deterioration coefficient calculation unit includes a differentiator that obtains a deviation between the corrected maximum temperature output and the actual output, and a coefficient calculator that obtains the deterioration coefficient according to the deviation during temperature control in which the inlet temperature is controlled to be the inlet maximum temperature. The coefficient calculator includes a deterioration parameter storage unit that stores a deterioration parameter, which is a value obtained by performing proportional-integral processing on a ratio of the deviation when the deviation is equal to or greater than a predetermined threshold during the temperature control. The coefficient calculator outputs the deterioration coefficient based on the deterioration parameter stored in the deterioration parameter storage unit.

[0010] In this aspect, it is possible to obtain a combustion load command value considering the performance deterioration of the gas turbine both when using the first fuel and when using the second fuel. For this reason, in this aspect, it is possible to obtain a flow rate ratio for each of a plurality of fuel valves considering the performance deterioration of the gas turbine both when using the first fuel and when using the second fuel. Therefore, in this aspect, even when the performance of the gas turbine deteriorates both when using the first fuel and when using the second fuel, the fuel can be stably combusted.

[0011] Also, in this aspect, even immediately after the control device receives a fuel type command indicating a combustion type different from the current fuel type, the degradation coefficient can be obtained using the degradation parameters stored in the degradation parameter storage unit. Therefore, in this aspect, even immediately after the control device receives a new fuel type command, the degradation coefficient can reflect the degree of performance degradation of the gas turbine, and stable combustion of the fuel can be achieved.

[0012] As one aspect for achieving the above object, the control program for the gas turbine facility is applied to the following gas turbine facility. This gas turbine facility includes a compressor capable of compressing air to generate compressed air, a combustor capable of burning fuel in the compressed air to generate combustion gas, a gas turbine having a turbine drivable by the combustion gas, and a plurality of types of fuel valves for adjusting the flow rate of fuel supplied to the combustor. The combustor has a plurality of types of nozzles for injecting fuel. Each of the plurality of types of fuel valves is provided for each of the plurality of types of nozzles. This control program causes a computer to execute a combustion load command generation step of obtaining a combustion load command value, which is a parameter having a positive correlation with the inlet temperature, which is the temperature of the combustion gas at the inlet of the turbine; a flow rate ratio calculation step of obtaining a flow rate ratio of fuel supplied to each of the plurality of types of nozzles according to the combustion load command value; a valve opening degree calculation step of obtaining the valve opening degree of the fuel valve for each of the plurality of types of nozzles based on the flow rate ratio of fuel supplied to each of the plurality of types of nozzles; and a control signal output step of outputting a control signal indicating the valve opening degree to the fuel valve for each of the plurality of types of nozzles. The combustion load command generation process includes a first load command calculation step of obtaining the combustion load command value for a first fuel which is the fuel type indicated by a fuel type command from the outside, and a second load command calculation step of obtaining the combustion load command value for a second fuel which is the fuel type indicated by the fuel type command from the outside. Both the first load command calculation step and the second load command calculation step include a maximum temperature output calculation step of obtaining a maximum temperature output which is a planned output according to the fuel type with respect to an inlet maximum temperature which is the highest temperature determined in advance for the inlet temperature, a minimum temperature output calculation step of obtaining a minimum temperature output which is a planned output according to the fuel type with respect to an inlet minimum temperature which is the lowest temperature determined in advance for the inlet temperature, a deterioration coefficient calculation step of obtaining a deterioration coefficient for correcting the maximum temperature output, a deterioration correction step of correcting the maximum temperature output using the deterioration coefficient, a combustion load command value calculation step of obtaining the combustion load command value using the minimum temperature output, the corrected maximum temperature output which is the maximum temperature output corrected in the deterioration correction step, and the actual output which is the actual output of the gas turbine. The deterioration coefficient calculation step includes a deviation calculation step of obtaining a deviation between the corrected maximum temperature output and the actual output, and a coefficient calculation step of obtaining the deterioration coefficient according to the deviation during temperature control in which the inlet temperature is controlled to be the inlet maximum temperature. The coefficient calculation step includes a deterioration parameter storage step of storing, in a deterioration parameter storage unit which is a part of the storage area of the computer, a deterioration parameter which is a value obtained by proportional integral processing with respect to a ratio of the deviation when the deviation is equal to or greater than a predetermined threshold during the temperature control. In the coefficient calculation step, the deterioration coefficient based on the deterioration parameter stored in the deterioration parameter storage unit is output.

[0013] By causing a computer to execute the control program of this aspect, similar to the control device in the first aspect, even when the performance of the gas turbine deteriorates in both the case of using the first fuel and the case of using the second fuel, stable combustion of the fuel can be achieved.

[0014] Furthermore, by causing a computer to execute the control program of the present aspect, similar to the control device in the first aspect, even immediately after receiving a new fuel type command, the deterioration coefficient can reflect the degree of performance deterioration of the gas turbine, and stable combustion of the fuel can be achieved.

[0015] As one aspect for achieving the above object, an operation method of a gas turbine facility is applied to the following gas turbine facility. This gas turbine facility includes a compressor capable of compressing air to generate compressed air, a combustor capable of burning fuel in the compressed air to generate combustion gas, a gas turbine including a turbine drivable by the combustion gas, and a plurality of types of fuel valves for adjusting the flow rate of fuel supplied to the combustor. The combustor has a plurality of types of nozzles for injecting fuel. Each of the plurality of types of fuel valves is provided for each of the plurality of types of nozzles. In this operation method, a combustion load command generation step of obtaining a combustion load command value, which is a parameter having a positive correlation with the inlet temperature, which is the temperature of the combustion gas at the inlet of the turbine, a flow rate ratio calculation step of obtaining the flow rate ratio of the fuel supplied to each of the plurality of types of nozzles according to the combustion load command value, a valve opening degree calculation step of obtaining the valve opening degree of the fuel valve for each of the plurality of types of nozzles based on the flow rate ratio of the fuel supplied to each of the plurality of types of nozzles, and a control signal output step of outputting a control signal indicating the valve opening degree to the fuel valve for each of the plurality of types of nozzles are executed. The combustion load command generation process includes a first load command calculation step of obtaining the combustion load command value for a first fuel which is the fuel type indicated by a fuel type command from the outside, and a second load command calculation step of obtaining the combustion load command value for a second fuel which is the fuel type indicated by the fuel type command from the outside. Both the first load command calculation step and the second load command calculation step include a maximum temperature output calculation step of obtaining a maximum temperature output which is a planned output according to the fuel type with respect to an inlet maximum temperature which is the highest temperature determined in advance for the inlet temperature, a minimum temperature output calculation step of obtaining a minimum temperature output which is a planned output according to the fuel type with respect to an inlet minimum temperature which is the lowest temperature determined in advance for the inlet temperature, a degradation coefficient calculation step of obtaining a degradation coefficient for correcting the maximum temperature output, a degradation correction step of correcting the maximum temperature output using the degradation coefficient, a combustion load command value calculation step of obtaining the combustion load command value using the minimum temperature output, the corrected maximum temperature output which is the maximum temperature output corrected in the degradation correction step, and the actual output which is the actual output of the gas turbine. The degradation coefficient calculation step includes a deviation calculation step of obtaining a deviation between the corrected maximum temperature output and the actual output, and a coefficient calculation step of obtaining the degradation coefficient according to the deviation during temperature control when the inlet temperature is controlled to be the inlet maximum temperature. The coefficient calculation step includes a degradation parameter storage step of storing, in a degradation parameter storage unit, a degradation parameter which is a value obtained by proportional integral processing with respect to a ratio of the deviation when the deviation is equal to or greater than a predetermined threshold during the temperature control. In the coefficient calculation step, the degradation coefficient based on the degradation parameter stored in the degradation parameter storage unit is output.

[0016] Also in this aspect, similar to the control device in the first aspect, even when the performance of the gas turbine deteriorates both when using the first fuel and when using the second fuel, the fuel can be stably combusted.

[0017] Furthermore, also in this aspect, similar to the control device in the first aspect, even immediately after receiving a new fuel type command, the degradation coefficient can reflect the degree of performance degradation of the gas turbine, and the fuel can be stably combusted.

Advantages of the Invention

[0018] In one aspect of the present disclosure, when using multiple types of fuels, even if the performance of the gas turbine deteriorates, the fuel can be stably combusted.

Brief Description of the Drawings

[0019]

Figure 1

Figure 2

Figure 3

Figure 4

Figure 5

Figure 6

Figure 7

Figure 8

Figure 9

Figure 10

Figure 11

Figure 12

Figure 13

Figure 14

Figure 15

Figure 16

Figure 17

Mode for Carrying Out the Invention

[0020] Hereinafter, various embodiments according to the present disclosure will be described with reference to the drawings.

[0021] 「Embodiment of Gas Turbine Facility」 An embodiment of a control device according to the present disclosure and a gas turbine facility including this control device will be described with reference to FIGS. 1 to 14.

[0022] As shown in FIG. 1, the gas turbine facility of the present embodiment includes a gas turbine 10, a generator 29 that generates electricity by being driven by the gas turbine 10, a plurality of types of fuel valves 65, 66, 67, a plurality of fuel switching valves 61f, 61s, and a control device 100 that controls the operation of the gas turbine 10.

[0023] The gas turbine 10 includes a compressor 11 that can compress air A to generate compressed air Ac, a combustor 31 that can burn fuel F in the compressed air Ac from the compressor 11 to generate combustion gas, and a turbine 21 that can be driven by the high-temperature and high-pressure combustion gas.

[0024] The compressor 11 has a compressor rotor 13 that rotates about an axis Ar, a compressor casing 12 that rotatably covers the compressor rotor 13, and an IGV (inlet guide vane) 14 provided at an inlet of the compressor casing 12. The IGV 14 has a plurality of guide vanes 15 and a driver 16 that drives the plurality of guide vanes 15. The IGV 14 adjusts the flow rate of air sucked into the compressor casing 12.

[0025] The turbine 21 includes a turbine rotor 23 that rotates about the axis Ar by combustion gas from the combustor 31, and a turbine casing 22 that rotatably covers the turbine rotor 23. The turbine rotor 23 and the compressor rotor 13 are rotatably connected to each other about the same axis Ar to form a gas turbine rotor 28. The rotor of the generator 29 is connected to the gas turbine rotor 28.

[0026] The gas turbine 10 further includes an intermediate casing 24 and an exhaust casing 25. The intermediate casing 24 is disposed between the compressor casing 12 and the turbine casing 22 in the direction in which the axis Ar extends, and connects the compressor casing 12 and the turbine casing 22. Compressed air Ac discharged from the compressor 11 flows into the intermediate casing 24. The exhaust casing 25 is disposed on the side opposite to the side where the intermediate casing 24 is disposed with respect to the turbine casing 22. Exhaust gas Ex, which is combustion gas exhausted from the turbine 21, flows into the exhaust casing 25.

[0027] The combustor 31 is fixed to the intermediate casing 24. As shown in FIG. 2, the combustor 31 includes an outer cylinder 32 fixed to the intermediate casing 24, a combustion cylinder (or tail cylinder) 33 disposed in the intermediate casing 24 and sending combustion gas into the combustion gas flow path of the turbine 21, and a fuel injector 41 that injects fuel and air into the combustion cylinder 33.

[0028] As shown in FIGS. 2 and 3, the fuel injector 41 includes an inner cylinder 42, a pilot burner 43 disposed on the central axis Ak of the inner cylinder 42, a plurality of main burners 53 disposed at equal intervals in the circumferential direction around the pilot burner 43, and a top hat nozzle 51 disposed on the outer peripheral side of the inner cylinder 42 on the inner peripheral side of the outer cylinder 32. Hereinafter, in the direction in which the central axis Ak of the inner cylinder 42 extends, the side in the combustion cylinder 33 where the combustion gas G flows is defined as the downstream side, and the opposite side is defined as the upstream side.

[0029] The pilot burner 43 has a pilot nozzle 44 disposed on the central axis Ak of the inner cylinder 42, and a cylindrical pilot air cylinder 45 surrounding the outer periphery of the pilot nozzle 44. The downstream side of the pilot air cylinder 45 forms a pilot cone 46 whose diameter gradually increases toward the downstream side. On the inner peripheral side of the pilot air cylinder 45, there is a pilot air flow path 48 through which the compressed air Ac from the compressor 11 flows as pilot air Ap. The pilot fuel Fp injected from the pilot nozzle 44 burns (diffusion combustion) in the pilot air Ap ejected from the pilot air flow path 48 to form a diffusion flame 49.

[0030] The main burner 53 has a cylindrical main air inner cylinder 55 surrounding the outer periphery of the pilot air cylinder 45, a cylindrical main air outer cylinder 56 surrounding the outer periphery of the main air inner cylinder 55, a partition plate 57 that divides the annular space between the outer peripheral side of the main air inner cylinder 55 and the inner peripheral side of the main air outer cylinder 56 into a plurality in the circumferential direction, and a main nozzle 54 disposed between the plurality of partition plates 57. The plurality of spaces defined by the main air inner cylinder 55, the main air outer cylinder 56, and the plurality of partition plates 57 form a main air flow path 58 through which the compressed air Ac from the compressor 11 flows as main air Am. Main fuel Fm is injected into the main air Am flowing through this main air flow path 58 from the main nozzle 54 disposed in the main air flow path 58. Therefore, on the downstream side of the tip (downstream end) of the main nozzle 54 in the main air flow path 58, a premixed gas in which the main air Am and the main fuel Fm are mixed flows. When this premixed gas flows out of the main air flow path 58, it burns (premixed combustion) to form a premixed flame 59. The aforementioned diffusion flame 49 serves to hold the premixed flame 59.

