Gas turbine control device, gas turbine and gas turbine control method

Abstract

To secure stability of an operating state of a gas turbine while reducing emissions of nitrogen oxide included in combustion gas by injecting water.SOLUTION: This invention relates to a gas turbine control device for controlling a gas turbine including a combustor that can generate combustion gas capable of driving turbine by burning fuel and a water injection mechanism for injecting water into the combustor. The gas turbine control device corrects an output value by applying a first delay function to the output value of the gas turbine. The corrected output value is used for calculating a water injection amount target value of the water injection mechanism, and the water injection mechanism is controlled on the basis of the water injection amount target value.SELECTED DRAWING: Figure 2

Description

[Technical field]

[0001] The present disclosure relates to a gas turbine control device, a gas turbine, and a gas turbine control method. [Background technology]

[0002] For example, gas turbines capable of driving a turbine with combustion gas generated by burning fuel in a combustor are known as a power source for driving a generator in a thermal power plant. In this type of gas turbine, the combustion gas generated in the combustor becomes hot under high load conditions. The amount of nitrogen oxide emissions contained in the combustion gas increases exponentially with an increase in the temperature of the combustion gas. In order to reduce the amount of nitrogen oxide emissions in the combustion gas under such high load conditions, there is a gas turbine equipped with a water injection mechanism that can reduce the amount of nitrogen oxide emissions by injecting water toward the inner cylinder of the combustor and reducing the local high temperature area of ​​the diffusion flame. For example, Patent Document 1 discloses controlling the amount of water injected by the water injection mechanism based on the operating load of the gas turbine. [Prior art documents] [Patent documents]

[0003] [Patent Document 1] Japanese Utility Model Application Publication No. 61-029031 Summary of the Invention [Problem to be solved by the invention]

[0004] In a gas turbine equipped with a water injection mechanism as in Patent Document 1, the output of the gas turbine fluctuates due to hunting of the water injection flow rate in the water injection system, which can cause the operating state to become unstable. This is because the fluctuation in the amount of water injection by the water injection mechanism changes the combustion state, such as the combustion temperature, and the output of the gas turbine fluctuates. Since the water injection amount in the water injection mechanism is controlled based on the output (load) of the gas turbine as in Patent Document 1, once hunting occurs in the water injection amount, the output of the gas turbine also begins to fluctuate. This can cause a vicious cycle in which the control target value of the water injection amount also fluctuates, causing further hunting of the actual value of the water injection amount. This series of events can occur even when the gas turbine is operating at a substantially constant load.

[0005] At least one embodiment of the present disclosure has been made in consideration of the above-mentioned circumstances, and has an object to provide a gas turbine control device, a gas turbine, and a gas turbine control method that can ensure the stability of the operating state of the gas turbine while reducing the emission of nitrogen oxides contained in the combustion gas by injecting water. [Means for solving the problem]

[0006] In order to solve the above problems, a gas turbine control device according to at least one embodiment of the present disclosure includes: a combustor capable of combusting a fuel to generate combustion gas capable of driving a turbine; a water injection mechanism for injecting water into the interior of the combustor; A gas turbine control device for controlling a gas turbine comprising: an output value acquisition unit for acquiring an output value of the gas turbine; an output value correcting unit for correcting the output value by applying a first lag function to the output value; a water injection amount target value calculation unit for calculating a water injection amount target value of the water injection mechanism based on a corrected output value which is the output value corrected by the output value correction unit; a water injection mechanism control unit for controlling the water injection mechanism based on the water injection amount target value; Equipped with.

[0007] In order to solve the above problems, a gas turbine according to at least one embodiment of the present disclosure includes: A gas turbine control device according to at least one embodiment of the present disclosure is provided.

[0008] In order to solve the above problem, a gas turbine control method according to at least one embodiment of the present disclosure includes: a combustor capable of combusting a fuel to generate combustion gas capable of driving a turbine; a water injection mechanism for injecting water into the interior of the combustor; 1. A gas turbine control method for controlling a gas turbine comprising: acquiring an output value of the gas turbine; calculating a corrected output value by correcting the output value by applying a first lag function to the output value; calculating a water injection amount target value of the water injection mechanism based on the corrected output value; controlling the water injection mechanism based on the water injection amount target value; Equipped with. Effect of the Invention

