Information processing method, information processor and program

Abstract

To provide an information processing method, an information processor and a program capable of shortening a time required for data accumulation of a database that stores information related to an operation history of a gas turbine.SOLUTION: An information processing method includes: a first step of accumulating information related to an operation history of a gas turbine including a combustion load command value in a database during an operation of the gas turbine; a second step of calculating a coefficient for adjusting the acquired combustion load command value in a predetermined operating state of the gas turbine to a combustion load command value to be obtained at a gas turbine inlet combustion gas temperature calculated on the basis of at least measured exhaust gas temperature and cabin pressure; and a third step of correcting each combustion load command value accumulated in the database on the basis of the coefficient. The combustion load command value is an index value obtained by making the gas turbine inlet combustion gas temperature dimensionless.SELECTED DRAWING: Figure 18

Description

Technical Field

[0001] The present disclosure relates to an information processing method, an information processing apparatus, and a program.

Background Art

[0002] Patent Document 1 describes a gas turbine control method in which an optimal operating condition is automatically searched by applying an operation amount such as a pilot ratio, and correction for suppressing combustion vibration generated during gas turbine operation is performed so as not to deviate from the operating state at the ideal fuel flow rate and air flow rate assumed at the time of design. In the gas turbine control method described in Patent Document 1, using a first database, at least one of the fuel flow rate or the air flow rate supplied to the combustor is varied in a state where combustion vibration does not occur in the gas turbine to search for an optimal operating condition, and the stored content of the first database is updated according to the obtained operating condition. This first database stores information associating control system settings performed when combustion vibration occurs with changes in the combustion state in the combustor, information such as frequency analysis results obtained by analyzing based on the accumulated information, and the like. Further, in the gas turbine control method of Patent Document 1, when sufficient data is not accumulated in the first database, for example, immediately after installing the gas turbine, the direction of adjustment is determined based on a mathematical model showing standard combustion characteristics, constraint information, experience information, and the like.

Prior Art Documents

Patent Documents

[0003]

Patent Document 1

Summary of the Invention

Problems to be Solved by the Invention

[0004] As described above, in the gas turbine control method described in Patent Document 1, for example, immediately after installing a gas turbine, there is a problem that a database for storing optimal operating conditions in a combustor may not be available until sufficient data is accumulated.

[0005] The present disclosure has been made in view of the above circumstances, and an object thereof is to provide an information processing method, an information processing apparatus, and a program capable of shortening the time required for data accumulation in a database that stores information related to the operation results of a gas turbine.

Means for Solving the Problem

[0006] The information processing method according to the present disclosure includes a first step of accumulating, in a database, information related to the operation results of the gas turbine including a combustion load command value during operation of the gas turbine; a second step of calculating, in a predetermined operation state of the gas turbine, a coefficient for adjusting the obtained combustion load command value to the combustion load command value that should be obtained at the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure; and a third step of correcting each of the combustion load command values stored in the database based on the coefficient, wherein the combustion load command value is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature by linear interpolation based on a first gas turbine output corresponding to a first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor of the gas turbine and the opening degree of the inlet guide vane of the gas turbine, a second gas turbine output corresponding to a second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor and the opening degree of the inlet guide vane, and the output of the gas turbine.

[0007] The information processing apparatus according to the present disclosure accumulates information related to the operation results of the gas turbine, including the combustion load command value, in a database during the operation of the gas turbine, and in a predetermined operation state of the gas turbine, the obtained combustion load command value is adjusted to the combustion load command value that should be obtained by the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure. A coefficient for adjustment is calculated, and based on the coefficient, each of the combustion load command values stored in the database is corrected. The combustion load command value is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature by linear interpolation based on the first gas turbine output corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor of the gas turbine and the opening degree of the inlet guide vane of the gas turbine, the second gas turbine output corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor and the opening degree of the inlet guide vane, and the output of the gas turbine.

[0008] The program according to the present disclosure includes a first step of accumulating information related to the operation results of the gas turbine, including the combustion load command value, in a database during the operation of the gas turbine, a second step of calculating a coefficient for adjusting the obtained combustion load command value to the combustion load command value that should be obtained by the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure in a predetermined operation state of the gas turbine, and a third step of correcting each of the combustion load command values stored in the database based on the coefficient. The combustion load command value is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature by linear interpolation based on the first gas turbine output corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor of the gas turbine and the opening degree of the inlet guide vane of the gas turbine, the second gas turbine output corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor and the opening degree of the inlet guide vane, and the output of the gas turbine, and causes the computer to execute each step.

Advantages of the Invention

[0009] According to the information processing method, information processing apparatus, and program of the present disclosure, it is possible to shorten the time required for data accumulation in a database that stores information related to the operation results of a gas turbine.

Brief Description of the Drawings

[0010]

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Embodiments for Carrying Out the Invention

[0011] Hereinafter, an information processing method, an information processing apparatus, and a program according to embodiments of the present disclosure will be described with reference to the drawings. Note that the dimensions, materials, shapes, relative arrangements, properties, characteristics, performances, functions, etc. of the constituent parts described in this embodiment are not intended to limit the scope of this disclosure thereto, but are merely illustrative examples, unless otherwise specifically described. Also, in each figure, the same or corresponding configurations are denoted by the same reference numerals, and the description thereof will be omitted as appropriate.

[0012] (Schematic Configuration of Gas Turbine) First, the gas turbine 2 will be briefly described using FIG. 1 showing a schematic configuration of the gas turbine and FIG. 2 which is a cross-sectional view for explaining the schematic configuration of the combustor. The gas turbine 2 shown in FIG. 1 has a compressor 22 having an inlet guide vane (IGV) 26, and a gas turbine main body 21 having a turbine 24 to which the compressor 22 and, as an example, a generator 40 are connected via a rotating shaft 39. Combustion gas is supplied to this turbine 24 from a combustor 23 via a combustion gas introduction pipe 38, and the combustion gas is discharged to the outside as exhaust gas (exhaust) through a pipe.