[0031] The space between the inner peripheral side of the outer cylinder 32 and the outer peripheral side of the inner cylinder 42 forms a compressed air flow path 52 that guides the compressed air Ac from the compressor 11 into the inner cylinder 42. The top hat nozzle 51 injects the top hat fuel Ft into this compressed air flow path 52. Therefore, when the top hat fuel Ft is injected into the compressed air flow path 52, the top hat fuel Ft is mixed into the main air Am and the pilot air Ap.

[0032] As shown in FIG. 1, the gas turbine facility of the present embodiment further includes a first fuel line 60f through which the first fuel Ff flows, a second fuel line 60s through which the second fuel Fs flows, an integrated fuel line 60 through which one of the first fuel Ff and the second fuel Fs flows, a pilot fuel line 62, a main fuel line 63, and a top hat fuel line 64. One end of the integrated fuel line 60 is connected to the first fuel line 60f and the second fuel line 60s. The second fuel Fs is a fuel having a composition different from that of the first fuel Ff. For example, the first fuel Ff is natural gas, and the second fuel Fs is oil. The pilot fuel line 62, the main fuel line 63, and the top hat fuel line 64 are all lines branched from the integrated fuel line 60. The pilot fuel line 62 is connected to the pilot nozzle 44. The main fuel line 63 is connected to the main nozzle 54. The top hat fuel line 64 is connected to the top hat nozzle 51.

[0033] Examples of the plurality of fuel switching valves 61f, 61s include a first fuel switching valve 61f and a second fuel switching valve 61s. The first fuel switching valve 61f is provided in the first fuel line 60f. The second fuel switching valve 61s is provided in the second fuel line 60s.

[0034] Examples of the plurality of fuel valves 65, 66, 67 include a pilot fuel valve 65, a main fuel valve 66, and a top hat fuel valve 67. The pilot fuel valve 65 is provided in a pilot fuel line 62 and is capable of adjusting the flow rate of fuel flowing through the pilot fuel line 62. The main fuel valve 66 is provided in a main fuel line 63 and is capable of adjusting the flow rate of fuel flowing through the main fuel line 63. The top hat fuel valve 67 is provided in a top hat fuel line 64 and is capable of adjusting the flow rate of fuel flowing through the top hat fuel line 64.

[0035] As shown in FIG. 1, the gas turbine facility of the present embodiment further includes a tachometer 71 that detects the rotational speed N of the gas turbine rotor 28, an output meter 72 that detects the output PW of the generator 29, an intake air temperature meter 73 that detects the intake air temperature Ti, which is the temperature of the air A sucked in by the compressor 11, an intake air pressure meter 74 that detects the intake air pressure (atmospheric pressure) Pi, which is the pressure of the air sucked in by the compressor 11, a blade path temperature meter 75 that detects the blade path temperature Tb, which is the temperature of the combustion gas immediately after the final stage of the turbine 21, and an exhaust gas temperature meter 76 that detects the exhaust gas temperature Te in the exhaust casing 25 on the downstream side of the final stage of the turbine 21. The output PW of the generator 29 detected by the output meter 72 is the actual output of the gas turbine 10.

[0036] The control device 100 is a computer. Hardware-wise, as shown in FIG. 4, the control device 100 includes a computer main body 110, an input device 101 such as a keyboard and a mouse, and a display device 102. The computer main body includes a CPU (Central Processing Unit) 111 that performs various operations, a main storage device 112 such as a memory that serves as a work area for the CPU 111, an auxiliary storage device 113 such as a hard disk drive device, a storage / playback device 115 that performs storage processing and playback processing of data with respect to a disk-type storage medium D, an input / output interface 116 for the input device 101 and the display device 102, a device interface 117, and a communication interface 118 for communicating with the outside via a network N.

[0037] The device interface 117 is connected to each of the detectors 71 to 76, the first fuel switching valve 61f, the second fuel switching valve 61s, the fuel valves 65, 66, 67, and the IGV 14 via signal lines or the like.

[0038] The auxiliary storage device 113 stores a control program 113p and the like in advance. This control program 113p is taken into the auxiliary storage device 113 from the disk-type storage medium D via, for example, the storage / playback device 115. Note that the control program 113p may be taken into the auxiliary storage device 113 from an external device via the communication interface 118. Each functional unit of the control device 100 described below functions when the CPU 111 executes the control program 113p stored in the auxiliary storage device 113.

[0039] Functionally, as shown in FIG. 5, the control device 100 includes a combustion load command generator 120 that generates a combustion load command value CLCSO, a fuel flow rate command generator 150 that generates a fuel flow rate command value CSO, a flow rate ratio calculator 160 that calculates the flow rate ratio (PLr, THr) of the fuel, a valve opening calculator 170 that obtains the valve opening degrees of the fuel valves 65, 66, 67, an IGV command generator 180 that generates an IGV command value IGVC indicating the opening degree of the IGV 14, and a control signal outputter 190 that outputs a control signal indicating a command value to a control target.

[0040] The combustion load command value CLCSO is a parameter obtained by non-dimensionalizing the temperature of the combustion gas at the inlet of the turbine 21 (hereinafter referred to as the inlet temperature), and is a parameter having a positive correlation with this inlet temperature. The combustion load command value CLCSO is set to 0% when the inlet temperature is the lower limit value and 100% when the inlet temperature is the upper limit value. For example, when the lower limit value (inlet minimum temperature) of the inlet temperature is 700°C and the upper limit value (inlet maximum temperature) of the inlet temperature is 1500°C, the combustion load command value CLCSO is expressed by the following formula.

[0041] CLCSO (%) = { (actual output of the gas turbine - 700°C MW) / (1500°C MW - 700°C MW)} × 100 ···· (1) Note that the actual output of the gas turbine is the actual gas turbine output detected by the output meter 72. 700°C MW is the planned gas turbine output when the inlet temperature is 700°C, which is the lower limit value. This 700°C MW is the inlet minimum temperature output. 1500°C MW is the planned gas turbine output when the inlet temperature is 1500°C, which is the upper limit value. This 1500°C MW is the inlet maximum temperature output.

[0042] In the above, the lower limit value of the inlet temperature of the combustion gas in the turbine 21 is 700°C and the upper limit value is 1500°C. However, depending on the type of the combustor 31 and the like, the lower limit value and the upper limit value of the inlet temperature of the combustion gas in the turbine 21 may be set to values different from the above examples.

[0043] As shown in FIG. 6, the combustion load command generator 120 includes a first load command calculation unit 121f that generates a combustion load command value CLCSO according to the first fuel Ff, and a second load command calculation unit 121s that generates a combustion load command value CLCSO according to the second fuel Fs.

[0044] Both the first load command calculation unit 121f and the second load command calculation unit 121s include a standard atmospheric pressure generator 122f, 122s, an intake pressure ratio calculator 123f, 123s, a degradation coefficient calculator 124f, 124s, a maximum temperature output calculator 131f, 131s, a minimum temperature output calculator 136f, 136s, a degradation correction unit 139f, 139s, and a combustion load command value calculator 140f, 140s.

[0045] Among the components of the first load command calculation unit 121f and the second load command calculation unit 121s described above, the components indicated by the symbols including "f" are the components of the first load command calculation unit 121f, and the components indicated by the symbols including "s" are the components of the second load command calculation unit 121s.

[0046] The standard atmospheric pressure generators 122f and 122s generate a standard intake pressure (standard atmospheric pressure) Ps. The intake pressure ratio calculators 123f and 123s obtain an intake pressure ratio Pr, which is the ratio of the intake pressure (atmospheric pressure) Pi detected by the intake pressure gauge 74 to the standard intake pressure Ps.

[0047] The maximum temperature output calculators 131f and 131s obtain a planned maximum temperature output of 1500 °C MW according to the fuel type. The maximum temperature output calculators 131f and 131s include a planned maximum temperature output generator 132f and 132s, a machine error correction coefficient generator 133f and 133s, a machine error corrector 134f and 134s, and an intake pressure corrector 135f and 135s.

[0048] The planned maximum temperature output generators 132f and 132s use the intake temperature Ti and the IGV command value IGVc as variable parameters, and use functions Hhf and Hhs according to the fuel type to obtain a planned maximum temperature output, which is the planned gas turbine output when the inlet temperature is 1500 °C. The machine error correction coefficient generators 133f and 133s generate a machine error correction coefficient. This machine error correction coefficient (gain) is the ratio of the gas turbine output when the inlet temperature of the actual gas turbine is 1500 °C to the planned maximum temperature output. This machine error correction coefficient is obtained during the trial operation of the actual gas turbine, etc. The machine error correctors 134f and 134s are multipliers that multiply the planned maximum temperature output by the machine error correction coefficient (gain) to correct the planned maximum temperature output. The intake pressure correctors 135f and 135s are multipliers that multiply the planned maximum temperature output after machine error correction by the intake pressure ratio Pr to further correct the planned maximum temperature output after machine error correction. The output from the intake pressure correctors 135f and 135s is the planned maximum temperature output of 1500 °C MW according to the fuel type.

[0049] The minimum temperature output calculators 136f and 136s obtain a planned minimum temperature output of 700 °C MW according to the fuel type. The minimum temperature output calculators 136f and 136s include a planned minimum temperature output generator 137f and 137s and an intake pressure corrector 138f and 138s.

[0050] The planned maximum temperature output generators 132f and 132s use the intake air temperature Ti and the IGV command value IGVc as variable parameters, and use the function Hl according to the fuel type to obtain the planned minimum temperature output, which is the designed gas turbine output when the inlet temperature is 700°C. The intake air pressure correctors 138f and 138s are multipliers that correct the planned minimum temperature output by multiplying the planned minimum temperature output by the intake air pressure ratio Pr. The output from this intake air pressure corrector 138f and 138s is the aforementioned planned minimum temperature output 700°C MW according to the fuel type.

[0051] The degradation coefficient calculation units 124f and 124s obtain a degradation coefficient k indicating the degree of output degradation of the gas turbine 10 due to the use of the gas turbine 10. The degradation correction units 139f and 139s are multipliers that correct the maximum temperature output 1500°C MW, which is the output from the maximum temperature output calculation units 131f and 131s, by multiplying it by the degradation coefficient k. The maximum temperature output corrected by this degradation correction unit 139f and 139s is the corrected maximum temperature output 1500°C MWr.

[0052] The degradation coefficient calculation units 124f and 124s include a differentiator 125f and 125s that obtains the deviation Δ between the actual output and the corrected maximum temperature output 1500°C MWr, a divider 126f and 126s that obtains the ratio of the deviation Δ with respect to the corrected maximum temperature output 1500°C MWr, a proportional-integral controller 127f and 127s that obtains a degradation parameter pm, which is a value obtained by performing proportional-integral processing on the output from the divider 126f and 126s, a fixed-value generator 128f and 128s that generates a fixed value of 1.0, and an adder 129f and 129s that adds the fixed value to the degradation parameter pm from the proportional-integral controller 127f and 127s. The proportional-integral controller 127f and 127s has a degradation parameter storage unit 127mf and 127ms. Note that the degradation parameter storage unit 127mf and 127ms is secured in a part of the main storage device 112 such as the memory shown in FIG. 4. This proportional-integral controller 127f and 127s stores the degradation parameter pm, which is a value obtained by performing proportional-integral processing on the output from the divider 126f and 126s, in the degradation parameter storage unit 127mf and 127ms, and outputs this degradation parameter pm. The degradation coefficient calculation units 124f and 124s output the output from the adder 129f and 129s as the degradation coefficient k.

[0053] In this embodiment, a coefficient calculator of the deterioration coefficient calculators 124f and 124s is constituted by the dividers 126f and 126s, the proportional-integral controllers 127f and 127s, the fixed-value generators 128f and 128s, and the adders 129f and 129s. The proportional-integral controllers 127f and 127s included in this coefficient calculator obtain the aforementioned deterioration parameter pm during temperature control for controlling the inlet temperature to be the inlet maximum temperature, and store this in the deterioration parameter storage units 127mf and 127ms. Suppose the actual output, which is the actual output of the gas turbine 10 detected by the output meter 72, is 90 MW, and the corrected maximum temperature output 1500 °C M Wr is 100 MW. Then, the differentiators 125f and 125s execute an operation of (90 - 100) and output -10 MW. The dividers 126f and 126s divide the output of -10 MW from the differentiators 125f and 125s by 100 MW, which is the corrected maximum temperature output 1500 °C M Wr, and output -0.1. The proportional-integral controllers 127f and 127s obtain the aforementioned deterioration parameter pm during temperature control for controlling the inlet temperature to be the inlet maximum temperature, and store this in the deterioration parameter storage units 127mf and 127ms. For example, if the deterioration parameter pm obtained by the proportional-integral controllers 127f and 127s is also -0.1, the adders 129f and 129s add the fixed value 1.0 from the fixed-value generators 128f and 128s to the deterioration parameter pm (-0.1), and output 0.9, which is the result of this addition, as the deterioration coefficient k.