[0009] According to at least one embodiment of the present disclosure, it is possible to provide a gas turbine control device, a gas turbine, and a gas turbine control method that can ensure the stability of the operating state of the gas turbine while reducing the emission of nitrogen oxides contained in the combustion gas by injecting water. [Brief description of the drawings]

[0010] [Figure 1] FIG. 1 is a schematic configuration diagram of a gas turbine according to an embodiment. [Diagram 2] FIG. 1 is a configuration block diagram of a gas turbine control device according to an embodiment. [Diagram 3] FIG. 13 is an explanatory diagram of a lag function LAG. [Figure 4A]4 is an example showing a change in output characteristics when the time constant T is changed in the lag function LAG of FIG. 3. [Figure 4B] 4 is another example showing a change in the output characteristic when the time constant T is changed in the lag function LAG of FIG. 3. [Diagram 5] FIG. 3 is a control flow diagram of the output correction unit in FIG. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0011] Hereinafter, some embodiments of the present disclosure will be described with reference to the accompanying drawings. However, the dimensions, materials, shapes, relative arrangements, etc. of the configurations described as the embodiments or shown in the drawings are merely illustrative examples and are not intended to limit the scope of the present disclosure.

[0012] First, a gas turbine that is a control target of a gas turbine control device according to at least one embodiment of the present disclosure will be described with reference to Fig. 1. Fig. 1 is a schematic configuration diagram of a gas turbine according to one embodiment.

[0013] The gas turbine 1 includes a compressor 2, a combustor 4, and a turbine 6. Compressed air A generated by the compressor 2 is supplied to the combustor 4 as combustion air. In the combustor 4, fuel supplied from a fuel supply system (a liquid fuel supply system 30 or a gaseous fuel supply system 40 described below) is mixed with the compressed air A and combusted to generate combustion gas g. The combustion gas g generated in the combustor 4 drives the turbine 6, whereby electricity is generated by a generator 8 connected to an output shaft of the turbine 6.

[0014] The combustor 4 is disposed downstream of a diffuser 10 that constitutes a flow path for the compressed air A generated by the compressor 2. The combustor 4 includes an outer casing 12 and an inner casing 14 that is disposed inside the outer casing 12 and defines a combustion chamber 16 in which fuel is combusted to generate combustion gas g. The upstream side of the combustion chamber 16 is closed by an end cover 18, and the downstream side of the combustion chamber 16 is connected to a transition piece 20, so that the combustion gas g generated in the combustion chamber 16 is guided to the turbine 6.

[0015] The combustor 4 includes several fuel injection nozzles for injecting fuel into the combustion chamber 16. The gas turbine 1 of this embodiment is a so-called dual-fuel gas turbine capable of handling both liquid fuel, such as fuel oil or liquid ammonia, and gas fuel, such as natural gas, as fuel. A fuel injection nozzle is provided for each type of fuel. Specifically, a swirler 22 is disposed on the upstream side of the inner cylinder 12, and a liquid fuel injection nozzle 24 for injecting liquid fuel as fuel into the combustion chamber 16 is provided at the axial center of the swirler 22. Furthermore, a gas fuel injection nozzle 26 for injecting gas fuel as fuel is provided on the upstream side of the swirler 22.

[0016] A liquid fuel supply system 30 for supplying liquid fuel is connected to the liquid fuel injection nozzle 24. The liquid fuel supply system 30 includes a liquid fuel storage unit 32 for storing liquid fuel such as fuel oil (e.g., liquid fossil fuel such as kerosene or diesel), and a liquid fuel supply line 34 for connecting the liquid fuel storage unit 32 to the liquid fuel injection nozzle 24. The liquid fuel supply line 34 is provided with a supply pump 35 for pressure-feeding the liquid fuel, a flow rate adjustment valve 36 for adjusting the flow rate of the liquid fuel, and a shutoff valve 38.

[0017] A gas fuel supply system 40 for supplying gas fuel is connected to the gas fuel injection nozzle 26. The gas fuel supply system 40 includes a gas fuel storage unit 42 for storing liquid fuel, which is a gaseous fossil fuel such as natural gas, and a gas fuel supply line 44 for connecting the gas fuel storage unit 42 to the gas fuel injection nozzle 26. The gas fuel supply line 44 is provided with a flow rate adjustment valve 46 for adjusting the flow rate of the gas fuel, and a shutoff valve 48.