[0013] The rotation of the turbine 24 is transmitted to the compressor 22 via the rotating shaft 39, and outside intake air 25 is taken in from an intake inlet provided with a filter to generate compressed air, and the compressed air is supplied from a compressed air introduction section 27 to the combustor 23 for use in combustion. The inlet guide vane 26 provided in this compressor 22 is a rotating vane on the air introduction side of the compressor 22, and by controlling the angle of the rotating vane of this inlet guide vane 26, that is, the valve opening degree, it is possible to adjust the flow rate of air introduced into the compressor 22 (compressor intake air flow rate) even at a constant rotational speed.

[0014] The combustor 23 is connected to a compressed air introduction section 27, a bypass air introduction pipe 36, a bypass valve 35, and a bypass air mixing pipe 37 to form a combustion section 110. The compressed air introduction section 27 is a space that is a pipe connected to the compressor 22 and guides air into the passenger compartment of the combustor 23, and discharges the compressed air from the compressor to the combustor 23. One end of the bypass air introduction pipe 36 is open and connected inside the compressed air introduction section 27, and the other end is connected to a bypass valve 35 that controls the flow rate of air passing through the bypass air introduction pipe 36, and is a pipe that bypasses the portion of the compressed air discharged from the compressor that is not supplied to the combustor 23 to the turbine 24. Further, the bypass air mixing pipe 37 connected to the other end side of the bypass valve 35 is connected to the combustion gas introduction pipe 38 and supplies the air that has passed through the bypass valve 35 to the combustion gas introduction pipe 38 so as to be mixed with the combustion gas generated in the combustor 23.

[0015] Also, to the combustor 23, main fuel is supplied via the main fuel flow control valve 28 and the main fuel supply valve 29, top-hat fuel is supplied via the top-hat fuel flow control valve 30 and the top-hat fuel supply valve 31, and pilot fuel is supplied via the pilot fuel flow control valve 32 and the pilot fuel supply valve 33, respectively. The main fuel flow control valve 28 is connected on one side to a pipe for supplying fuel from the outside and on the other side to a pipe connected to a plurality of main fuel supply valves 29. The main fuel flow control valve 28 controls the flow rate of the fuel supplied from the outside to the combustor 23, and the main fuel supply valve 29 controls the fuel supplied to the main burner (main nozzle) of the combustor 23.

[0016] The top-hat fuel flow control valve 30 is connected on one side to a pipe for supplying fuel from the outside and on the other side to a plurality of top-hat fuel supply valves 31. The top-hat fuel flow control valve 30 controls the flow rate of the fuel supplied from the outside to the combustor 23, and the top-hat fuel supply valve 31 controls the fuel supplied to the top-hat burner. The pilot fuel flow control valve 32 is connected on one side to a pipe for supplying fuel from the outside and on the other side to a plurality of pilot fuel supply valves 33. The pilot fuel flow control valve 32 controls the flow rate of the fuel supplied from the outside to the combustor 23, and the pilot fuel supply valve 33 controls the fuel supplied to the pilot burner.

[0017] As shown in FIG. 2, the combustor 23 is composed of a plurality of types of fuel nozzles, with the pilot nozzle 44 at the center of the inner cylinder, the main nozzle 45 around it, and the top hat nozzle 47 provided between the inner combustor cylinder 42 and the outer combustor cylinder 41. Among these, the pilot nozzle 44 is a fuel nozzle for diffusion combustion aimed at achieving combustion stability, etc. The main nozzle 45 is a fuel nozzle for premixed combustion that mixes the main fuel gas and compressed air upstream of the combustion section for the purpose of NOx reduction, etc., and then burns them. A plurality of main nozzles 45 are provided around the pilot nozzle 44. The top hat nozzle 47 is a fuel nozzle for premixed combustion that burns the top hat fuel gas and compressed air after mixing them even more upstream than in the case of the main nozzle 45 for the purpose of further reducing NOx, etc. A plurality of top hat nozzles 47 are provided on the outer peripheral side further than the main nozzle 45. In FIG. 2, 43 is the combustor tail pipe.

[0018] Returning to FIG. 1 again, the air introduced from the outside is compressed by the compressor 22 and supplied to each combustor 23. A part of the fuel reaches the pilot fuel supply valve 33 and the top hat fuel supply valve 31 of each combustor 23 via the pilot fuel flow control valve 32 and the top hat fuel flow control valve 30, and is introduced into each combustor 23 from there. The remaining fuel reaches the main fuel supply valve 29 of each combustor 23 via the main fuel flow control valve 28 and is introduced into each combustor 23 from there. The introduced air and fuel burn in each combustor 23, and the combustion gas generated is introduced into the turbine 24 to rotate the turbine 24, and the generator 40 generates electricity by the rotational energy.

[0019] (Gas Turbine System) FIG. 3 is a block diagram showing a functional configuration for controlling the gas turbine 2 in a gas turbine system 1 including the gas turbine 2 and the gas turbine control device 3, and FIG. 4 is a detailed block diagram of the automatic adjustment unit 10 in the gas turbine control device 3 of FIG. 3. As shown in FIG. 3, in order to control the gas turbine 2 with the gas turbine control device 3, the gas turbine 2 is provided with a process quantity measurement unit 4, a pressure fluctuation measurement unit (sensor) 5, an acceleration measurement unit (sensor) 6, a NOx measurement unit 7, and an operation mechanism 8. Further, the controller 9 includes a CLCSO (combustion load command value) calculator 20. Note that the gas turbine control device 3 is an example of a configuration of the "information processing device" according to the present disclosure.