[0054] The combustion load command value calculators 140f and 140s include the first differentiators 141f and 141s, the second differentiators 142f and 142s, the dividers 143f and 143s, the fixed-value generators 144f and 144s that generate a fixed value of 100, the multipliers 145f and 145s, and the limiters 146f and 146s.

[0055] The first differentiators 141f and 141s obtain the deviation between the actual output and the minimum temperature output of 700 °C MW. The value of the numerator in the above-mentioned formula (1) is obtained by this first differentiator 141f and 141s. The second differentiators 142f and 142s obtain the deviation between the corrected maximum temperature output of 1500 °C MWr and the minimum temperature output of 700 °C MW. The value of the denominator in the above-mentioned formula (1) is obtained by this second differentiator 142f and 142s. The dividers 143f and 143s divide the value of the numerator in the above-mentioned formula (1), which is the output from the first differentiators 141f and 141s, by the value of the denominator in the above-mentioned formula (1), which is the output from the second differentiators 142f and 142s. The multipliers 145f and 145s multiply the output from the dividers 143f and 143s by 100 from the fixed value generators 144f and 144s, and output this result as the combustion load command value CLCSO. The limiters 146f and 146s limit the rate of increase or decrease of the combustion load command value CLCSO so that the rate of change per unit time of the combustion load command value CLCSO from the multipliers 145f and 145s is equal to or less than a predetermined value.

[0056] Note that the machine difference correction coefficient generator 133f of the first load command calculation unit 121f is different from the machine difference correction coefficient generator 133s of the second load command calculation unit 121s. The machine difference correction coefficient generator 133f of the first load command calculation unit 121f generates a machine difference correction coefficient obtained when the gas turbine 10 is under a trial operation using the first fuel Ff. Also, the machine difference correction coefficient generator 133s of the second load command calculation unit 121s generates a machine difference correction coefficient obtained when the gas turbine 10 is under a trial operation using the second fuel Fs. The planned maximum temperature output generator 132f of the first load command calculation unit 121f is different from the planned maximum temperature output generator 132s of the second load command calculation unit 121s. The planned maximum temperature output generator 132f of the first load command calculation unit 121f uses a function Hhf corresponding to the first fuel Ff to obtain and generate the planned maximum temperature output when the inlet temperature is 1500°C. The planned minimum temperature output generator 137f of the first load command calculation unit 121f is different from the planned minimum temperature output generator 137s of the second load command calculation unit 121s. The planned minimum temperature output generator 137f of the first load command calculation unit 121f uses a function Hlf corresponding to the first fuel Ff to obtain and generate the planned minimum temperature output when the inlet temperature is 700°C. The planned minimum temperature output generator 137s of the second load command calculation unit 121s uses a function Hls corresponding to the second fuel Fs to obtain and generate the planned minimum temperature output when the inlet temperature is 700°C.

[0057] The fuel flow rate command value CSO is a value indicating the total flow rate of the fuel supplied to the combustor 31 (hereinafter referred to as the total fuel flow rate). Therefore, the fuel flow rate command generator 150 calculates the total fuel flow rate. As shown in FIG. 7, the fuel flow rate command generator 150 includes a first fuel flow rate command calculation unit 151f that generates a fuel flow rate command value CSO corresponding to the first fuel Ff, and a second fuel flow rate command calculation unit 151s that generates a fuel flow rate command value CSO corresponding to the second fuel Fs.

[0058] The first fuel flow rate command calculation unit 151f and the second fuel flow rate command calculation unit 151s both include a governor controller 152f, 152s, a load controller 153f, 153s, a blade path temperature controller 154f, 154s, an exhaust gas temperature controller 155f, 155s, a low value selector 156f, 156s, and a limiter 157f, 157s. Among the components of the first fuel flow rate command calculation unit 151f and the second fuel flow rate command calculation unit 151s described above, the components indicated by the symbols including "f" are the components of the first fuel flow rate command calculation unit 151f, and the components indicated by the symbols including "s" are the components of the second fuel flow rate command calculation unit 151s.

[0059] The governor controllers 152f, 152s include a target rotation speed generator 152gf, 152gs that generates a target rotation speed Nt, a rotation speed comparator 152cf, 152cs that compares the rotation speed N of the gas turbine rotor 28 from the rotation speed meter 71 with the target rotation speed Nt and outputs a comparison value according to the fuel type, and a proportional-integral controller 152pf, 152ps that performs proportional-integral calculation on the comparison value from the rotation speed comparator 152cf, 152cs. The governor controllers 152f, 152s output the output from this proportional-integral controller 152pf, 152ps as a command value GVCSO. This command value GVCSO is a command value indicating the total fuel flow rate for making the rotation speed N of the gas turbine rotor 28 the target rotation speed Nt.

[0060] The load controllers 153f, 153s include an output comparator 153cf, 153cs that compares the actual output PW of the gas turbine 10 from the output meter 72 with the required output PWr for the gas turbine 10 from the upper controller and outputs a comparison value according to the fuel type, and a proportional-integral controller 153pf, 153ps that performs proportional-integral calculation on the comparison value from the output comparator 153cf, 153cs. The load controllers 153f, 153s output the output from this proportional-integral controller 153pf, 153ps as a command value LDCSO. This command value LDCSO is a command value indicating the total fuel flow rate for making the actual output PW the required output PWr.

[0061] The blade path temperature controllers 154f and 154s include an upper limit value generator 154gf and 154gs that generate an upper limit value Tbu of the blade path temperature, a blade path temperature comparator 154cf and 154cs that compares the blade path temperature Tb from the blade path thermometer 75 with the upper limit value Tbu and outputs a comparison value according to the fuel type, and a proportional-integral controller 154pf and 154ps that performs a proportional-integral operation on the comparison value from the blade path temperature comparator 154cf and 154cs. The blade path temperature controllers 154f and 154s output the output from this proportional-integral controller 154pf and 154ps as a command value BPCSO. This command value BPCSO is a command value indicating the total fuel flow rate to prevent the blade path temperature Tb from exceeding the upper limit value Tbu.

[0062] The exhaust gas temperature controllers 155f and 155s include an upper limit value generator 155gf and 155gs that generate an upper limit value Teu of the exhaust gas temperature, an exhaust gas temperature comparator 155cf and 155cs that compares the exhaust gas temperature Te from the exhaust gas thermometer 76 with the upper limit value Teu and outputs a comparison value according to the fuel type, and a proportional-integral controller 155pf and 155ps that performs a proportional-integral operation on the comparison value from the exhaust gas temperature comparator 155cf and 155cs. The exhaust gas temperature controllers 155f and 155s output the output from this proportional-integral controller 155pf and 155ps as a command value EXCSO. This command value EXCSO is a command value indicating the total fuel flow rate to prevent the exhaust gas temperature Te from exceeding the upper limit value Teu.

[0063] Note that the rotation speed comparator 152cf of the first fuel flow rate command calculator 151f is different from the rotation speed comparator 152cs of the second fuel flow rate command calculator 151s. The rotation speed comparator 152cf of the first fuel flow rate command calculator 151f outputs a comparison value corresponding to the first fuel Ff, and the rotation speed comparator 152cs of the second fuel flow rate command calculator 151s outputs a comparison value corresponding to the second fuel Fs. The output comparator 153cf of the first fuel flow rate command calculator 151f is different from the output comparator 153cs of the second fuel flow rate command calculator 151s. The output comparator 153cf of the first fuel flow rate command calculator 151f outputs a comparison value corresponding to the first fuel Ff, and the output comparator 153cs of the second fuel flow rate command calculator 151s outputs a comparison value corresponding to the second fuel Fs. The blade path temperature comparator 154cf of the first fuel flow rate command calculator 151f is different from the blade path temperature comparator 154cs of the second fuel flow rate command calculator 151s. The blade path temperature comparator 154cf of the first fuel flow rate command calculator 151f outputs a comparison value corresponding to the first fuel Ff, and the blade path temperature comparator 154cs of the second fuel flow rate command calculator 151s outputs a comparison value corresponding to the second fuel Fs. The exhaust gas temperature comparator 155cf of the first fuel flow rate command calculator 151f is different from the exhaust gas temperature comparator 155cs of the second fuel flow rate command calculator 151s. The exhaust gas temperature comparator 155cf of the first fuel flow rate command calculator 151f outputs a comparison value corresponding to the first fuel Ff, and the exhaust gas temperature comparator 155cs of the second fuel flow rate command calculator 151s outputs a comparison value corresponding to the second fuel Fs.

[0064] The minimum value selectors 156f and 156s select the command value indicating the smallest fuel flow rate among the command value GVCSO, the command value LDCSO, the command value BPCSO, and the command value EXCSO, and output this command value as the fuel flow rate command value CSO. The limiters 157f and 157s limit the increase / decrease rate of this fuel flow rate command value CSO so that the increase / decrease rate, which is the change amount per unit time of the fuel flow rate command value CSO from the minimum value selectors 156f and 156s, becomes equal to or less than a predetermined value.

[0065] As shown in FIG. 8, the flow rate ratio calculator 160 obtains a pilot ratio PLr, which is the ratio of the pilot fuel flow rate Fpf to the total fuel flow rate, and a top hat ratio THr, which is the ratio of the top hat fuel flow rate Ftf to the total fuel flow rate. This flow rate ratio calculator 160 includes a pilot ratio calculator 161 and a top hat ratio calculator 162.

[0066] The pilot ratio calculator 161 has a function F1 that defines the relationship between the combustion load command value CLCSO, which has a positive correlation with the inlet temperature of the combustion gas in the turbine 21, and the pilot ratio PLr. As shown in FIG. 10, this function F1 is a function in which the pilot ratio PLr gradually decreases as the combustion load command value CLCSO increases, that is, as the inlet temperature of the combustion gas rises. The pilot ratio calculator 161 receives the combustion load command value CLCSO from the combustion load command generator 120. Then, this pilot ratio calculator 161 uses the function F1 to obtain the pilot ratio PLr corresponding to the combustion load command value CLCSO. Here, the relationship between the combustion load command value CLCSO and the pilot ratio PLr is defined by the function F1, but this relationship may also be defined by a map.

[0067] The top hat ratio calculator 162 has a function F2 that defines the relationship between the combustion load command value CLCSO, which has a positive correlation with the inlet temperature of the combustion gas in the turbine 21, and the top hat ratio THr. As shown in FIG. 11, this function F2 is a function in which the top hat ratio THr gradually increases as the combustion load command value CLCSO increases, that is, as the inlet temperature of the combustion gas rises. The top hat ratio calculator 162 receives the combustion load command value CLCSO from the combustion load command generator 120. Then, this top hat ratio calculator 162 uses the function F2 to obtain the top hat ratio THr corresponding to the combustion load command value CLCSO. Here, the relationship between the combustion load command value CLCSO and the top hat ratio THr is defined by the function F2, but this relationship may also be defined by a map.

[0068] As shown in FIG. 9, the valve opening calculator 170 includes a first multiplier 171, a second multiplier 172, a first subtractor 173, a second subtractor 174, a PL valve command value calculator 175, a TH valve command value calculator 176, and an M valve command value calculator 177.

[0069] The first multiplier 171 multiplies the fuel flow command value CSO indicating the total fuel flow by the pilot ratio PLr to obtain the pilot fuel flow Fpf. The PL valve command value calculator 175 determines the valve opening of the pilot fuel valve 65 such that the flow rate of the pilot fuel Fp injected from the pilot nozzle 44 becomes the pilot fuel flow Fpf, and outputs a command value indicating this valve opening.

[0070] The second multiplier 172 multiplies the fuel flow command value CSO indicating the total fuel flow by the top hat ratio THr to obtain the top hat fuel flow Ftf. The TH valve command value calculator 176 determines the valve opening of the top hat fuel valve 67 such that the flow rate of the top hat fuel Ft injected from the top hat nozzle 51 becomes the top hat fuel flow Ftf, and outputs a command value indicating this valve opening.

[0071] The first subtractor 173 subtracts the top hat fuel flow Ftf from the fuel flow command value CSO indicating the total fuel flow. The second subtractor 174 further subtracts the pilot fuel flow Fpf from the subtraction result of the first subtractor 173, and outputs this subtraction result as the main fuel flow Fmf to the M valve command value calculator 177. The M valve command value calculator 177 determines the valve opening of the main fuel valve 66 such that the total flow rate of the main fuel Fm ejected from the plurality of main nozzles 54 becomes the main fuel flow Fmf, and outputs a command value indicating this valve opening.