[0018] Further, the end cover 18 is provided with a water injection nozzle 28 for injecting water into the combustion chamber 16. A water supply system 50 for supplying water is connected to the water injection nozzle 28. The water supply system 50 includes a water storage unit 52 for storing water, and a water supply line 54 for connecting the water storage unit 52 to the water injection nozzle 28. The water supply line 54 is provided with a supply pump 55 for pressurizing water, a flow rate adjustment valve 56 for adjusting the flow rate of water, and a shutoff valve 58.

[0019] In the gas turbine 1 having the above configuration, compressed air A generated in the compressor 2 passes from the diffuser 10 between the outer cylinder 12 and the inner cylinder 14 and is guided to the combustion chamber 16. A part of the compressed air A is introduced into the combustion chamber 16 as cooling air A' for the inner cylinder 14. The compressed air A other than the cooling air A' is turned into a swirling flow by the swirler 22 and flows into the inner cylinder 14. The compressed air A that has flowed from the swirler 22 into the inner cylinder 14 is mixed with the liquid fuel injected from the liquid fuel injection nozzle 24 or the gas fuel injected from the gas fuel injection nozzle 26, and a diffusion flame 60 is formed in the combustion chamber 16.

[0020] The combustion gas g generated by the diffusion flame 60 is introduced into the turbine 6 through the transition piece 20 installed downstream of the combustor 4. After completing its work in the turbine 6, the combustion gas g is discharged to the outside through an exhaust line (not shown). In the operation of such a gas turbine, under conditions where the load of the gas turbine is high (high load conditions), the combustion gas g becomes hot. The amount of emission of nitrogen oxides contained in the combustion gas g increases exponentially with the increase in the temperature of the combustion gas g. Therefore, in order to reduce the amount of emission of nitrogen oxides in the combustion gas g under such high load conditions, water is injected from the water injection nozzle 28 toward the inner tube 12 of the combustor 16, thereby reducing the local high temperature area of ​​the diffusion flame 60 and thereby reducing the amount of emission of nitrogen oxides.

[0021] In the gas turbine 1 equipped with such a water injection mechanism, the operating state may become unstable due to fluctuations in the output of the gas turbine 1 caused by hunting of the water injection amount from the water injection nozzle 28. Such a problem can be suitably solved by the gas turbine control device 100 according to the embodiment described below.

[0022] Next, a gas turbine control device 100 for controlling the gas turbine 1 having the above configuration will be described. Fig. 2 is a configuration block diagram of the gas turbine control device 100 according to one embodiment.

[0023] The gas turbine control device 100 is composed of, for example, a central processing unit (CPU), a random access memory (RAM), a read only memory (ROM), and a computer-readable storage medium. A series of processes for realizing various functions is stored in a storage medium or the like in the form of a program, for example, and the CPU reads this program into the RAM or the like and executes information processing and arithmetic processing to realize various functions. The program may be installed in a ROM or other storage medium in advance, may be provided in a state stored in a computer-readable storage medium, or may be distributed via wired or wireless communication means. The computer-readable storage medium may be a magnetic disk, a magneto-optical disk, a CD-ROM, a DVD-ROM, a semiconductor memory, or the like.

[0024] As shown in FIG. 2, the gas turbine control device 100 includes an output value acquisition unit 102, a fuel signal acquisition unit 104, an inlet temperature acquisition unit 106, an output value correction unit 108, a water injection amount target value calculation unit 110, a fuel determination unit 112, a temperature correction value calculation unit 114, and a water injection mechanism control unit 116.

[0025] The output value acquisition unit 102 is configured to acquire the output G of the gas turbine 1. The output G acquired by the output value acquisition unit 102 may be a measured value by a sensor installed in the gas turbine 1, or may be a calculated value calculated from the measured value.

[0026] The fuel signal acquiring unit 104 is configured to acquire a fuel signal Sf corresponding to the type of fuel supplied to the combustor 4. As described above, in the gas turbine 1 according to this embodiment, either liquid fuel or gaseous fuel can be supplied to the combustor 4 from the liquid fuel supply system 30 or the gaseous fuel supply system 40. The fuel signal Sf is a binary signal that indicates, for example, High when liquid fuel is supplied to the combustor 4 and Low when gaseous fuel is supplied.

[0027] The inlet temperature acquisition unit 106 is configured to acquire the inlet temperature T of the compressor 2. The inlet temperature T acquired by the inlet temperature acquisition unit 106 may be a measured value by a sensor installed at the inlet of the compressor 2, or may be a calculated value calculated from the measured value.