[0020] The process quantity measurement unit 4 is various measuring devices installed at appropriate parts on the gas turbine 2 to measure the process quantity indicating the operating conditions and operating state during the operation of the gas turbine 2, and the measurement results are output to the controller 9 of the gas turbine control device 3 at predetermined times t1, t2,.... Here, the process quantity (plant state quantity) is, for example, bypass valve opening degree, pilot ratio, top hat ratio, atmospheric temperature, generator output (generated power, generated current, generated voltage), cabin pressure (compressor outlet pressure; cabin pressure), intake pressure (compressor inlet pressure), CLCSO, turbine exhaust gas temperature, humidity, fuel flow rate and pressure at each part, air flow rate and pressure at each part, combustion gas temperature, combustion gas flow rate, combustion gas pressure in the combustor 23 (FIG. 1), rotation speed of the compressor 22 and the turbine 24, nitrogen oxides (NOx), carbon monoxide (CO), etc. contained in the exhaust gas from the turbine 2, and the concentration of emissions such as these. This process quantity is divided into "operable operation quantity (plant data)" such as the amount of fuel and air supplied to the gas turbine 2, and "non-operable state quantity" such as meteorological data such as atmospheric temperature and the magnitude of the load of the generator determined by requirements (generator output).

[0021] The pressure fluctuation measurement unit 5 is a pressure measuring device attached to each of the plurality of combustors 23, and outputs the measured values of the pressure fluctuations in each combustor 23 generated by combustion to the gas turbine control device 3 at predetermined times t1, t2,... according to commands from the controller 9. The acceleration measurement unit 6 is an acceleration measuring device attached to each combustor 23, and measures the acceleration (second derivative of position) of each combustor 23 generated by combustion at predetermined times t1, t2,... according to commands from the controller 9, and outputs the measured values to the gas turbine control device 3. The NOx measurement unit 7 is a NOx measuring device included in the exhaust gas of each combustor 23, and measures the NOx generated by combustion at predetermined times t1, t2,... according to commands from the controller 9, and outputs the measured values to the gas turbine control device 3.

[0022] The operation mechanism 8 is a mechanism that operates, according to commands from the controller 9, the opening degrees of the main fuel flow control valve 28 and the main fuel supply valve 29, the opening degrees of the top hat fuel flow control valve 30 and the top hat fuel supply valve 31, the opening degrees of the pilot fuel flow control valve 32 and the pilot fuel supply valve 33, the opening degree of the bypass valve 35, the angle of the rotating blades of the inlet guide vanes 26 of the compressor 22, etc., thereby performing control of the flow rate of the main fuel, control of the flow rate of the top hat fuel, control of the flow rate of the pilot fuel, control of the flow rate of the air supplied to each combustor 23, control of the flow rate of the air introduced into the compressor 22, etc. Specifically, the control of the flow rate of the air supplied to each combustor 23 is achieved by increasing (or decreasing) the opening degree of the bypass valve 35 in each combustor 23 and increasing (or decreasing) the air flow rate flowing through the bypass side, thereby controlling the flow rate of the air supplied to the combustor 23.

[0023] The gas turbine control device 3 includes a controller 9 and an automatic adjustment unit 10. The controller 9 receives the measured values output from the process quantity measurement unit 4, the pressure fluctuation measurement unit 5, and the acceleration measurement unit 6, and transfers them to the automatic adjustment unit 10. Further, based on commands and the like from the automatic adjustment unit 10, the controller 9 outputs signals for operating the main fuel flow control valve 28, the main fuel supply valve 29, the top hat fuel flow control valve 30, the top hat fuel supply valve 31, the pilot fuel flow control valve 32, the pilot fuel supply valve 33, the bypass valve 35, and the inlet guide vane 26 with the operating mechanism 8.

[0024] (Controller) FIG. 5 is a block diagram showing an outline of the processing flow in the controller 9. Based on FIG. 5, the outline of the processing flow of the controller 9 will be described. First, the CLCSO is calculated based on the generator output, the IGV opening command value, the intake air temperature, the intake air flow rate, the turbine bypass ratio (turbine bypass flow rate / intake air flow rate) which is the ratio of the turbine bypass flow rate to the intake air flow rate, and the atmospheric pressure ratio (atmospheric pressure / standard atmospheric pressure) which is the ratio of the atmospheric pressure to the standard atmospheric pressure. This CLCSO is a value obtained by dimensionlessizing the gas turbine inlet combustion gas temperature (the temperature of the fuel gas at the inlet of the gas turbine main body flowing from the combustor 23 to the gas turbine main body 21 (turbine 24)), that is, a value proportional to the gas turbine inlet combustion gas temperature (details will be described later). Then, based on this CLCSO, the pilot ratio which is the ratio of the pilot fuel gas flow rate (weight flow rate) to the total fuel gas flow rate (weight flow rate), the top hat ratio which is the ratio of the top hat fuel gas flow rate (weight flow rate) to the total fuel gas flow rate (weight flow rate), and the main ratio which is the ratio of the main fuel gas flow rate (weight flow rate) to the total fuel gas flow rate (weight flow rate) are obtained.

[0025] Subsequently, based on these pilot ratios, top hat ratios, and main ratios, respective mass flow rates are determined, namely, the pilot fuel gas flow rate GfPL, the top hat fuel gas flow rate GfTH, and the main fuel gas flow rate GfMA. Further, based on these pilot fuel gas flow rate GfPL, top hat fuel gas flow rate GfTH, and main fuel gas flow rate GfMA, the Cv value of the pilot fuel flow control valve 32, the Cv value of the top hat fuel flow control valve 30, and the Cv value of the main fuel flow control valve 28 are respectively determined. Then, based on these Cv values of the pilot fuel flow control valve 32, top hat fuel flow control valve 30, and main fuel flow control valve 28, a pilot fuel flow control valve opening command value, a top hat fuel flow control valve opening command value, and a main fuel flow control valve opening command value are respectively determined. Also, regarding the bypass valve 35, a bypass valve opening command value is determined based on the CLCSO.

[0026] Next, the processing of the controller 9 will be described in detail. Hereinafter, regarding the processing of the controller 9, first, the processing until the CLCSO is calculated by the CLCSO calculator 20 will be described.