[0072] As shown in Fig. 5, the intake air temperature Ti from the intake air thermometer 73 and the output PW from the output meter 72 are input to the IGV command generator 180. The IGV command generator 180 has a function F3 showing the relationship between the output of the gas turbine 10 and the IGV opening degree. As shown in Fig. 12, this function F3 is a function in which the IGV opening degree gradually increases as the output PW of the gas turbine 10 increases. The IGV command generator 180 first corrects the output PW from the output meter 72 with the intake air temperature Ti. Next, the IGV command generator 180 obtains the IGV opening degree for the output PW corrected by the intake air temperature Ti using the function F3. Here, the relationship between the output of the gas turbine 10 and the IGV opening degree is defined by the function F3, but this relationship may also be defined by a map. The IGV command generator 180 outputs an IGV command value IGVc indicating this IGV opening degree to the combustion load command generator 120, the fuel flow rate command generator 150, and the control signal output unit 190. As described above, the combustion load command generator 120 generates a combustion load command value CLCSO using this IGV command value IGVc. As described above, the fuel flow rate command generator 150 generates a fuel flow rate command value CSO using this IGV command value IGVc.

[0073] The control signal output unit 190 creates a control signal indicating the valve opening degree command value for each of the fuel valves 65, 66, and 67 obtained by the valve opening degree calculator 170. Then, the control signal output unit 190 outputs the control signal for each of the fuel valves 65, 66, and 67 to the corresponding fuel valves 65, 66, and 67. Further, the control signal output unit 190 creates a control signal indicating the IGV command value IGVc output by the IGV command generator 180. Then, the control signal output unit 190 outputs this control signal to the IGV 14. When the control signal output unit 190 receives a fuel type command Cft indicating a fuel type different from the current fuel type, it outputs a control signal indicating the switching of the opening and closing states of each fuel valve 65, 66, and 67 to the first fuel switching valve 61f and the second fuel switching valve 61s so that the fuel of the fuel type indicated by the fuel type command Cft is supplied to the combustor 31.

[0074] Next, the operation of the control device 100 will be described according to the flowcharts shown in Figs. 13 and 14.

[0075] As shown in the flowchart of FIG. 13, when the control device 100 receives a new fuel type command Cft indicating a fuel type different from the current fuel type (S1), the control signal output unit 190 of the control device 100 outputs a control signal indicating switching of the open / closed state of each fuel switching valve 61f, 61s to supply the fuel of the fuel type indicated by the fuel type command Cft to the combustor 31 (S2). Specifically, when the current fuel type is the first fuel Ff and the fuel type indicated by the new fuel type command Cft is the second fuel Fs, the control signal output unit 190 outputs a control signal indicating a close instruction to the first fuel switching valve 61f and a control signal indicating an open instruction to the second fuel switching valve 61s.

[0076] Next, the fuel flow rate command generator 150 generates a fuel flow rate command value CSO for the fuel type indicated by the new fuel type command Cft (S3: fuel flow rate command generation step). For example, when the fuel type indicated by the new fuel type command Cft is the second fuel Fs, the second fuel flow rate command calculation unit 151s of the fuel flow rate command generator 150 generates a fuel flow rate command value CSO corresponding to the second fuel Fs. Also, when the fuel type indicated by the new fuel type command Cft is the first fuel Ff, the first fuel flow rate command calculation unit 151f of the fuel flow rate command generator 150 generates a fuel flow rate command value CSO corresponding to the first fuel Ff.

[0077] When the temperature control for controlling the inlet temperature to reach the inlet maximum temperature is started, the combustion load command generator 120 generates a combustion load command value CLCSO for the fuel type indicated by the new fuel type command Cft (S10: combustion load command generation step). For example, when the fuel type indicated by the new fuel type command Cft is the second fuel Fs, the second load command calculation unit 121s of the fuel flow rate command generator 150 generates a combustion load command value CLCSO corresponding to the second fuel Fs. Also, when the fuel type indicated by the new fuel type command Cft is the first fuel Ff, the first load command calculation unit 121f of the fuel flow rate command generator 150 generates a combustion load command value CLCSO corresponding to the first fuel Ff.

[0078] The flow rate ratio calculator 160 obtains the pilot ratio PLr and the top hat ratio THr using the combustion load command value CLCSO from the combustion load command generator 120, and outputs them (S4: flow rate ratio calculation step). Note that if the temperature control is not being executed, the flow rate ratio calculator 160 outputs the planned pilot ratio PLr and top hat ratio THr according to the current operating status of the gas turbine 10.

[0079] The valve opening calculator 170 uses the fuel flow rate command value CSO indicating the total fuel flow rate, the pilot ratio PLr, and the top hat ratio THr to obtain the flow rate Fpf of the pilot fuel Fp injected from the pilot nozzle 44, the flow rate Ftf of the top hat fuel Ft injected from the top hat nozzle 51, and the total flow rate Fmf of the main fuel Fm ejected from the plurality of main nozzles 54. Then, the valve opening calculator 170 outputs a command value indicating the valve opening of each fuel valve 65, 66, 67 based on these flow rates Fpf, Ftf, Fmf (S5: valve opening calculation step).

[0080] The control signal outputter 190 creates a control signal indicating the valve opening command value for each of the fuel valves 65, 66, 67 obtained by the valve opening calculator 170. Then, the control signal outputter 190 outputs the control signal for each of the fuel valves 65, 66, 67 to the corresponding fuel valves 65, 66, 67 (S6: control signal output step).

[0081] Although not shown in the flowchart shown in FIG. 13, regardless of whether a new fuel type command is received, the IGV command generator 180 generates an IGV command value IGVc indicating the IGV opening. The control signal outputter 190 creates a control signal for the IGV using this IGV command value IGVc and outputs this control signal to the IGV.

[0082] Next, the details of the combustion load command generation step S10 by the combustion load command generator 120 will be described according to the flowchart shown in FIG. 14. Here, the case where the second load command calculation unit 121s of the combustion load command generator 120 generates a combustion load command value CLCSO corresponding to the second fuel Fs will be described.

[0083] First, the maximum temperature output calculation unit 131s of the second load command calculation unit 121s obtains a planned maximum temperature output of 1500 °C MW corresponding to the second fuel Fs (S11: maximum temperature output calculation step). In parallel with this maximum temperature output calculation step S11, the minimum temperature output calculation unit 136s of the second load command calculation unit 121s obtains a planned minimum temperature output of 700 °C MW corresponding to the second fuel Fs (S12: minimum temperature output calculation step S12). Further, in parallel with the maximum temperature output calculation step S11, the degradation coefficient calculation unit 124s of the second load command calculation unit 121s obtains a degradation coefficient k (S20: degradation coefficient calculation step).

[0084] This degradation coefficient calculation step S20 includes a deviation calculation step S21 and a coefficient calculation step S22. In the deviation calculation step S21, the differentiator 125s of the degradation coefficient calculation unit 124s obtains a deviation Δ between the actual output and the corrected maximum temperature output 1500 °C MWr. In the coefficient calculation step S22, the divider 126s, proportional-integral controller 127s, and adder 129s of the degradation coefficient calculation unit 124s operate to obtain the degradation coefficient k.

[0085] The coefficient calculation step S22 includes a primary calculation step S23, a determination step S24, a degradation parameter storage step S25, and a secondary calculation step S26.

[0086] In the primary calculation step S23, the divider 126s of the degradation coefficient calculation unit 124s divides the deviation Δ by the corrected maximum temperature output 1500 °C MWr to obtain the ratio of the deviation Δ to the corrected maximum temperature output 1500 °C MWr. Further, in this primary calculation step S23, as described above, the proportional-integral controller 127s of the degradation coefficient calculation unit 124s determines whether the deviation Δ is greater than or equal to a predetermined threshold value during temperature control such that the inlet temperature becomes the inlet maximum temperature. When the proportional-integral controller 127s determines that the deviation Δ is greater than or equal to the predetermined threshold value during temperature control, it performs proportional-integral processing on the output from the divider 126s to obtain a degradation parameter pm.

[0087] In the determination step S24, the proportional-integral controller 127s determines whether the deterioration parameter pm, which is the value of the new proportional-integral result, has changed with respect to the deterioration parameter pm stored in the deterioration parameter storage unit 127ms. When the proportional-integral controller 127s determines that the deterioration parameter pm, which is the value of the new proportional-integral result, has changed, in the deterioration parameter storage step S25, it stores this deterioration parameter pm in the deterioration parameter storage unit 127ms.

[0088] In the secondary calculation step S26, the adder 129s adds the fixed value "1.0" to the deterioration parameter pm stored in the deterioration parameter storage unit 127ms and outputs this value as the deterioration coefficient k.

[0089] Next, the deterioration correction unit 139s multiplies the maximum temperature output 1500 °C MW from the maximum temperature output calculation unit 131s by the deterioration coefficient k to correct the maximum temperature output 1500 °C MW (S13: deterioration correction step). The corrected maximum temperature output 1500 °C MW by this deterioration correction unit 139s is the corrected maximum temperature output 1500 °C MWr.

[0090] Next, the combustion load command value calculation unit 140s uses the minimum temperature output 700 °C MW from the minimum temperature output calculation unit 136s, the corrected maximum temperature output 1500 °C MWr from the deterioration correction unit 139s, and the actual output to execute the calculation shown in the above formula (1) to create a combustion load command value CLCSO corresponding to the second fuel Fs (S14: combustion load command value calculation step).

[0091] Thus, the combustion load command generation step S10 by the second load command calculation unit 121s of the combustion load command generator 120 ends. Note that above, the case of generating the combustion load command value CLCSO corresponding to the second fuel Fs has been described. When generating the combustion load command value CLCSO corresponding to the first fuel Ff, the first load command calculation unit 121f operates in the same manner as above to calculate the combustion load command value CLCSO corresponding to the first fuel Ff.

[0092] As described above, in this embodiment, the combustion load command value CLCSO considering the performance deterioration of the gas turbine can be obtained both when using the first fuel Ff and when using the second fuel Fs. Therefore, in this embodiment, the flow rate ratio for each of the plurality of fuel valves 65, 66, 67 considering the performance deterioration of the gas turbine can be obtained both when using the first fuel Ff and when using the second fuel Fs. Thus, in this embodiment, even when the performance of the gas turbine deteriorates both when using the first fuel Ff and when using the second fuel Fs, the fuel can be stably combusted.

[0093] Incidentally, immediately after the control device 100 receives the fuel type command Cft indicating the second fuel Fs, the second load command calculation unit 121s operates as follows. The deterioration coefficient calculation unit 124s of the second load command calculation unit 121s obtains the deterioration coefficient k using the deterioration parameter pm stored in the deterioration parameter storage unit 127ms when previously performing temperature control using the second fuel Fs. The deterioration correction unit 139s of the second load command calculation unit 121s multiplies the maximum temperature output 1500 °C MW from the maximum temperature output calculation unit 131s of the second load command calculation unit 121s by the deterioration coefficient k to obtain the corrected maximum temperature output 1500 °C MWr. Immediately after the control device 100 receives the fuel type command Cft indicating the second fuel Fs, the differentiator 125s and the divider 126s in the deterioration coefficient calculation unit 124s of the second load command calculation unit 121s perform calculations using this corrected maximum temperature output 1500 °C MWr.

[0094] As described above, in this embodiment, immediately after the control device 100 receives the fuel type command Cft indicating the second fuel Fs, the deterioration coefficient calculation unit 124s can obtain the deterioration coefficient k using the deterioration parameter pm stored in the deterioration parameter storage unit 127ms. Therefore, in this embodiment, even immediately after the control device 100 receives a new fuel type command Cft, the degree of performance deterioration of the gas turbine 10 when previously using the fuel of the same combustion type can be reflected in the deterioration coefficient k and the corrected maximum temperature output 1500 °C MWr.

[0095] "First Modified Example of Combustion Load Command Generator" Referring to FIG. 15, a first modified example of the combustion load command generator will be described.

[0096] The combustion load command generator 120b in this modified example also has a first load command calculation unit 121fb and a second load command calculation unit 121sb, similar to the combustion load command generator 120 in the above embodiment. Further, the first load command calculation unit 121fb and the second load command calculation unit 121sb in this modified example are both similar to the first load command calculation unit 121f and the second load command calculation unit 121s in the above embodiment, and each has a standard atmospheric pressure generator 122f, 122s, an intake pressure ratio calculator 123f, 123s, a deterioration coefficient calculation unit 124, a maximum temperature output calculator 131f, 131s, a minimum temperature output calculator 136f, 136s, a deterioration correction unit 139f, 139s, and a combustion load command value calculation unit 140f, 140s. However, in the combustion load command generator 120b in this modified example, the first load command calculation unit 121fb and the second load command calculation unit 121sb share the deterioration coefficient calculation unit 124 with each other, which is different from the combustion load command generator 120 in the above embodiment.

[0097] The deterioration coefficient calculation unit 124 in this modified example has a differentiator 125, a divider 126, a proportional-integral controller 127, a fixed value generator 128, and an adder 129, similar to the deterioration coefficient calculation units in the above embodiment and the first modified example. The proportional-integral controller 127 in this modified example has a deterioration parameter storage unit 127m. Further, the combustion load command generator 120b in this modified example has a maximum temperature output switch 148.

[0098] Note that the functional units indicated by thick lines in FIG. 15 are the functional units shared by the first load command calculation unit 121fb and the second load command calculation unit 121sb in this modified example.