[0028] The output value correcting unit 108 is configured to correct the output value G acquired by the output value acquiring unit 102. In particular, the output value correcting unit 108 outputs a corrected output value G' calculated by applying a first lag function LAG1 to the output value G acquired by the output value acquiring unit 102. The first lag function LAG1 has a first time constant T1, and the corrected output value G' is output as a result of suppressing fluctuations in the output value G of the gas turbine in accordance with the first time constant T1.

[0029] Here, the function of the lag function LAG will be described with reference to Figures 3 and 4. Figure 3 is an explanatory diagram of the lag function LAG, and Figures 4A and 4B are an example showing the change in output characteristics when the time constant T is changed in the lag function LAG of Figure 3, where the dashed line indicates the input X(n) to the lag function LAG and the solid line indicates the output Y(n) to the lag function LAG.

[0030] The relationship between the input X and the output Y of the lag function LAG shown in FIG. 3 is expressed by the following equation using a time constant T, the number of steps n, and the time difference between steps dt. Y(n)=Y(n-1)+{X(n)-Y(n-1)}×dt / (T1+dt) (1)

[0031] In this lag function LAG, when the time constant T is a value larger than dt, the output Y(n) is close to the output Y(n-1) of the previous step. For example, when the time constant T is 10 times dt, the output Y(n) of the lag function LAG is smoother than the input X(n), as shown by the solid line in FIG. 4A. On the other hand, when the time constant T is close to dt, the output Y(n) of the lag function LAG1 is close to the input X(n). For example, when the time constant T is the same as dt, the output Y(n) of the lag function LAG is close to the input X(n), as shown by the dashed line in FIG. 4B.

[0032] The first lag function LAG1 used in the output value correction unit 108 is such a lag function LAG with a first time constant T1 set as the time constant T. The first time constant T1 is variably set based on the output value G of the gas turbine 1. Here, with reference to Fig. 5, a method for setting the first time constant T1 will be described based on the control flow of the output correction unit 108. Fig. 5 is a control flow diagram of the output correction unit 108 in Fig. 2.

[0033] As shown in FIG. 5, in the output value correction unit 108, the output value G acquired by the output value acquisition unit 102 is input to a second lag function LAG2. The second lag function LAG2 is a function in which the time constant is set to a second time constant T2 in the lag function LAG described with reference to FIG. 3 and FIG. 4. The second time constant T2 is set to a predetermined value in advance so as to be a value equal to or greater than a predetermined ratio with respect to the time difference dt between steps. For example, T2 is set to a value equal to or greater than 10 times the time difference dt between steps. The output value G acquired by the output value acquisition unit 102 and the output of the second lag function LAG2 are input to a differentiator to obtain a difference Δ between the two. The absolute value of this difference Δ is an index indicating how much the output value has changed per predetermined time.

[0034] The absolute value of the difference Δ is input to a first function fx1, and a corresponding first time constant T1 is obtained. The first function fx1 is a characteristic function that specifies the relationship between the absolute value of the difference Δ and the first time constant T1, and is prepared in advance. In this manner, the first time constant T1 is variably set based on the difference Δ between the output value G acquired by the output value acquisition unit 102 and the result of applying the second lag function LAG2 having a preset second time constant T2 to the output value G.

[0035] The first time constant T1 is set to be smaller as the absolute value of the difference Δ increases. For example, when the absolute value of the difference Δ is equal to or larger than a predetermined threshold value Δref, the first time constant T1 is set to a first value (e.g., less than 5 times dt) that is close to the time difference dt between steps, and when the absolute value of the difference Δ is less than the predetermined threshold value Δref, the first time constant T1 is set to a second value (e.g., more than 10 times dt) that is a value that is equal to or larger than a predetermined ratio with respect to the time difference dt between steps. In this way, when the absolute value of the difference Δ is small, by setting the first time constant T1 to the second value that is larger than the first value, a corrected output value G' that more effectively suppresses the influence of minute fluctuations in the output value G of the gas turbine 1 can be obtained.