[0027] (Calculation of CLCSO) In this embodiment, in order to make the pilot ratio, top hat ratio, main ratio, and bypass valve opening degree functions of the gas turbine inlet combustion gas temperature TIT, which is the original idea, the CLCSO obtained by dimensionlessizing the gas turbine inlet combustion gas temperature TIT is used as a control parameter. For this purpose, the CLCSO is calculated. As shown in FIG. 6, it is assumed that the CLCSO is in a proportional relationship with the gas turbine inlet combustion gas temperature TIT (CLCSO ∝ TIT). In the illustrated example, the CLCSO corresponding to when the gas turbine inlet combustion gas temperature TIT is 700°C as the first gas turbine inlet combustion gas temperature is 0%, and the CLCSO corresponding to when the gas turbine inlet combustion gas temperature TIT is 1500°C as the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature is 100%. Note that the first gas turbine inlet combustion gas temperature and the second gas turbine inlet combustion gas temperature serving as the criteria for calculating the CLCSO are not limited to 700°C and 1500°C, and can be set as appropriate.

[0028] The CLCSO is calculated based on the gas turbine output (generator output). For this purpose, considering the IGV opening degree and intake air temperature as illustrated in FIG. 7, and further considering the turbine bypass ratio and the atmospheric pressure ratio (atmospheric pressure / standard atmospheric pressure: for example, the average atmospheric pressure at the gas turbine installation location is used as the standard atmospheric pressure), the relationship (function) between the generator output (gas turbine output) and the CLCSO is set.

[0029] That is, first, set the generator output (gas turbine output) at 700 °C MW, which is the generator output when the gas turbine inlet combustion gas temperature TIT is 700 °C defined as the first gas turbine inlet combustion gas temperature, and the generator output (gas turbine output) at 1500 °C MW, which is the generator output when the gas turbine inlet combustion gas temperature TIT is 1500 °C defined as the second gas turbine inlet combustion gas temperature. Note that 1500 °C is the maximum combustion gas temperature (upper limit value) determined from the heat resistance of the combustor 23 and the gas turbine main body 21 in the gas turbine design, and since the temperature is adjusted so as not to exceed this temperature, 1500 °C MW is also referred to as temperature-controlled MW or base load. These 700 °C MW and 1500 °C MW (temperature-controlled MW) can be obtained in prior studies (gas turbine design).

[0030] Then, as shown in FIG. 7, set the CLCSO for 700 °C MW to 0% and the CLCSO for 1500 °C MW to 100%. However, both of these 700 °C MW and 1500 °C MW are values considering the IGV opening degree, intake air temperature, turbine bypass ratio, and atmospheric pressure ratio, that is, the generator output (gas turbine output) when the gas turbine inlet combustion gas temperature TIT is 700 °C and the generator output (gas turbine output) when the gas turbine inlet combustion gas temperature TIT is 1500 °C at a certain IGV opening degree, intake air temperature, turbine bypass ratio, and atmospheric pressure ratio.

[0031] That is, as illustrated in FIG. 8, the relationship between the generator output (gas turbine output) and the CLCSO varies depending on the IGV opening degree (e.g., 0% (the intake air passage is not completely closed), 50%, 100%). As illustrated in FIG. 9, the relationship between the generator output (gas turbine output) and the CLCSO also varies depending on the intake air temperature (e.g., -10°C, 40°C). As illustrated in FIG. 10, the relationship between the generator output (gas turbine output) and the CLCSO also varies depending on the turbine bypass ratio. Although not shown, the relationship between the generator output (gas turbine output) and the CLCSO also varies depending on the atmospheric pressure ratio (e.g., 1.0, 1.1). Therefore, values of 1500°C MW corresponding to the IGV opening degree, intake air temperature, turbine bypass ratio, and atmospheric pressure ratio are preset. Also, by multiplying the value of 1500°C MW considering the IGV opening degree, intake air temperature, and turbine bypass ratio by the atmospheric pressure ratio, a value of 1500°C MW considering the atmospheric pressure ratio can be calculated.

[0032] Although specific explanations are omitted, for 700°C MW as well, values considering the IGV opening degree, intake air temperature, turbine bypass ratio, and atmospheric pressure ratio can be obtained in the same manner as in the case of 1500°C MW. And once the values of 700°C MW and 1500°C MW considering the IGV opening degree, intake air temperature, turbine bypass ratio, and atmospheric pressure ratio are determined, based on these values of 700°C MW and 1500°C MW and the measured gas turbine output (generator output), the CLCSO is calculated from the following formula (F1), which is a linear interpolation (interpolation calculation) formula.

[0033] CLCSO (%) = {(Measured gas turbine output (MW) - 700°C MW) / (1500°C MW - 700°C MW)} × 100…(F1)

[0034] Based on the calculation logic of the CLCSO calculator 20 shown in Fig. 11, first, in the function generator 51, based on the measured intake air temperature, the IGV opening command value, and the turbine bypass ratio obtained by dividing the measured intake air flow rate (corresponding to the total compressed air volume) by the measured turbine bypass flow rate in the divider 53 (turbine bypass flow rate / intake air flow rate), the value of 1500 °C MW (temperature control MW) as the second gas turbine output is calculated. That is, the value of 1500 °C MW considering the IGV opening, intake air temperature, and turbine bypass ratio is obtained.

[0035] In the function generator 52, based on the intake air temperature, the IGV opening command value, and the turbine bypass ratio, the value of 700 °C MW as the first gas turbine output is calculated. That is, the value of 700 °C MW considering the IGV opening, intake air temperature, and turbine bypass ratio is obtained.

[0036] In the divider 54, the measured intake air pressure (atmospheric pressure) is divided by the standard atmospheric pressure set by the signal generator 61 to obtain the atmospheric pressure ratio (intake air pressure / standard atmospheric pressure). In the multiplier 55, the value of 1500 °C MW obtained by the function generator 51 is multiplied by the atmospheric pressure ratio obtained by the divider 54 to obtain the value of 1500 °C MW considering the atmospheric pressure ratio. The value of 1500 °C MW obtained by the multiplier 55 is output to the subtractor 57 via the learning circuit 62. Details of the learning circuit 62 will be described later. In the multiplier 56, the value of 700 °C MW obtained by the function generator 52 is multiplied by the atmospheric pressure ratio obtained by the divider 54 to obtain the value of 700 °C MW considering the atmospheric pressure ratio.