[0099] The maximum temperature output switch 148 outputs one of the corrected maximum temperature outputs of 1500 °C MWR from the degradation correction unit 139f of the first load command calculation unit 121fb and the corrected maximum temperature output of 1500 °C MWR from the degradation correction unit 139s of the second load command calculation unit 121sb to the degradation coefficient calculation unit 124 according to the fuel type command Cft.

[0100] When the maximum temperature output switch 148 in this modified example receives the fuel type command Cft indicating the second fuel Fs, it outputs the corrected maximum temperature output of 1500 °C MWR from the degradation correction unit 139s of the second load command calculation unit 121sb to the degradation coefficient calculation unit 124. Also, when the maximum temperature output switch 148 in this modified example receives the fuel type command Cft indicating the first fuel Ff, it outputs the corrected maximum temperature output of 1500 °C MWR from the degradation correction unit 139f of the first load command calculation unit 121fb to the degradation coefficient calculation unit 124.

[0101] As described above, in this modified example, since the maximum temperature output switch 148 is provided, even when a new fuel type command Cft is received, one of the corrected maximum temperature outputs of 1500 °C MWR from the degradation correction unit 139f of the first load command calculation unit 121fb and the corrected maximum temperature output of 1500 °C MWR from the degradation correction unit 139s of the second load command calculation unit 121sb, the corrected maximum temperature output of 1500 °C MWR corresponding to the fuel type command Cft can be output to the degradation coefficient calculation unit 124.

[0102] Therefore, also in this modified example, similar to the above-described embodiment, the combustion load command value CLCSO considering the performance degradation of the gas turbine can be obtained both when the first fuel Ff is used and when the second fuel Fs is used.

[0103] Moreover, in this modified example, since the first load command calculation unit 121fb and the second load command calculation unit 121sb share the degradation coefficient calculation unit 124 with each other, the number of functional units constituting the combustion load command generator 120b in this modified example can be made smaller than the number of functional units constituting the combustion load command generator 120 in the above-described embodiment.

[0104] 「Second Modified Example of Combustion Load Command Generator」 With reference to FIG. 16, a second modified example of the combustion load command generator will be described.

[0105] The combustion load command generator 120c in this modified example includes a standard atmospheric pressure generator 122, an intake pressure ratio calculator 123, a degradation coefficient calculation unit 124, a maximum temperature output calculation unit 131, a minimum temperature output calculation unit 136, a degradation correction unit 139, and a combustion load command value calculation unit 140.

[0106] The standard atmospheric pressure generator 122f and the intake pressure ratio calculator 123f of the first load command calculation unit 121f in the above-described embodiment, and the standard atmospheric pressure generator 122s and the intake pressure ratio calculator 123s of the second load command calculation unit 121s operate in the same manner as each other even when the fuel type changes. For this reason, the standard atmospheric pressure generator 122 and the intake pressure ratio calculator 123 in this modified example do not exist for each fuel type. Therefore, the standard atmospheric pressure generator 122 in this modified example generates the same standard intake pressure (standard atmospheric pressure) Ps even when the fuel type changes. Also, the intake pressure ratio calculator 123 in this modified example obtains the intake pressure ratio Pr, which is the ratio of the intake pressure (atmospheric pressure) Pi detected by the intake pressure gauge 74 to the aforementioned standard intake pressure Ps, even when the fuel type changes.

[0107] The degradation coefficient calculation unit 124f of the first load command calculation unit 121f and the degradation coefficient calculation unit 124s of the second load command calculation unit 121s in the above-described embodiment operate in the same manner as each other even when the fuel type changes. For this reason, the degradation coefficient calculation unit 124 in this modified example does not exist for each fuel type. Therefore, the degradation coefficient calculation unit 124 in this modified example executes the same calculation to calculate the degradation coefficient k even when the fuel type changes. Note that the degradation coefficient calculation unit 124 in this modified example has a differentiator 125, a divider 126, a proportional-integral controller 127, a fixed value generator 128, and an adder 129, similar to the degradation coefficient calculation unit 124 of the second modified example.

[0108] The degradation correction unit 139f of the first load command calculation unit 121f and the degradation correction unit 139 of the second load command calculation unit 121s in the above-described embodiment perform the same operations as each other even when the fuel type changes. Therefore, the degradation correction unit 139 in this modification does not exist for each fuel type. Thus, the degradation correction unit 139 in this modification executes the same calculation even when the fuel type changes to obtain the corrected maximum temperature output of 1500 °C M Wr.

[0109] The combustion load command value calculation unit 140f of the first load command calculation unit 121f and the combustion load command value calculation unit 140s of the second load command calculation unit 121s in the above-described embodiment perform the same operations as each other even when the fuel type changes. Therefore, the combustion load command value calculation unit 140 in this modification does not exist for each fuel type. Thus, the combustion load command value calculation unit 140 in this modification executes the same calculation even when the fuel type changes to obtain the combustion load command value CL CSO. Note that the combustion load command value calculation unit 140 in this modification has a first differentiator 141, a second differentiator 142, a divider 143, a fixed value generator 144, a multiplier 145, and a limiter 146, similar to the combustion load command value calculation units 140f and 140s in the above-described embodiment.

[0110] The maximum temperature output calculation unit 131 in this modification has a first planned maximum temperature output generator 132f, a second planned maximum temperature output generator 132s, a first machine difference correction coefficient generator 133f, a second machine difference correction coefficient generator 133s, a machine difference corrector 134, and an intake pressure corrector 135.

[0111] The first planned maximum temperature output generator 132f uses the intake temperature Ti and the IGV command value IGVc as variable parameters and uses a function Hhf corresponding to the first fuel Ff to obtain a planned maximum temperature output, which is the planned gas turbine output when the inlet temperature is 1500 °C. Therefore, the first planned maximum temperature output generator 132f in this modification is substantially the same as the planned maximum temperature output generator 132f of the first load command calculation unit 121f in the above-described embodiment.

[0112] The second planned maximum temperature output generator 132s uses the intake air temperature Ti and the IGV command value IGVc as variable parameters, and obtains the planned maximum temperature output, which is the planned gas turbine output when the inlet temperature is 1500°C, using the function Hhs corresponding to the second fuel Fs. Therefore, the second planned maximum temperature output generator 132s in this modified example is substantially the same as the planned maximum temperature output generator 132s of the second load command calculation unit 121s in the above-described embodiment.

[0113] When the fuel type command Cft is input, only the planned maximum temperature output generator corresponding to the fuel type indicated by this fuel type command Cft among the first planned maximum temperature output generator 132f and the second planned maximum temperature output generator outputs the planned maximum temperature output.

[0114] The first machine difference correction coefficient generator 133f generates the machine difference correction coefficient obtained when the gas turbine is under commissioning using the first fuel Ff. Therefore, the first machine difference correction coefficient generator 133f in this modified example is the same as the machine difference correction coefficient generator 133f of the first load command calculation unit 121f in the above-described embodiment.

[0115] The second machine difference correction coefficient generator 133s generates the machine difference correction coefficient obtained when the gas turbine is under commissioning using the second fuel Fs. Therefore, the second machine difference correction coefficient generator 133s in this modified example is the same as the machine difference correction coefficient generator 133s of the second load command calculation unit 121s in the above-described embodiment.

[0116] The maximum temperature output calculation unit 131 in this modified example further includes a machine difference correction coefficient switch 147. This machine difference correction coefficient switch 147 outputs the machine difference correction coefficient corresponding to the fuel type indicated by the fuel type command Cft from among the machine difference correction coefficient from the first machine difference correction coefficient generator 133f and the machine difference correction coefficient from the second machine difference correction coefficient generator 133s.

[0117] The mechanical error corrector 134 multiplies the planned maximum temperature output from the planned maximum temperature output generator corresponding to the fuel type indicated by the fuel type command Cft, out of the first planned maximum temperature output generator 132f and the second planned maximum temperature output generator 132s, by the mechanical error correction coefficient from the mechanical error correction coefficient switcher 147 to correct this planned maximum temperature output. The intake pressure corrector 135 multiplies the planned maximum temperature output after mechanical error correction by the intake pressure ratio Pr from the intake pressure ratio calculator 123 to further correct the planned maximum temperature output after mechanical error correction. The output from this intake pressure corrector 135 is the planned maximum temperature output 1500 °C MW corresponding to the fuel type indicated by the fuel type command Cft.

[0118] Therefore, the maximum temperature output calculation unit 131 in this modified example has the functions of both the maximum temperature output calculation unit 131f of the first load command calculation unit 121f and the maximum temperature output calculation unit 131s of the second load command calculation unit 121s in the above-described embodiment.

[0119] The minimum temperature output calculation unit 136 in this modified example includes a first planned minimum temperature output generator 137f, a second planned minimum temperature output generator 137s, and an intake pressure corrector 138.

[0120] The first planned minimum temperature output generator 137f uses the intake temperature Ti and the IGV command value IGVc as variable parameters, and uses the function Hlf corresponding to the first fuel Ff to obtain the planned minimum temperature output, which is the planned gas turbine output when the inlet temperature is 700 °C. Therefore, the first planned minimum temperature output generator 137f in this modified example is substantially the same as the planned minimum temperature output generator 137f of the first load command calculation unit 121f in the above-described embodiment.

[0121] The second planned minimum temperature output generator 137s uses the intake temperature Ti and the IGV command value IGVc as variable parameters, and uses the function Hls corresponding to the second fuel Fs to obtain the planned minimum temperature output, which is the planned gas turbine output when the inlet temperature is 700 °C. Therefore, the second planned minimum temperature output generator 137s in this modified example is substantially the same as the planned minimum temperature output generator 137s of the second load command calculation unit 121s in the above-described embodiment.

[0122] When the fuel type command Cft is input, among the first planned minimum temperature output generator 137f and the second planned minimum temperature output generator 137s, only the planned minimum temperature output generator corresponding to the fuel type indicated by this fuel type command Cft outputs the planned minimum temperature output.

[0123] The intake pressure corrector 138 multiplies the planned minimum temperature output from the planned minimum temperature output generator corresponding to the fuel type indicated by the fuel type command Cft, among the first planned minimum temperature output generator 137f and the second planned minimum temperature output generator 137s, by the intake pressure ratio Pr from the intake pressure ratio calculator 123 to correct the planned minimum temperature output. The output from this intake pressure corrector 138 is the planned minimum temperature output 700°C MW corresponding to the fuel type indicated by the fuel type command Cft.

[0124] Therefore, the minimum temperature output calculation unit 136 in this modification has the functions of both the minimum temperature output calculation unit 136f of the first load command calculation unit 121f in the above-described embodiment and the minimum temperature output calculation unit 136s of the second load command calculation unit 121s in the above-described embodiment.

[0125] As described above, the combustion load command generator 120c in this modification also functionally has a first load command calculation unit and a second load command calculation unit, similar to the combustion load command generator 120 in the above-described embodiment, and each of these load command calculation units has a standard atmospheric pressure generator 122, an intake pressure ratio calculator 123, a degradation coefficient calculation unit 124, a maximum temperature output calculation unit 131, a minimum temperature output calculation unit 136, a degradation correction unit 139, and a combustion load command value calculation unit 140.

[0126] Therefore, also in this modification, similar to the above-described embodiment and each of the above modifications, the combustion load command value CLCSO considering the performance degradation of the gas turbine can be obtained both when using the first fuel Ff and when using the second fuel Fs.

[0127] Also, in the combustion load command generator 120c in this modification example, the first load command calculation unit and the second load command calculation unit share the standard atmospheric pressure generator 122, the intake pressure ratio calculator 123, the degradation coefficient calculation unit 124, a part of the maximum temperature output calculation unit 131, a part of the minimum temperature output calculation unit 136, the degradation correction unit 139, and the combustion load command value calculation unit 140 with each other.

[0128] In this modification example, the number of functional units constituting the combustion load command generator 120c can be made smaller than the number of functional units constituting the combustion load command generators 120 and 120b in the above-described embodiment and modification example.

[0129] Note that the functional units indicated by thick lines in FIG. 16 are the functional units shared by the first load command calculation unit and the second load command calculation unit in this modification example.

[0130] "Modification Example of Fuel Flow Rate Command Generator" A modification example of the fuel flow rate command generator will be described with reference to FIG. 17.

[0131] The fuel flow rate command generator 150a in this modification example includes a governor controller 152, a load controller 153, a blade path temperature controller 154, an exhaust gas temperature controller 155, a low value selector 156, and a limiter 157.

[0132] The governor controller 152 in this modification example includes a target rotational speed generator 152g, a first rotational speed comparator 152cf, a second rotational speed comparator 152cs, a comparison value switch 152sw, and a proportional integral controller 152p.