[0036] As shown in FIG. 5, the output value correction unit 108 may include a trend determination unit 109 for performing trend determination based on an output request signal Sm for the gas turbine 1. The trend determination unit 109 determines whether or not the amount of change over time of the output request signal Sm is equal to or greater than a reference value by continuously acquiring the output request signal Sm. When the amount of change over time of the output request signal Sm is equal to or greater than the reference value, the gas turbine 1 is in a so-called transient state in which the output value G of the gas turbine 1 is actively changed based on the output request signal Sm. Therefore, the trend determination unit 109 disables the first delay function LAG1 so that the output value G acquired by the output value acquisition unit 102 is output as it is as the corrected output value G' in the gas turbine 1 in the transient state. As a result, the corrected output value G' faithfully coincides with the output value G, and operation control according to the output request signal Sm that changes from moment to moment becomes possible.

[0037] On the other hand, when the amount of change over time of the output request signal Sm is less than the reference value, the output value correction unit 108 outputs a corrected output value G' by applying the first lag function LAG1 to the output value G acquired by the output value acquisition unit 102 as described above (in this case, the trend determination unit 109 does not affect the first lag function LAG1).

[0038] Returning to Fig. 2, water injection amount target value calculation unit 110 is configured to calculate a target value of the water injection amount in the water injection mechanism (water injection amount target value Wt) based on the corrected output value G' output from the output value correction unit 108. The relationship between the corrected output value G' and the water injection amount target value Wt is prepared in advance as a characteristic function. Water injection amount target value calculation unit 110 calculates the water injection amount target value Wt corresponding to the corrected output value G' output from the output value correction unit 108 by referring to the characteristic function.

[0039] The fuel determination unit 112 is configured to determine the type of fuel based on the fuel signal Sf acquired by the fuel signal acquisition unit 104. In this embodiment, as described above, the fuel signal Sf is a binary signal that indicates, for example, High when liquid fuel is supplied to the combustor 4 and Low when gaseous fuel is supplied. Therefore, the fuel determination unit 112 determines the type of fuel based on whether the fuel signal Sf is High or Low. When the fuel determination unit 112 determines that the fuel supplied to the combustor 4 is liquid fuel because the fuel signal Sf is High, the fuel determination unit 112 enables the output of the water injection amount target value calculation unit 110 to permit the execution of water injection. On the other hand, when the fuel determination unit 112 determines that the fuel supplied to the combustor 4 is gaseous fuel because the fuel signal Sf is Low, the fuel determination unit 112 disables the output of the water injection amount target value calculation unit 110 to prohibit the execution of water injection.

[0040] The temperature correction value calculation unit 114 is configured to calculate a temperature correction coefficient c based on the inlet temperature T of the compressor 2 acquired by the inlet temperature acquisition unit 106. The relationship between the inlet temperature T and the temperature correction coefficient c is prepared in advance as a characteristic function. The temperature correction value calculation unit 114 calculates the temperature correction coefficient c corresponding to the inlet temperature T acquired by the inlet temperature acquisition unit 106 by referring to the characteristic function. The temperature correction coefficient c is multiplied by the water injection amount target value Wt and used to correct the water injection amount target value Wt (the water injection amount target value Wt after correction is referred to as the corrected water injection amount target value Wt').

[0041] The water injection mechanism control unit 116 is configured to control the water injection mechanism based on the corrected water injection amount target value Wt'. In this embodiment, the opening degree of the supply pump 55 or the flow rate adjustment valve 56 provided in the water supply system 50 is controlled so that the water injection amount from the water injection nozzle 28 becomes the corrected water injection amount target value Wt'.

[0042] As described above, according to each of the above embodiments, the water injection amount by the water injection mechanism is controlled based on the corrected output value G' corrected by applying the first lag function LAG1 to the output value G of the gas turbine 1. As a result, even if the output value G of the gas turbine 1 fluctuates due to hunting occurring in the water injection amount by the water injection mechanism, the fluctuation is suppressed by the first lag function LAG1. Since fluctuations are suppressed in the water injection amount target value calculated based on the corrected output value G' in which the fluctuations are suppressed in this manner, by controlling the water injection amount based on the water injection amount target value, it is possible to effectively reduce the emission of nitrogen oxides contained in the combustion gas by water injection while maintaining a stable operating state of the gas turbine 1.

[0043] In addition, within the scope of the present disclosure, the components in the above-described embodiments may be replaced with well-known components as appropriate, and the above-described embodiments may be combined as appropriate.

[0044] The contents described in each of the above embodiments can be understood, for example, as follows.