[0037] In the subtractor 57, the value of 700 °C MW obtained by the multiplier 56 is subtracted from the value of 1500 °C MW obtained by the multiplier 55 (or corrected by the learning circuit 62) (1500 °C MW - 700 °C MW: refer to the above formula (F1)). In the subtractor 58, the value of 700 °C MW obtained by the multiplier 56 is subtracted from the measured generator output (gas turbine output) (measured generator output (gas turbine output) - 700 °C MW: refer to the above formula (F1)).

[0038] Then, in the divider 59, the subtraction result of the subtractor 58 and the subtraction result of the subtractor 57 are divided (see the above formula (F1)). Thus, CLCSO can be calculated. To express CLCSO as a percentage, the output value of the divider 59 may be multiplied by 100. In the rate setter 60, in order to prevent the main fuel flow control valve 28 and the like from frequently repeating the opening and closing operations due to the minute fluctuations in the gas turbine output (generator output) causing minute fluctuations in CLCSO, the input value from the divider 59 is not immediately output as CLCSO, but is output after being limited to a predetermined increase and decrease rate.

[0039] By the way, when the gas turbine 2 is operated for a long period of time, performance degradation of the gas turbine 2 may occur due to degradation of the compression performance of the compressor 22 and the like, and accordingly, the generator output (gas turbine output) decreases. That is, at this time, even if the gas turbine inlet combustion gas temperature TIT reaches 1500 °C, the generator output (gas turbine output) does not reach the predetermined (for example, rated) generator output (gas turbine output). As a result, CLCSO also decreases and the relationship between CLCSO and the gas turbine inlet combustion gas temperature TIT is shifted, and the relationship between the gas turbine inlet combustion gas temperature TIT and the pilot ratio, top hat ratio, main ratio, and bypass valve opening degree is also shifted. Therefore, at this time, it is also necessary to decrease the value of 1500 °C MW (temperature control MW) for calculating CLCSO. Alternatively, at the start of operation of the gas turbine 2, or after facility renovation, etc., the generator output (gas turbine output) may increase due to individual variations or the like compared to the design value. At this time, it is also necessary to increase the value of 1500 °C MW (temperature control MW) for calculating CLCSO.

[0040] Therefore, the controller 9 is further provided with a learning circuit 62 for 1500 °C MW (temperature control MW) in the calculation logic of CLCSO.

[0041] In the learning circuit 62, first, before starting the learning of 1500°C MW (temperature-controlled MW), to determine whether the decrease or increase in the generator output (gas turbine output) is due to the characteristic deterioration or deviation from the design value of the gas turbine 2, it is determined whether the gas turbine inlet combustion gas temperature TIT has reached the maximum combustion gas temperature (1500°C). That is, when the gas turbine inlet combustion gas temperature TIT is the maximum combustion gas temperature (1500°C), there is a relationship as shown in FIG. 12 between the pressure ratio of the compressor 22 (the ratio of the inlet-side pressure to the outlet-side pressure of the compressor 22) and the exhaust gas temperature. Therefore, in the learning circuit 62, the pressure ratio of the compressor 22 (compartment pressure / intake pressure) obtained from the measured intake pressure and the measured compartment pressure, and the measured exhaust gas temperature are monitored, and when these pressure ratio and exhaust gas temperature are in the relationship shown in FIG. 12, it is determined that the gas turbine inlet combustion gas temperature TIT has reached the maximum combustion gas temperature (1500°C), and the learning is started.

[0042] At this time, in the learning circuit 62, first, in the subtractor (deviation calculator) 63, the deviation (generator output - 1500°C MW) between the 1500°C MW (temperature-controlled MW) after atmospheric pressure ratio correction input from the multiplier 55 and the measured gas turbine output (generator output) is obtained. In the PI (proportional-integral) controller 64, a correction coefficient is obtained by performing proportional-integral calculation on the deviation obtained by the subtractor (deviation calculator) 63. In the limiter 65, the correction coefficient calculated by the PI controller 64 is limited, for example, within the range of 0.95 to 1.05. Such a limitation range of the correction coefficient is considered in view of the change amount of the generator output (gas turbine output) that may be caused by the performance deterioration or individual variation of the normal gas turbine 2, and is to prevent excessive correction due to abnormal output changes of the gas turbine 2. In the multiplier 66, the correction coefficient is multiplied by the 1500°C MW (temperature-controlled MW) input from the multiplier 55, and the multiplication result is output to the subtractor (deviation calculator) 63.

[0043] By performing such processing, the value of 1500°C MW (temperature-controlled MW) is corrected to match the value of the measured gas turbine output (generator output). Then, the corrected value of 1500°C MW (temperature-controlled MW) is output to the subtracter 57 for use in the calculation of CLCSO.

[0044] (Automatic adjustment unit) Figure 4 is a detailed block diagram of the automatic adjustment unit 10 in the gas turbine control device 3 shown in Figure 3. 11 is an input means, 12 is a state grasping means, 13 is a frequency analysis means, 14 is a combustion characteristic grasping means, 15 is a first database (hereinafter, also simply referred to as "database"), 16 is a correction amount calculation means, 17 is an output means, 18 is a second database, and 19 is a database correction means. In the automatic adjustment unit 10 composed of these, when combustion vibration occurs, control is performed to change the operation amount (process amount) in the most effective direction for suppressing the vibration.

[0045] That is, the automatic adjustment unit 10 receives, by the input means 11, the process amount, pressure, and acceleration data from the process amount measurement unit 4, pressure fluctuation measurement unit 5, and acceleration measurement unit 6 transferred from the controller 9. Further, based on the vibration frequency analysis result in the gas turbine 2 by the frequency analysis means 13, the state grasping means 12 grasps the state of the gas turbine 2, and the combustion characteristic grasping means 14 grasps the combustion characteristics of each combustor 23. Also, the automatic adjustment unit 10 accumulates information such as the process amount, pressure, and acceleration data received from the controller 9 (information related to the operation results of the gas turbine 2 including CLCSO) in the first database 15 and the like. Then, based on the contents grasped by the state grasping means 12 and the combustion characteristic grasping means 14, the correction amount calculation means 16 determines countermeasures so that combustion vibration does not occur in the gas turbine 2, that is, whether to adjust the main fuel flow control valve 28 and the main fuel supply valve 29, the top hat fuel flow control valve 30 and the top hat fuel supply valve 31, the pilot fuel flow control valve 32 and the pilot fuel supply valve 33, the bypass valve 35, and the inlet guide vane 26, and if so, determines the adjustment part and the adjustment amount. Then, the determination result of the correction amount calculation means 16 is output to the controller 9 by the output means 17.