[0133] The target rotational speed generator 152g generates a target rotational speed Nt. The first rotational speed comparator 152cf compares the rotational speed N of the gas turbine rotor 28 from the rotational speed meter 71 with the target rotational speed Nt, and outputs a comparison value corresponding to the first fuel Ff. Therefore, this first rotational speed comparator 152cf is the same as the rotational speed comparator 152cf of the first fuel flow rate command calculation unit 151f in the said embodiment. The second rotational speed comparator 152cs compares the rotational speed N of the gas turbine rotor 28 from the rotational speed meter 71 with the target rotational speed Nt, and outputs a comparison value corresponding to the second fuel Fs. Therefore, this second rotational speed comparator 152cs is the same as the rotational speed comparator 152cs of the second fuel flow rate command calculation unit 151s in the said embodiment. The comparison value switch 152sw outputs a comparison value corresponding to the fuel type indicated by the fuel type command Cft among the comparison value from the first rotational speed comparator 152cf and the comparison value from the second rotational speed comparator 152cs. The proportional-integral controller 152 performs proportional-integral operation on the comparison value from the comparison value switch 152sw. This governor controller 152 outputs the output from this proportional-integral controller 152 as a command value GVCSO.

[0134] Therefore, the governor controller 152 in this modification has the functions of both the governor controller 152f of the first fuel flow rate command calculation unit 151f and the governor controller 152s of the second fuel flow rate command calculation unit 151s in the said embodiment.

[0135] The load controller 153 in this modification includes a first output comparator 153cf, a second output comparator 153cs, a comparison value switch 153sw, and a proportional-integral controller 153p.

[0136] The first output comparator 153cf compares the actual output PW of the gas turbine 10 from the output meter 72 with the required output PWr for the gas turbine 10 from the upper control device, and outputs a comparison value corresponding to the first fuel Ff. Therefore, this first output comparator 153cf is the same as the output comparator 153cf of the first fuel flow rate command calculation unit 151f in the said embodiment. The second output comparator 153cs compares the actual output PW of the gas turbine 10 from the output meter 72 with the required output PWr for the gas turbine 10 from the upper control device, and outputs a comparison value corresponding to the second fuel Fs. Therefore, this second output comparator 153cs is the same as the output comparator 153cs of the second fuel flow rate command calculation unit 151s in the said embodiment. The comparison value switch 153sw outputs a comparison value corresponding to the fuel type indicated by the fuel type command Cft among the comparison value from the first output comparator 153cf and the comparison value from the second output comparator 153cs. The proportional-integral controller 153 performs proportional-integral operation on the comparison value from the comparison value switch 153sw. This load controller 153 outputs the output from this proportional-integral controller 153 as the command value LDCSO.

[0137] Therefore, the load controller 153 in this modification has the functions of both the load controller 153f of the first fuel flow rate command calculation unit 151f and the load controller 153s of the second fuel flow rate command calculation unit 151s in the said embodiment.

[0138] The blade path temperature controller 154 in this modification includes an upper limit value generator 154g, a first blade path temperature comparator 154cf, a second blade path temperature comparator 154cs, a comparison value switch 154sw, and a proportional-integral controller 154p.

[0139] The upper limit value generator 154g generates the upper limit value Tbu of the blade path temperature. The first blade path temperature comparator 154cf compares the blade path temperature Tb from the blade path thermometer 75 with its upper limit value Tbu and outputs a comparison value corresponding to the first fuel Ff. Therefore, this first blade path temperature comparator 154cf is the same as the blade path temperature comparator 154cf of the first fuel flow rate command calculator 151f in the above embodiment. The second blade path temperature comparator 154cs compares the blade path temperature Tb from the blade path thermometer 75 with its upper limit value Tbu and outputs a comparison value corresponding to the second fuel Fs. Therefore, this second blade path temperature comparator 154cs is the same as the blade path temperature comparator 154cs of the second fuel flow rate command calculator 151s in the above embodiment. The comparison value switch 154sw outputs a comparison value corresponding to the fuel type indicated by the fuel type command Cft among the comparison value from the first blade path temperature comparator 154cf and the comparison value from the second blade path temperature comparator 154cs. The proportional-integral controller 154 performs proportional-integral calculation on the comparison value from the comparison value switch 154sw. This blade path temperature controller 154 outputs the output from this proportional-integral controller 154p as the command value BPCSO.

[0140] Therefore, the blade path temperature controller 154 in this modification has the functions of both the blade path temperature controller 154f of the first fuel flow rate command calculator 151f in the above embodiment and the blade path temperature controller 154s of the second fuel flow rate command calculator 151s in the above embodiment.

[0141] The exhaust gas temperature controller 155 in this modification includes an upper limit value generator 155g, a first exhaust gas temperature comparator 155cf, a second exhaust gas temperature comparator 155cs, a comparison value switch 155sw, and a proportional-integral controller 155p.

[0142] The upper limit value generator 155g generates the upper limit value Teu of the exhaust gas temperature. The first exhaust gas temperature comparator 155cf compares the exhaust gas temperature Te from the exhaust gas thermometer 76 with its upper limit value Teu and outputs a comparison value corresponding to the first fuel Ff. Therefore, this first exhaust gas temperature comparator 155cf is the same as the exhaust gas temperature comparator 155cf of the first fuel flow rate command calculation unit 151f in the said embodiment. The second exhaust gas temperature comparator 155cs compares the exhaust gas temperature Te from the exhaust gas thermometer 76 with its upper limit value Teu and outputs a comparison value corresponding to the second fuel Fs. Therefore, this second exhaust gas temperature comparator 155cs is the same as the exhaust gas temperature comparator 155cs of the second fuel flow rate command calculation unit 151s in the said embodiment. The comparison value switch 155sw outputs a comparison value corresponding to the fuel type indicated by the fuel type command Cft among the comparison value from the first exhaust gas temperature comparator 155cf and the comparison value from the second exhaust gas temperature comparator 155cs. The proportional integral controller 155p performs proportional integral calculation on the comparison value from the comparison value switch 155sw. The exhaust gas temperature controller 155 outputs the output from this proportional integral controller 155p as the command value EXCSO.

[0143] Therefore, the exhaust gas temperature controller 155 in this modified example has the functions of both the exhaust gas temperature controller 155f of the first fuel flow rate command calculation unit 151f and the exhaust gas temperature controller 155s of the second fuel flow rate command calculation unit 151s in the said embodiment.

[0144] The low value selector 156f of the first fuel flow rate command calculation unit 151f and the low value selector 156s of the second fuel flow rate command calculation unit 151s in the said embodiment perform the same operations as each other even when the fuel type changes. For this reason, the low value selector 156 in this modified example does not exist for each fuel type.

[0145] The limiter 157f of the first fuel flow rate command calculation unit 151f and the limiter 157s of the second fuel flow rate command calculation unit 151s in the said embodiment perform the same operations as each other even when the fuel type changes. For this reason, the limiter 157 in this modified example does not exist for each fuel type.

[0146] Therefore, the fuel flow rate command generator 150a in this modified example also functionally has the same first fuel flow rate command calculation unit and second fuel flow rate command calculation unit as the fuel flow rate command generator 150 in the above-described embodiment, and each of these fuel flow rate command calculation units has a governor controller 152, a load controller 153, a blade path temperature controller 154, an exhaust gas temperature controller 155, a minimum selector 156, and a limiter 157. However, the fuel flow rate command generator 150a in this modified example shares the minimum selector 156, the limiter 157, a part of the governor controller 152, a part of the load controller 153, a part of the blade path temperature controller 154, and a part of the exhaust gas temperature controller 155 between the first fuel flow rate calculation unit and the second fuel flow rate calculation unit. For this reason, the number of functional units constituting the fuel flow rate command generator 150a in this modified example can be made smaller than the number of functional units constituting the fuel flow rate command generator 150 in the above-described embodiment.

[0147] This modified example is a modified example of the fuel flow rate command generator 150 in the above-described first embodiment. However, the fuel flow rate command generator 150a in this modified example may be adopted regardless of whether the combustion load command generator 120b in the first modified example or the combustion load command generator 120c in the second modified example is adopted.

[0148] "Other Modified Examples" In the above-described embodiment and each of the above modified examples, natural gas is exemplified as the first fuel Ff, and oil is exemplified as the second fuel Fs. However, any one of natural gas, oil, hydrogen, combustible synthetic gas, ammonia, and a mixed fuel combining these may be the first fuel Ff, and the other may be the second fuel Fs.

[0149] In the above-described embodiment and each of the above modified examples, there are two types of fuel species. However, the number of fuel species may be three or more.

[0150] Furthermore, the present disclosure is not limited to the above-described embodiment and each of the above modifications. Various additions, changes, replacements, partial deletions, etc. are possible without departing from the conceptual ideas and spirits of the present invention derived from the content defined in the claims and their equivalents.

[0151] "Supplementary Note" The control device of the gas turbine facility in the above-described embodiment and each modification is understood as follows, for example.

[0152] (1) The control device 100 of the gas turbine facility in the first aspect is applied to the following gas turbine facility. This gas turbine facility includes a compressor 11 capable of compressing air to generate compressed air, a combustor 31 capable of burning fuel in the compressed air to generate combustion gas, a turbine 21 drivable by the combustion gas, a gas turbine 10, and a plurality of types of fuel valves 65, 66, 67 for adjusting the flow rate of fuel supplied to the combustor 31. The combustor 31 has a plurality of types of nozzles 44, 51, 54 for injecting fuel. Each of the plurality of types of fuel valves 65, 66, 67 is provided for each of the plurality of types of nozzles 44, 51, 54. This control device 100 includes a combustion load command generator 120, 120b, 120c for obtaining a combustion load command value CLCSO, which is a parameter having a positive correlation with the inlet temperature of the combustion gas at the inlet of the turbine 21; a flow rate ratio calculator 160 for obtaining a flow rate ratio of fuel supplied to each of the plurality of types of nozzles 44, 51, 54 according to the combustion load command value CLCSO; a valve opening degree calculator 170 for obtaining the valve opening degree of each of the fuel valves 65, 66, 67 for each of the plurality of types of nozzles 44, 51, 54 based on the flow rate ratio of fuel supplied to each of the plurality of types of nozzles 44, 51, 54; and a control signal outputter 190 for outputting a control signal indicating the valve opening degree to each of the fuel valves 65, 66, 67 for each of the plurality of types of nozzles 44, 51, 54. The combustion load command generators 120, 120b, and 120c include first load command calculation units 121f, 121fb that obtain the combustion load command value CLCSO for the first fuel Ff, which is the fuel type indicated by the external fuel type command Cft, and second load command calculation units 121s, 121sb that obtain the combustion load command value CLCSO for the second fuel Fs, which is the fuel type indicated by the external fuel type command Cft. The first load command calculation units 121f, 121fb and the second load command calculation units 121s, 121sb each include a maximum temperature output calculation unit 131f, 131s, 131 that obtains a maximum temperature output, which is a planned output corresponding to the fuel type, with respect to the inlet maximum temperature, which is the highest temperature determined in advance for the inlet temperature; a minimum temperature output calculation unit 136f, 136s, 136 that obtains a minimum temperature output, which is a planned output corresponding to the fuel type, with respect to the inlet minimum temperature, which is the lowest temperature determined in advance for the inlet temperature; a degradation coefficient calculation unit 124f, 124s, 124 that obtains a degradation coefficient k for correcting the maximum temperature output; a degradation correction unit 139f, 139s, 139 that corrects the maximum temperature output using the degradation coefficient k; a combustion load command value calculation unit 140f, 140s, 140 that obtains the combustion load command value CLCSO using the minimum temperature output, the corrected maximum temperature output 1500 °C M Wr, which is the maximum temperature output corrected by the degradation correction unit 139f, 139s, 139, and the actual output of the gas turbine 10. The degradation coefficient calculation unit 124f, 124s, 124 includes a differentiator 125f, 125s, 125 that obtains a deviation Δ between the corrected maximum temperature output 1500 °C M Wr and the actual output, and a coefficient calculator that obtains the degradation coefficient k according to the deviation Δ during temperature control in which the inlet temperature is controlled to be the inlet maximum temperature. The coefficient calculator includes a degradation parameter storage unit 127mf, 127ms, 127m that stores a degradation parameter pm, which is a value obtained by performing proportional-integral processing on the ratio of the deviation when the deviation Δ is equal to or greater than a predetermined threshold during temperature control. The coefficient calculator outputs the degradation coefficient k based on the degradation parameter pm stored in the degradation parameter storage unit 127mf, 127ms, 127m.

[0153] In this aspect, the combustion load command value CLCSO considering the performance degradation of the gas turbine 10 can be obtained both when using the first fuel Ff and when using the second fuel Fs. Therefore, in this aspect, the flow rate ratio for each of the plurality of fuel valves 65, 66, 67 considering the performance degradation of the gas turbine 10 can be obtained both when using the first fuel Ff and when using the second fuel Fs. Thus, in this aspect, even if the performance of the gas turbine 10 deteriorates both when using the first fuel Ff and when using the second fuel Fs, the fuel can be stably combusted.

[0154] Also, in this aspect, even immediately after the control device 100 receives a fuel type command Cft indicating a combustion type different from the current fuel type, the degradation coefficient k can be obtained using the degradation parameter pm stored in the degradation parameter storage units 127mf, 127ms, 127m. Therefore, in this aspect, even immediately after the control device 100 receives a new fuel type command Cft, the degree of performance degradation of the gas turbine 10 can be reflected in the degradation coefficient k, and the fuel can be stably combusted.