[0045] (1) A gas turbine control device according to one aspect includes: a combustor capable of combusting a fuel to generate combustion gas capable of driving a turbine; a water injection mechanism for injecting water into the interior of the combustor; A gas turbine control device for controlling a gas turbine comprising: an output value acquisition unit for acquiring an output value of the gas turbine; an output value correcting unit for correcting the output value by applying a first lag function to the output value; a water injection amount target value calculation unit for calculating a water injection amount target value of the water injection mechanism based on a corrected output value which is the output value corrected by the output value correction unit; a water injection mechanism control unit for controlling the water injection mechanism based on the water injection amount target value; Equipped with.

[0046] According to the above aspect (1), the water injection amount by the water injection mechanism is controlled based on a corrected output value corrected by applying the first lag function to the output value of the gas turbine. As a result, even if the output of the gas turbine fluctuates due to hunting occurring in the water injection amount by the water injection mechanism, the fluctuation is suppressed by the first lag function. Since fluctuations are suppressed in the water injection amount target value calculated based on the corrected output value whose fluctuations are suppressed in this manner, by controlling the water injection amount based on the water injection amount target value, it is possible to effectively reduce the emission of nitrogen oxides contained in the combustion gas by water injection while maintaining a stable operating state of the gas turbine.

[0047] (2) In another embodiment, in the above embodiment (1), The first delay function has a first time constant that is variably set based on the output value acquired by the output value acquisition unit.

[0048] According to the above aspect (2), the first time constant of the first lag function for correcting the output value is variably set based on the output value of the gas turbine.

[0049] (3) In another embodiment, in the above embodiment (2), The first time constant is set based on the difference between the output value acquired by the output value acquisition unit and a result of applying a second lag function having a preset second time constant to the output value.

[0050] According to the above aspect (3), the first time constant of the first lag function for correcting the output value is variably set based on the difference between the output value of the gas turbine and the output value of the gas turbine to which a second lag function having a preset second time constant is applied.

[0051] (4) In another embodiment, in the above embodiment (3), The first time constant is set to be smaller as the difference is larger.

[0052] According to the above aspect (4), the first time constant of the first delay function for correcting the output value is The time constant is variably set so as to become smaller as the difference between the output value of the gas turbine and the output value to which the second delay function is applied increases. As a result, the smaller the difference is, the larger the time constant becomes, thereby making it possible to suppress the effects of minute fluctuations in the output value of the gas turbine.

[0053] (5) In another embodiment, in the above embodiment (4), The first time constant is If the difference is greater than or equal to a predetermined threshold, it is set to a first value; If the difference is less than the predetermined threshold, it is set to a second value greater than the first value.

[0054] According to the above aspect (5), when the difference between the output value of the gas turbine and the output value to which the second lag function is applied is equal to or greater than the threshold and thus relatively large, the first time constant of the first lag function is set to a first value. On the other hand, when the difference between the output value of the gas turbine and the output value to which the second lag function is applied is less than the threshold and thus relatively small, the first time constant of the first lag function is set to a second value. In this way, when the difference is small, the first time constant is set to a second value larger than the first value, thereby making it possible to more effectively suppress the influence of minute fluctuations in the output value of the gas turbine.

[0055] (6) In another embodiment, in any one of the above (1) to (5), The output value correcting unit outputs the output value acquired by the output value acquiring unit as the corrected output value when a time change amount of an output request signal for the gas turbine is equal to or greater than a reference value.

[0056] According to the above aspect (6), when the time change amount of the output demand signal for the gas turbine is equal to or greater than a reference value and the operating state of the gas turbine is actively changed, the correction of the output value by application of the first lag function is invalidated. In this case, the output value acquired by the output value acquisition unit is output as it is as the corrected output value, so that the behavior of the gas turbine in a transient operating state is not hindered.

[0057] (7) In another embodiment, in any one of the above (1) to (6), The water injection amount target value is corrected using a temperature correction coefficient calculated based on the inlet temperature of the compressor.

[0058] According to the above aspect (7), the target value of the water injection amount for stably controlling the gas turbine can be accurately determined by correcting the target value of the water injection amount using the inlet temperature of the compressor.

[0059] (8) A gas turbine according to one embodiment includes: The gas turbine control device according to any one of the above aspects (1) to (7) is used for control.

[0060] According to the above aspect (8), it is possible to realize a gas turbine that can maintain a stable operating state while effectively reducing the amount of nitrogen oxides emitted from the combustion gas by water injection.