[0046] Further, when combustion vibration occurs as described later, this correction amount calculation means 16, in order to suppress it, is based on the control system settings, a database 15a that stores information associating changes in the combustion state in the combustor 23 as shown in FIG. 13 stored in the first database 15, a basic database (not shown) that stores information obtained by analyzing based on the information accumulated in the database, information associating the past adjustments as shown in FIG. 14 with the changes in the operating state of the gas turbine 2 caused by performing such adjustments, a mathematical model showing standard combustion characteristics, constraint information, experience information, and knowledge accumulated with experience information associating the "symptoms" set based on the experience (know-how) of a skilled adjuster with effective countermeasures in such symptoms. A desired correction amount is calculated based on a database (not shown), etc. At that time, the sensitivity of the load to the individual operation amounts stored in the second database 18 is referred to, and the amount of load fluctuation generated for the total operation amount to be changed is predicted and used in advance for control to maintain the desired load. The sensitivity of the load to the operation amounts stored in the second database 18 can be calculated based on the process amounts measured during actual operation, for example, as described in Patent Document 1. However, there is no limitation on the calculation method.

[0047] The first database 15 is a database that accumulates information related to the operation results of the gas turbine 2 including CLCSO (combustion load command value). The first database 15 includes, for example, a database 15a as shown in FIG. 13. The database 15a stores process quantities including operable "operation quantities (plant data)" such as the amount of fuel and air supplied to the gas turbine 2, "non-operable state quantities" such as meteorological data such as atmospheric temperature and the magnitude of the load of the generator (generator output) determined by requirements, etc., and associates the frequency analysis results of pressure fluctuations and vibrations with time information (t1, t2,...). In the example shown in FIG. 13, the operation quantities include the bypass valve opening degree, the pilot ratio, and the top hat ratio. The non-operable state quantities include atmospheric temperature, generator output, intake pressure (inlet pressure of the compressor), cabin pressure (outlet pressure of the compressor (cabin pressure)), turbine exhaust gas temperature (hereinafter also referred to as exhaust gas temperature), and CLCSO. Here, CLCSO is data calculated by the CLCSO calculator 20. Further, it includes data indicating the analysis results of each frequency band calculated by the frequency analysis means. The first database 15 can include a plurality of pieces of information representing combustion characteristics and the like as shown in FIG. 17 described later, associated with a plurality of different CLCSOs.

[0048] Also, the database correction means 19 calculates a coefficient (=100 / 98) for adjusting the acquired CLCSO (e.g., 98%) to the CLCSO (e.g., 100%) that should be obtained at the gas turbine inlet combustion gas temperature TIT (e.g., 1500°C) calculated based on at least the measured exhaust gas temperature and the cabin pressure in a predetermined operating state of the gas turbine 2 (e.g., the state where the base load is reached), and corrects each CLCSO stored in the first database 15 based on the calculated coefficient. In this example, by multiplying each CLCSO stored in the first database 15 by the coefficient (=100 / 98), the value of the CLCSO (98%) obtained when the gas turbine inlet combustion gas temperature TIT is 1500°C is corrected to the value of the CLCSO (100%) that should be obtained in the state where the base load is reached. Note that the same coefficient (e.g., 100 / 98) is multiplied to correct the values of the CLCSO obtained other than when the base load is reached and stored in the first database 15. Also, as described with reference to FIG. 12, the gas turbine inlet combustion gas temperature TIT can be calculated based on the measured exhaust gas temperature and the cabin pressure, but it can also be calculated using other parameters. That is, the gas turbine inlet combustion gas temperature TIT can be calculated based on the heat balance (heat balance calculation) by adding, for example, a plurality of other measurement parameters (atmospheric pressure, atmospheric temperature, etc.) in addition to the exhaust gas temperature and the cabin pressure. In this case, TIT and CLCSO can be calculated with higher accuracy. Note that the calculation of TIT by the heat balance may be continuously repeated, for example, during operation, and the CLCSO may be updated each time.

[0049] As described above, in the CLCSO calculator 20, the learning circuit 62 corrects the value of 1500 °C MW (temperature control MW) so as to match the value of the measured gas turbine output (generator output) when the base load of the gas turbine 2 is reached. CLCSO is calculated using the value of 1500 °C MW as shown in equation (F1). Therefore, when the value of 1500 °C MW is corrected, the corrected CLCSO becomes a value calculated using a 1500 °C MW different from the CLCSO before correction. For this reason, the CLCSO before and after correction becomes a relatively shifted value as it is.

[0050] Figure 15 shows an example of the change in output when the gas turbine 2 is first started after a periodic inspection, with the horizontal axis representing time and the vertical axis representing the generator output (= GT load (MW)). Note that "after periodic inspection" is an example, and the same operation example can be applied at startup other than after periodic inspection. In the example shown in Figure 15, the gas turbine 2 is started at time tc1. Thereafter, the collection of data into the first database 15 is started at time tc2. In this example, the generator output increases stepwise and rises to the base load. Then, at time tc3 when the operation becomes stable after reaching the base load, it is assumed that the value of 1500 °C MW (temperature control MW) is corrected so as to match the value of the measured gas turbine output (generator output), and the CLCSO value is adjusted. In this case, the value of CLCSO before time tc3 is a value calculated using a 1500 °C MW (temperature control MW) value different from the corrected CLCSO. As shown in Figure 16, when the change in output and CLCSO is represented with the horizontal axis representing the generator output (= GT load (MW)) and the vertical axis representing CLCSO, when the generator output changes, the CLCSO value is calculated with respect to the value before the change (solid line), for example, as shown by the dashed line.