[0155] (2) The control device 100 of the gas turbine in the second aspect In the control device 100 of the gas turbine facility in the first aspect, the first load command calculation unit 121fb and the second load command calculation unit 121sb share the degradation coefficient calculation unit 124 with each other.

[0156] In this aspect, similar to the second aspect, since the first load command calculation unit 121fb and the second load command calculation unit 121sb share the degradation parameter storage unit 127m, immediately after receiving a new fuel type command Cft, the degree of performance degradation of the gas turbine 10 immediately before receiving this fuel type command Cft can be reflected in the degradation coefficient k. Furthermore, in this aspect, since the first load command calculation unit 121fb and the second load command calculation unit 121sb share the degradation coefficient calculation unit 124 with each other, the number of components of the control device 100 can be reduced.

[0157] (3) The control device 100 of the gas turbine in the third aspect In the control device 100 of the gas turbine facility in the second aspect, the combustion load command generator 120b outputs, to the degradation coefficient calculation unit 124, one of the corrected maximum temperature outputs of 1500 °C MWr from the degradation correction unit 139f of the first load command calculation unit 121fb and the corrected maximum temperature output of 1500 °C MWr from the degradation correction unit 139s of the second load command calculation unit 121sb, according to the fuel type indicated by the fuel type command Cft, through a maximum temperature output switch 148.

[0158] (4) The control device 100 of the gas turbine in the fourth aspect is In the control device 100 of the gas turbine facility in the third aspect, the first load command calculation unit 121fb and the second load command calculation unit 121sb share the degradation correction unit 139 and the combustion load command value calculation unit 140 with each other.

[0159] In this aspect, since the first load command calculation unit and the second load command calculation unit share the degradation correction unit 139 and the combustion load command value calculation unit 140 with each other, the number of components of the control device 100 can be reduced.

[0160] The control program for the gas turbine facility in the above embodiments is understood as follows, for example.

[0161] (5) The control program 113p for the gas turbine facility in the fifth aspect is applied to the following gas turbine facilities. This gas turbine facility includes a compressor 11 capable of compressing air to generate compressed air, a combustor 31 capable of burning fuel in the compressed air to generate combustion gas, a turbine 21 drivable by the combustion gas, a gas turbine 10, and a plurality of types of fuel valves 65, 66, 67 for adjusting the flow rate of fuel supplied to the combustor 31. The combustor 31 has a plurality of types of nozzles 44, 51, 54 for injecting fuel. Each of the plurality of types of fuel valves 65, 66, 67 is provided for each of the plurality of types of nozzles 44, 51, 54. This control program causes a computer to execute a combustion load command generation step S10 for obtaining a combustion load command value CLCSO, which is a parameter having a positive correlation with an inlet temperature that is the temperature of the combustion gas at the inlet of the turbine 21; a flow rate ratio calculation step S4 for obtaining a flow rate ratio of fuels supplied to each of the plurality of types of nozzles 44, 51, 54 according to the combustion load command value CLCSO; a valve opening degree calculation step S5 for obtaining a valve opening degree of each of the fuel valves 65, 66, 67 for each of the plurality of types of nozzles 44, 51, 54 based on the flow rate ratio of the fuels supplied to each of the plurality of types of nozzles 44, 51, 54; and a control signal output step S6 for outputting a control signal indicating the valve opening degree to each of the fuel valves 65, 66, 67 for each of the plurality of types of nozzles 44, 51, 54. The combustion load command generation step S10 includes a first load command calculation step of obtaining the combustion load command value CLCSO for the first fuel Ff which is the fuel type indicated by the external fuel type command Cft, and a second load command calculation step of obtaining the combustion load command value CLCSO for the second fuel Fs which is the fuel type indicated by the external fuel type command Cft. Both the first load command calculation step and the second load command calculation step include a maximum temperature output calculation step S11 of obtaining a maximum temperature output which is a planned output according to the fuel type with respect to the inlet maximum temperature which is the highest temperature determined in advance for the inlet temperature, a minimum temperature output calculation step S12 of obtaining a minimum temperature output which is a planned output according to the fuel type with respect to the inlet minimum temperature which is the lowest temperature determined in advance for the inlet temperature, a deterioration coefficient calculation step S20 of obtaining a deterioration coefficient k for correcting the maximum temperature output, a deterioration correction step S13 of correcting the maximum temperature output using the deterioration coefficient k, a combustion load command value calculation step S14 of obtaining the combustion load command value CLCSO using the minimum temperature output, the corrected maximum temperature output 1500 °C M Wr which is the maximum temperature output corrected in the deterioration correction step S13, and the actual output which is the actual output of the gas turbine 10. The deterioration coefficient calculation step S20 includes a deviation calculation step S21 of obtaining a deviation Δ between the corrected maximum temperature output 1500 °C M Wr and the actual output, and a coefficient calculation step S22 of obtaining the deterioration coefficient k according to the deviation Δ during temperature control for controlling the inlet temperature to be the inlet maximum temperature. The coefficient calculation step S22 includes a deterioration parameter storage step S25 of storing, in a deterioration parameter storage unit 127mf, 127ms, 127m which is a part of the storage area of the computer, a deterioration parameter pm which is a value obtained by proportional integral processing with respect to the ratio of the deviation when the deviation Δ is equal to or greater than a predetermined threshold during the temperature control. In the coefficient calculation step S22, the deterioration coefficient k based on the deterioration parameter pm stored in the deterioration parameter storage unit 127mf, 127ms, 127m is output.

[0162] By causing a computer to execute the control program of this aspect, similar to the control device 100 in the first aspect, even when the performance improvement of the gas turbine 10 deteriorates both when using the first fuel Ff and when using the second fuel Fs, the fuel can be stably combusted.

[0163] Furthermore, by causing a computer to execute the control program of this aspect, similar to the control device 100 in the first aspect, even immediately after receiving a new fuel type command Cft, the deterioration coefficient k can reflect the degree of performance deterioration of the gas turbine 10, and the fuel can be stably combusted.

[0164] (6) The control program 113p of the gas turbine facility in the sixth aspect is In the control program 113p of the gas turbine facility in the fifth aspect, the first load command calculation step and the second load command calculation step share the deterioration coefficient calculation step with each other.

[0165] By causing a computer to execute the control program of this aspect, similar to the control device 100 in the second aspect, the degree of performance deterioration of the gas turbine 10 immediately before receiving a new fuel type command Cft can be reflected in the deterioration coefficient k.

[0166] The operation method of the gas turbine facility in the above embodiments is understood as follows, for example.

[0167] (7) The operation method of the gas turbine facility in the seventh aspect is applied to the following gas turbine facility. This gas turbine facility includes a gas turbine 10 having a compressor 11 capable of compressing air to generate compressed air, a combustor 31 capable of burning fuel in the compressed air to generate combustion gas, and a turbine 21 drivable by the combustion gas, and a plurality of types of fuel valves 65, 66, 67 for adjusting the flow rate of fuel supplied to the combustor 31. The combustor 31 has a plurality of types of nozzles 44, 51, 54 for injecting fuel. Each of the plurality of types of fuel valves 65, 66, 67 is provided for each of the plurality of types of nozzles 44, 51, 54. In this operation method, a combustion load command generation step S10 of obtaining a combustion load command value CLCSO which is a parameter having a positive correlation with the inlet temperature which is the temperature of the combustion gas at the inlet of the turbine 21, a flow rate ratio calculation step S4 of obtaining a flow rate ratio of fuel supplied to each of the plurality of types of nozzles 44, 51, 54 according to the combustion load command value CLCSO, a valve opening degree calculation step S5 of obtaining the valve opening degree of each of the fuel valves 65, 66, 67 for each of the plurality of types of nozzles 44, 51, 54 based on the flow rate ratio of fuel supplied to each of the plurality of types of nozzles 44, 51, 54, and a control signal output step S6 of outputting a control signal indicating the valve opening degree to each of the fuel valves 65, 66, 67 for each of the plurality of types of nozzles 44, 51, 54 are executed. The combustion load command generation step S10 includes a first load command calculation step of obtaining the combustion load command value CLCSO for the first fuel Ff, which is the fuel type indicated by the external fuel type command Cft, and a second load command calculation step of obtaining the combustion load command value CLCSO for the second fuel Fs, which is the fuel type indicated by the external fuel type command Cft. Both the first load command calculation step and the second load command calculation step include a maximum temperature output calculation step S11 of obtaining a maximum temperature output, which is a planned output according to the fuel type, with respect to the inlet maximum temperature, which is the highest temperature determined in advance for the inlet temperature; a minimum temperature output calculation step S12 of obtaining a minimum temperature output, which is a planned output according to the fuel type, with respect to the inlet minimum temperature, which is the lowest temperature determined in advance for the inlet temperature; a degradation coefficient calculation step S20 of obtaining a degradation coefficient k for correcting the maximum temperature output; a degradation correction step S13 of correcting the maximum temperature output using the degradation coefficient k; and a combustion load command value calculation step S14 of obtaining the combustion load command value CLCSO using the minimum temperature output, the corrected maximum temperature output 1500 °C M Wr, which is the maximum temperature output corrected by the degradation correction units 139f and 139s, and the actual output, which is the actual output of the gas turbine 10. The degradation coefficient calculation step S20 includes a deviation calculation step S21 of obtaining a deviation Δ between the corrected maximum temperature output 1500 °C M Wr and the actual output, and a coefficient calculation step S22 of obtaining the degradation coefficient k according to the deviation Δ during temperature control when the inlet temperature is controlled to be the inlet maximum temperature. The coefficient calculation step S22 includes a degradation parameter storage step S25 of storing, in the degradation parameter storage units 127mf, 127ms, and 127m, a degradation parameter pm, which is a value obtained by proportional integral processing with respect to the ratio of the deviation when the deviation is equal to or greater than a predetermined threshold during temperature control. In the coefficient calculation step S22, the degradation coefficient k based on the degradation parameter pm stored in the degradation parameter storage units 127mf, 127ms, and 127m is output.

[0168] Also in this embodiment, similar to the control device 100 in the first embodiment, even when the performance of the gas turbine 10 deteriorates both when using the first fuel Ff and when using the second fuel Fs, the fuel can be stably combusted.

[0169] Furthermore, also in this aspect, similar to the control device 100 in the first aspect, even immediately after receiving a new fuel type command Cft, the deterioration coefficient k can reflect the degree of performance deterioration of the gas turbine 10, and stable combustion of the fuel can be achieved.

[0170] (8) The operation method of the gas turbine facility in the eighth aspect is In the operation method of the gas turbine facility in the seventh aspect, the first load command calculation step and the second load command calculation step share the deterioration coefficient calculation step with each other.

[0171] Also in this aspect, similar to the control device 100 in the second aspect, the degree of performance deterioration of the gas turbine 10 immediately before receiving a new fuel type command Cft can be reflected in the deterioration coefficient k.

[0172] (9) The operation method of the gas turbine facility in the ninth aspect is In the operation method of the gas turbine facility in the seventh aspect or the eighth aspect, any one of natural gas, oil, hydrogen, combustible synthesis gas, ammonia, and a mixed fuel combining these is the first fuel Ff, and the other one is the second fuel Fs.

Industrial Applicability

[0173] In one aspect of the present disclosure, when using a plurality of types of fuels, stable combustion of the fuel can be achieved even if the performance of the gas turbine deteriorates.