[0061] (9) A gas turbine control method according to one aspect includes the steps of: a combustor capable of combusting a fuel to generate combustion gas capable of driving a turbine; a water injection mechanism for injecting water into the interior of the combustor; 1. A gas turbine control method for controlling a gas turbine comprising: acquiring an output value of the gas turbine; calculating a corrected output value by correcting the output value by applying a first lag function to the output value; calculating a water injection amount target value of the water injection mechanism based on the corrected output value; controlling the water injection mechanism based on the water injection amount target value; Equipped with.

[0062] According to the above aspect (9), the water injection amount by the water injection mechanism is controlled based on a corrected output value corrected by applying the first lag function to the output value of the gas turbine. As a result, even if the output of the gas turbine fluctuates due to hunting occurring in the water injection amount by the water injection mechanism, the fluctuation is suppressed by the first lag function. By controlling the water injection amount based on the corrected output value in which fluctuation is suppressed in this manner, it is possible to effectively reduce the emission of nitrogen oxides contained in the combustion gas by water injection while maintaining a stable operating state of the gas turbine. [Explanation of symbols]

[0063] 1. Gas turbine 2. Compressor 4. Combustor 6. Turbine 8. Generator 10 Diffuser 12 Outer cylinder 14 Inner cylinder 16 Combustion chamber 18 End cover 20 Transition Piece 22 Swara 24 Liquid fuel injection nozzle 26 Gaseous fuel injection nozzle 28 Water Injection Nozzle 30 Liquid fuel supply system 32 Liquid fuel storage section 34 Liquid fuel supply line 35 Supply Pump 36 Flow control valve 38 Shut-off valve 40 Gaseous fuel supply system 42 Gaseous fuel storage unit 44 Gaseous fuel supply line 46 Flow Control Valve 48 Shut-off valve 50 Water supply system 52 Water Storage Unit 54 Water Supply Line 55 Supply Pump 56 Flow control valve 58 Shut-off valve 60 Diffusion flame 100 Gas turbine control device 102 Output value acquisition unit 104 Fuel signal acquisition section 106 Inlet temperature acquisition section 108 Output value correction section 110 Water injection amount target value calculation unit 112 Fuel determination section 114 Temperature correction value calculation unit 116 Water injection mechanism control unit

Claims

1. a combustor capable of combusting a fuel to generate combustion gas capable of driving a turbine; a water injection mechanism for injecting water into the interior of the combustor; A gas turbine control device for controlling a gas turbine comprising: an output value acquisition unit for acquiring an output value of the gas turbine; an output value correcting unit for correcting the output value by applying a first lag function to the output value; a water injection amount target value calculation unit for calculating a water injection amount target value of the water injection mechanism based on a corrected output value which is the output value corrected by the output value correction unit; a water injection mechanism control unit for controlling the water injection mechanism based on the water injection amount target value; A gas turbine control device comprising:

2. 2 . The gas turbine control device according to claim 1 , wherein the first lag function has a first time constant that is variably set based on the output value acquired by the output value acquisition unit.

3. 3. The gas turbine control device according to claim 2, wherein the first time constant is set based on a difference between the output value acquired by the output value acquisition unit and a result of applying a second lag function having a preset second time constant to the output value.

4. The gas turbine control device according to claim 3 , wherein the first time constant is set to be smaller as the difference is larger.

5. The first time constant is If the difference is greater than or equal to a predetermined threshold, it is set to a first value; The gas turbine control system of claim 4 , wherein if the difference is less than the predetermined threshold, the difference is set to a second value greater than the first value.

6. 3. The gas turbine control device according to claim 1, wherein the output value correction unit outputs the output value acquired by the output value acquisition unit as the corrected output value when a time change amount of an output request signal for the gas turbine is equal to or greater than a reference value.

7. 3. The gas turbine control device according to claim 1, wherein the water injection amount target value is corrected using a temperature correction coefficient calculated based on an inlet temperature of the compressor.

8. A gas turbine controlled by the gas turbine control device according to claim 1 or 2.

9. a combustor capable of combusting a fuel to generate combustion gas capable of driving a turbine; a water injection mechanism for injecting water into the interior of the combustor; 1. A gas turbine control method for controlling a gas turbine comprising: acquiring an output value of the gas turbine; calculating a corrected output value by correcting the output value by applying a first lag function to the output value; calculating a water injection amount target value of the water injection mechanism based on the corrected output value; controlling the water injection mechanism based on the water injection amount target value; A gas turbine control method comprising:

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