[0051] FIG. 17 shows an example of the correction of the first database 15 by the database correction means 19. FIG. 17 shows the state before correction as "before integration" and the state after correction as "after integration". The first database 15 (including data accumulated from time tc2 to time tc3 in FIG. 15, for example) before "integration" includes information representing regions (regions shaded in the figure) where combustion vibration is less likely to occur in the relationship between the top hat ratio (TH ratio) and the pilot ratio (PL ratio) for each predetermined CLCSO (94%, 96.5%, and 98%). On the other hand, when a correction with a coefficient of 100 / 98 is performed at time tc3, the database correction means 19 corrects the values of 94%, 96.5%, and 98% to 95.9%, 98.5%, and 100% respectively by multiplying each by 100 / 98. By doing so, the data accumulated from time tc2 to time tc3 can be effectively used as data corresponding to the corrected CLCSO.

[0052] According to the present embodiment, by providing the database correction means 19, even when the CLCSO is corrected, the information accumulated before the correction can be effectively used, so that the time required for data accumulation in the database that stores information related to the operation results of the gas turbine can be shortened.

[0053] Note that this is a schematic configuration of an apparatus for implementing the gas turbine control method according to the present disclosure. The present disclosure is made to suppress the occurrence of an operation that deviates from the operation state at the ideal fuel flow rate and air flow rate assumed by the initial design value in a gas turbine that swings the operation amount such as the pilot ratio and automatically searches for the optimal operation conditions as described above.

[0054] Therefore, the present disclosure includes a frequency analysis means 13 for frequency-analyzing vibrations of pressure or acceleration in a combustor of a gas turbine, a combustion characteristic grasping means 14 for grasping the characteristics of combustion vibrations of the gas turbine based on the analysis results by frequency band, operation process quantities including the ratio of air flow rate, pilot fuel ratio, and top hat fuel ratio in the gas turbine, and state signals including atmospheric conditions and load amount, and a controller 9 for adjusting at least one of the fuel flow rate or air flow rate supplied to the combustor so as to suppress combustion vibrations when the combustion characteristic grasping means 14 grasps that combustion vibrations are occurring. The present disclosure further includes a second database 18 that stores the load sensitivity with respect to the operation amount based on the correlation between the change amounts of the fuel flow rate, air flow rate, pilot fuel ratio, and top hat fuel ratio in the gas turbine and the load amount of the gas turbine. When the controller 9 is not performing adjustment to suppress combustion vibrations, at least one of the fuel flow rate or air flow rate supplied to the combustor is varied to search for optimal operating conditions, and the load sensitivity stored in the second database 18 is used according to the obtained optimal operating conditions to predict the load change amount with respect to the operation amount of at least one of the fuel flow rate or air flow rate supplied to the combustor, and at least one of the fuel flow rate or air flow rate supplied to the combustor is adjusted according to the prediction result.

[0055] That is, when the gas turbine is in a stable operating state, data cannot be collected even with aging changes, so the operating conditions are varied at predetermined intervals to automatically search for the optimal operating conditions. Even when combustion vibrations occur in a plurality of frequency bands and the combustion vibrations can be effectively suppressed, as described above, unexpected load fluctuations may occur due to automatic changes, and the operation may deviate from the operating state with the ideal fuel flow rate and air flow rate assumed in the initial design value.

[0056] In contrast, in the present disclosure, a second database 18 is provided that stores the load sensitivity with respect to the operation amount based on the correlation between the change amounts of the fuel flow rate, air flow rate, pilot fuel ratio, and top hat fuel ratio in the gas turbine and the load amount of the gas turbine. When automatically searching in a state where the controller 9 does not perform adjustments to suppress combustion vibration, the load sensitivity stored in the second database 18 is used according to the obtained optimal operating conditions, and the load fluctuation amount with respect to the operation amount of at least one of the fuel flow rate or air flow rate supplied to the combustor is predicted. Then, at least one of the fuel flow rate or air flow rate supplied to the combustor is adjusted according to the prediction result. Therefore, the possibility of causing such problems is eliminated, and the design performance and operating state can be set to the ideal fuel flow rate and air flow rate assumed during design.

[0057] (Operation example of gas turbine control device) FIG. 18 is a flowchart showing an operation example of the gas turbine control device 3 according to an embodiment of the present disclosure. The flowchart shown in FIG. 18 is incorporated as part of a program for operating the gas turbine 2, and a series of processes are executed at predetermined time intervals while the gas turbine 2 is operating.

[0058] When the process starts at step S10, the process amount, pressure, acceleration, and NOx data transferred from the process amount measuring unit 4, pressure fluctuation measuring unit 5, acceleration measuring unit 6, and NOx measuring unit 7 in FIG. 3 via the controller 9 are received by the input means 11 at step S11 and sent to the state grasping means 12, frequency analysis means 13, and the first database 15.

[0059] In the next step S12, frequency analysis means 13 performs frequency analysis of the internal pressure fluctuation and acceleration, and abnormal diagnosis of the sensor. The frequency analysis means 13 performs frequency analysis (Fast Fourier Transform: FFT) of, for example, the pressure fluctuation (vibration) based on the pressure fluctuation measurement value measured by the pressure fluctuation measurement unit 5 in each combustor 23. FIG. 19 is an example of the result of frequency analysis performed by the frequency analysis means 13 based on the pressure fluctuation measurement value measured by the pressure fluctuation measurement unit 5. The horizontal axis represents the frequency, and the vertical axis represents the intensity (level) of vibration. Note that the frequency analysis means 13 can also perform frequency analysis of the acceleration based on the acceleration measurement value measured by the acceleration measurement unit 6.

[0060] As shown in FIG. 19, for example, the frequency analysis means 13 divides the frequency analysis results of the internal pressure fluctuation and acceleration into a plurality (n) of frequency bands and outputs them as analysis results for each frequency band. Here, the frequency band is a frequency region that is the minimum unit for correspondence based on the result of frequency analysis performed by the frequency analysis means 13.