Explanation of Signs

[0174] 10: Gas turbine 11: Compressor 12: Compressor casing 13: Compressor rotor 14: IGV 15: Guide vane 16: Driver 21: Turbine 22: Turbine casing 23: Turbine rotor 28: Gas turbine rotor 24: Intermediate casing 25: Exhaust casing 29: Generator 31: Combustor 32: Outer cylinder 33: Combustion cylinder (or tail cylinder) 41: Fuel injector 42: Inner cylinder 43: Pilot burner 44: Pilot nozzle 45: Cylinder for pilot air 48: Pilot air flow path 49: Diffusion flame 51: Top hat nozzle 52: Compressed air flow path 53: Main burner 54: Main nozzle 55: Inner cylinder for main air 56: Outer cylinder for main air 57: Partition plate 58: Main air flow path 59: Premixed flame 60: Integrated fuel line 60f: First fuel line 60s: Second fuel line 61f: First fuel switching valve (fuel switching valve) 61s: Second fuel switching valve (fuel switching valve) 62: Pilot fuel line 63: Main fuel line 64: Top hat fuel line 65: Pilot fuel valve 66: Main fuel valve 67: Top hat fuel valve 71: Tachometer 72: Output meter 73: Intake air temperature meter 74: Intake air pressure gauge 75: Blade path thermometer 76: Exhaust gas thermometer 100: Control device 101: Input device 102: Display device 110: Computer main body 111: CPU 112: Main memory device 113: Auxiliary memory device (memory area) 113p: Control program 115: Memory and playback device 116: Input / output interface 117: Device interface 118: Communication interface 120, 120b, 120c: Combustion load command generator 121f, 121fb,: First load command calculation unit 121s, 121sb: Second load command calculation unit 122f, 122s, 122: Standard atmospheric pressure generator 123f, 123s, 123: Intake pressure ratio calculator 124f, 124s, 124: Deterioration coefficient calculation unit 125f, 125s, 125: Differentiator 126f, 126s, 126: Divider 127f, 127s, 127: Proportional integral controller 127mf, 127ms, 127m: Deterioration parameter memory unit 128f, 128s, 128: Fixed value generator 129f, 129s, 129: Adder 131f, 131s, 131: Maximum temperature output calculation unit 132f: First planned maximum temperature output generator (planned maximum temperature output generator) 132s: Second planned maximum temperature output generator (planned maximum temperature output generator) 133f: First machine difference correction coefficient generator (machine difference correction coefficient generator) 133s: Second machine difference correction coefficient generator (machine difference correction coefficient generator) 134f, 134s, 134: Machine difference corrector 135f, 135s, 135: Intake pressure corrector 136f, 136s, 136: Minimum temperature output calculation unit 137f: First planned minimum temperature output generator (planned minimum temperature output generator) 137s: Second planned minimum temperature output generator (planned minimum temperature output generator) 138f, 138s, 138: Intake pressure corrector 139f, 139s, 139: Degradation corrector 140f, 140s, 140: Combustion load command value calculator 141f, 141s, 141: First differentiator 142f, 142s, 142: Second differentiator 143f, 143s, 143: Divider 144f, 144s, 144: Fixed value generator 145f, 145s, 145: Multiplier 146f, 146s, 146: Limiter 147: Machine difference correction coefficient switch 148: Maximum temperature output switch 149: Coefficient switch 150, 150a: Fuel flow rate command generator 151f: First fuel flow rate command calculator 151s: Second fuel flow rate command calculator 152f, 152s, 152: Governor controller 152gf, 152gs, 152g: Target rotation speed generator 152cf: First rotation speed comparator (rotation speed comparator) 152cs: Second rotation speed comparator (rotation speed comparator) 152pf, 152ps, 152p: Proportional integral controller 152sw: Comparison value switch 153f, 153s, 153: Load controller 153cf: First output comparator (output comparator) 153cs: Second output comparator (output comparator) 153pf, 153ps, 153p: Proportional integral controller 153sw: Comparison value switch 154f, 154s, 154: Blade path temperature controller 154gf, 154gs, 154g: Upper limit value generator 154cf: First blade path temperature comparator (blade path temperature comparator) 154cs: Second Blade Path Temperature Comparator (Blade Path Temperature Comparator) 154pf, 154ps, 154p: Proportional Integrator 154sw: Comparison Value Switcher 155f, 155s, 155: Exhaust Gas Temperature Controller 155gf, 155gs, 155g: Upper Limit Value Generator 155cf: First Exhaust Gas Temperature Comparator (Exhaust Gas Temperature Comparator) 155cs: Second Exhaust Gas Temperature Comparator (Exhaust Gas Temperature Comparator) 155pf, 155ps, 155p: Proportional Integrator 155sw: Comparison Value Switcher 156f, 156s, 156: Low Value Selector 157f, 157s, 157: Limiter 160: Flow Ratio Calculator 161: Pilot Ratio Calculator 162: Top Hat Ratio Calculator 170: Valve Opening Degree Calculator 171: First Multiplier 172: Second Multiplier 173: First Subtractor 174: Second Subtractor 175: PL Valve Command Value Calculator 176: TH Valve Command Value Calculator 177: M Valve Command Value Calculator 180: IGV Command Generator 190: Control Signal Output Device

Claims

1. A gas turbine having a compressor capable of compressing air to generate compressed air, a combustor capable of burning fuel in the compressed air to generate combustion gas, and a turbine drivable by the combustion gas, a plurality of types of fuel valves for adjusting the flow rate of fuel supplied to the combustor, the combustor having a plurality of types of nozzles for injecting fuel, each of the plurality of types of fuel valves being provided for each of the plurality of types of nozzles, in a control device of a gas turbine facility, a combustion load command generator for obtaining a combustion load command value which is a parameter having a positive correlation with the inlet temperature which is the temperature of the combustion gas at the inlet of the turbine, a flow rate ratio calculator for obtaining a flow rate ratio of fuel supplied to each of the plurality of types of nozzles according to the combustion load command value, a valve opening calculator for obtaining a valve opening of the fuel valve for each of the plurality of types of nozzles based on the flow rate ratio of fuel supplied to each of the plurality of types of nozzles, a control signal outputter for outputting a control signal indicating the valve opening to the fuel valve for each of the plurality of types of nozzles, comprising, the combustion load command generator having a first load command calculator for obtaining the combustion load command value for a first fuel which is the fuel type indicated by a fuel type command from the outside, and a second load command calculator for obtaining the combustion load command value for a second fuel which is the fuel type indicated by a fuel type command from the outside, both the first load command calculator and the second load command calculator, a maximum temperature output calculator for obtaining a maximum temperature output which is a planned output according to the fuel type with respect to an inlet maximum temperature which is a predetermined maximum temperature of the inlet temperature, a minimum temperature output calculator for obtaining a minimum temperature output which is a planned output according to the fuel type with respect to an inlet minimum temperature which is a predetermined minimum temperature of the inlet temperature, a degradation coefficient calculator for obtaining a degradation coefficient for correcting the maximum temperature output, a degradation correction unit for correcting the maximum temperature output using the degradation coefficient, a combustion load command value calculator for obtaining the combustion load command value using the minimum temperature output, the corrected maximum temperature output which is the maximum temperature output corrected by the degradation correction unit, and the actual output which is the actual output of the gas turbine, having, the degradation coefficient calculator having a differentiator for obtaining a deviation between the corrected maximum temperature output and the actual output, and a coefficient calculator for obtaining the degradation coefficient according to the deviation during temperature control for controlling the inlet temperature to be the inlet maximum temperature. The coefficient calculator has a deterioration parameter storage unit that stores a deterioration parameter which is a value obtained by performing proportional-integral processing on the ratio of the deviation when the deviation is equal to or greater than a predetermined threshold during temperature control. The coefficient calculator outputs the deterioration coefficient based on the deterioration parameter stored in the deterioration parameter storage unit. A control device for a gas turbine facility.

2. In the control device for a gas turbine facility according to Claim 1, the first load command calculator and the second load command calculator share the deterioration coefficient calculator with each other. A control device for a gas turbine facility.

3. In the control device for a gas turbine facility according to Claim 2, the combustion load command generator has a maximum temperature output switch that outputs, to the deterioration coefficient calculator, one of the corrected maximum temperature outputs from the deterioration correction unit of the first load command calculator and the corrected maximum temperature output from the deterioration correction unit of the second load command calculator, according to the fuel type indicated by the fuel type command. A control device for a gas turbine facility.

4. In the control device for a gas turbine facility according to Claim 3, the first load command calculator and the second load command calculator share the deterioration correction unit and the combustion load command value calculator with each other. A control device for a gas turbine facility.

5. A gas turbine having a compressor capable of compressing air to generate compressed air, a combustor capable of burning fuel in the compressed air to generate combustion gas, and a turbine drivable by the combustion gas, and a plurality of types of fuel valves for adjusting the flow rate of fuel supplied to the combustor. The combustor has a plurality of types of nozzles for injecting fuel. Each of the plurality of types of fuel valves is provided for each of the plurality of types of nozzles. In a control program for a gas turbine facility, a combustion load command generation step of obtaining a combustion load command value which is a parameter having a positive correlation with the inlet temperature which is the temperature of the combustion gas at the inlet of the turbine; a flow rate ratio calculation step of obtaining a flow rate ratio of fuel supplied to each of the plurality of types of nozzles according to the combustion load command value; a valve opening degree calculation step of obtaining a valve opening degree of the fuel valve for each of the plurality of types of nozzles based on the flow rate ratio of fuel supplied to each of the plurality of types of nozzles; a control signal output step of outputting a control signal indicating the valve opening degree to the fuel valve for each of the plurality of types of nozzles; and causing a computer to execute. The combustion load command generation process includes a first load command calculation process for obtaining the combustion load command value for a first fuel, which is the fuel type indicated by a fuel type command from the outside, and a second load command calculation process for obtaining the combustion load command value for a second fuel, which is the fuel type indicated by the fuel type command from the outside. Both the first load command calculation process and the second load command calculation process include a maximum temperature output calculation process for obtaining a maximum temperature output, which is a planned output corresponding to the fuel type, with respect to an inlet maximum temperature, which is the highest temperature determined in advance for the inlet temperature; a minimum temperature output calculation process for obtaining a minimum temperature output, which is a planned output corresponding to the fuel type, with respect to an inlet minimum temperature, which is the lowest temperature determined in advance for the inlet temperature; a degradation coefficient calculation process for obtaining a degradation coefficient for correcting the maximum temperature output; a degradation correction process for correcting the maximum temperature output using the degradation coefficient; and a combustion load command value calculation process for obtaining the combustion load command value using the minimum temperature output, the corrected maximum temperature output, which is the maximum temperature output corrected in the degradation correction process, and the actual output, which is the actual output of the gas turbine. It includes The degradation coefficient calculation process includes a deviation calculation process for obtaining a deviation between the corrected maximum temperature output and the actual output, and a coefficient calculation process for obtaining the degradation coefficient according to the deviation during temperature control when the inlet temperature is controlled to be the inlet maximum temperature. The coefficient calculation process includes a degradation parameter storage process for storing, in a degradation parameter storage unit, which is a part of the storage area of the computer, a degradation parameter that is a value obtained by performing proportional-integral processing on the ratio of the deviation when the deviation is greater than or equal to a predetermined threshold during temperature control. In the coefficient calculation process, the degradation coefficient based on the degradation parameter stored in the degradation parameter storage unit is output. A control program for a gas turbine facility.

6. In the control program for a gas turbine facility according to claim 5, the first load command calculation process and the second load command calculation process share the degradation coefficient calculation process with each other. A control program for a gas turbine facility.

7. A gas turbine having a compressor capable of compressing air to generate compressed air, a combustor capable of burning fuel in the compressed air to generate combustion gas, and a turbine drivable by the combustion gas, and a plurality of types of fuel valves for adjusting the flow rate of the fuel supplied to the combustor. The combustor has a plurality of types of nozzles for injecting fuel. Each of the plurality of types of fuel valves is provided for each of the plurality of types of nozzles. In an operating method of a gas turbine facility, a combustion load command generation step of obtaining a combustion load command value, which is a parameter having a positive correlation with the inlet temperature, which is the temperature of the combustion gas at the inlet of the turbine; a flow rate ratio calculation step of obtaining a flow rate ratio of fuel supplied to each of the plurality of types of nozzles according to the combustion load command value; a valve opening degree calculation step of obtaining a valve opening degree of the fuel valve for each of the plurality of types of nozzles based on the flow rate ratio of fuel supplied to each of the plurality of types of nozzles; a control signal output step of outputting a control signal indicating the valve opening degree to the fuel valve for each of the plurality of types of nozzles; Execute, The combustion load command generation step includes a first load command calculation step of obtaining the combustion load command value for a first fuel, which is the fuel type indicated by a fuel type command from the outside, and a second load command calculation step of obtaining the combustion load command value for a second fuel, which is the fuel type indicated by a fuel type command from the outside. Both the first load command calculation step and the second load command calculation step a maximum temperature output calculation step of obtaining a maximum temperature output, which is a planned output according to the fuel type, with respect to an inlet maximum temperature, which is a predetermined maximum temperature of the inlet temperature; a minimum temperature output calculation step of obtaining a minimum temperature output, which is a planned output according to the fuel type, with respect to an inlet minimum temperature, which is a predetermined minimum temperature of the inlet temperature; a degradation coefficient calculation step of obtaining a degradation coefficient for correcting the maximum temperature output; a degradation correction step of correcting the maximum temperature output using the degradation coefficient; a combustion load command value calculation step of obtaining the combustion load command value using the minimum temperature output, the corrected maximum temperature output, which is the maximum temperature output corrected in the degradation correction step, and the actual output, which is the actual output of the gas turbine; including, The degradation coefficient calculation step includes a deviation calculation step of obtaining a deviation between the corrected maximum temperature output and the actual output, and a coefficient calculation step of obtaining the degradation coefficient according to the deviation during temperature control in which the inlet temperature is controlled to be the inlet maximum temperature. The coefficient calculation step includes a degradation parameter storage step of storing, in a degradation parameter storage unit, a degradation parameter, which is a value obtained by proportional-integral processing with respect to a ratio of the deviation when the deviation is equal to or greater than a predetermined threshold during the temperature control. In the coefficient calculation step, the degradation coefficient based on the degradation parameter stored in the degradation parameter storage unit is output. Operating method of a gas turbine facility.

8. In the operating method of the gas turbine facility according to Claim 7, the first load command calculation step and the second load command calculation step share the deterioration coefficient calculation step with each other. Operating method of a gas turbine facility.

9. In the operating method of the gas turbine facility according to Claim 7 or 8, any one of natural gas, oil, hydrogen, combustible synthesis gas, ammonia, and a mixed fuel combining these is the first fuel, and the other one is the second fuel. Operating method of a gas turbine facility.

Images