[0061] Returning to FIG. 18 again, the frequency analysis is performed as described above. The result of this frequency analysis is added to and updated in the first database 15 in step S13. Here, the data stored in the first database 15 is stored in the first database 15 in a format such as the database 15a shown in FIG. 13. In FIG. 13, X11-1, X11-2, …, X11-n1, X12-1, X12-2, …, X19-n1 are process quantities, and Yi1-1, Yi1-2, ……, Yi1-n1, Yi2-1, Yi2-2, …, Yin-n1 are the maximum values of the vibration intensity in each frequency band. That is, in the first database 15, the process quantity and the maximum value Yin of the vibration intensity in each frequency band are sorted and stored at each time t1, t2, …. When these data are sent from the controller 9 and the frequency analysis means 13 to the first database 15 every moment, those data are additionally stored in the first database 15.

[0062] The data of the vibration intensity stored in the first database 15 may be only the pressure vibration, only the acceleration vibration, or both the pressure vibration and the acceleration vibration. As an example, at time t1 in FIG. 13, the valve opening degree of the bypass valve 35 is X11-1, the pilot ratio is X12-1, the top hat ratio is X13-1, the atmospheric temperature is X14-1, the load (MW) of the generator is X15-1, the intake pressure is X16-1, the cabin pressure is X17-1, the exhaust gas temperature is X18-1, the CLCSO is X19-1, the maximum value of the vibration intensity in the first frequency band is Yi1-1, the maximum value of the vibration intensity in the second frequency band is Yi2-1, and the maximum value of the vibration intensity in the nth frequency band is Yin-1. Similarly, at time t2, the valve opening degree of the bypass valve 35 is X11-2, the pilot ratio is X12-2, the top hat ratio is X13-2, the atmospheric temperature is X14-2, the load (MW) of the generator is X15-2, the intake pressure is X16-2, the cabin pressure is X17-2, the exhaust gas temperature is X18-2, the CLCSO is X19-2, the maximum value of the vibration intensity in the first frequency band is Yi1-2, the maximum value of the vibration intensity in the second frequency band is Yi2-2, and the maximum value of the vibration intensity in the nth frequency band is Yin-2.

[0063] And in the next step S14, the database correction means 19 determines whether a predetermined database correction condition is satisfied (step S14). The predetermined database correction condition can be, for example, that in the CLCSO calculator 20, a new correction of 1500 °C MW has been performed, that the cumulative correction amount of 1500 °C MW has exceeded a predetermined amount since the previous database correction, that the gas turbine 2 has reached the base load after the start of the gas turbine 2, that the setting of the parameters (see FIG. 11) used in the calculation of the CLCSO has been updated, that a predetermined time has elapsed, and the like.

[0064] When the specified database correction condition is satisfied (step S14: YES), the database correction means 19 calculates, for example, a coefficient for adjusting the CLCSO obtained in the operating state at the time of base load arrival to match the CLCSO that should be obtained at the gas turbine inlet combustion gas temperature TIT calculated based on the measured exhaust gas temperature and the cabin pressure, and corrects the values of the respective CLCSOs stored in the first database 15 by multiplying them by the calculated coefficient (step S15).

[0065] Then, in the next step S16, based on the analysis result of the pressure or acceleration by frequency band by the state grasping means 12, it is determined by comparing with a preset threshold value whether the combustion vibration is in a state that requires immediate adjustment, or whether there is a sign of combustion vibration that does not occur but requires immediate adjustment. As a result, if it is determined (Yes) that the control value deviates or there is a sign of combustion vibration, the process proceeds to step S18 to determine a countermeasure.

[0066] In this step S18, first, the characteristics of the occurring combustion vibration are calculated. This is the construction of a mathematical model for modeling the combustion characteristics based on the analysis result of the pressure or acceleration by frequency band from the frequency analysis means 13 and the process quantity from the process quantity measurement unit 4, which are stored in the first database 15 by the combustion characteristic grasping means 14. The mathematical model is, for example, a model for classifying an area where vibration is likely to occur and an area where it is less likely to occur, and may be a linear first-order expression as described in Patent Document 1, for example, or a non-linear model such as a second-order or higher-order model or a neural network.

[0067] FIG. 20 shows an example of a combustion vibration region with the valve opening degree X11 of the bypass valve 35 on the horizontal axis and the pilot ratio X12 on the vertical axis, which is obtained by the combustion characteristic grasping means 14. In this example, the combustion vibration region is expressed like contour lines for each gain αk, and the central part is an area where combustion vibration is less likely to occur, and the peripheral part is an area where it is more likely to occur. Note that FIG. 20 is shown in two-dimensional coordinates due to the convenience of explanation as described above with two variables for the operation amount, but if the operation amount is N variables, it will be shown in an N-dimensional coordinate space.

[0068] FIG. 21 is a diagram showing an example of the relationship between the fuel supply distribution ratio and CLCSO during load change, which is obtained by the combustion characteristic grasping means 14. The vertical axis of FIG. 21 represents the PL ratio, and the horizontal axis represents CLCSO. FIG. 21 shows the relationship between the PL ratio, CLCSO, and combustion vibration. Regions A4 and A5 are regions where combustion vibration occurs. Graph A1 shows an operating line indicating the relationship between the PL ratio and CLCSO where combustion vibration does not occur. Graph A2 is an example of an operating line when the load is increased (CLCSO increases), and operating line A3 is an example of an operating line when the load is decreased. In both cases, there is a possibility of combustion vibration occurring.

[0069] Based on the fact that the value of CLCSO is "CLCSO1" at a certain time, the calculated PL ratio "PL1" by the correction amount calculating means 16 is in a relationship included in the combustion vibration generation region in relation to the value "CLCSO2" of CLCSO at the time when the fuel flow rate supply based on the ratio is actually realized. Therefore, in this case, a bias h2 is added for correction so as to avoid the relationship between the PL ratio and CLCSO from becoming a relationship where combustion vibration is likely to occur. Regarding the TH ratio as well, a bias h1 is added for correction so as to avoid the relationship between the TH ratio and CLCSO from becoming a relationship where combustion vibration is likely to occur.

[0070] Further, the correction amount calculation means 16 determines the countermeasure content (countermeasure location and adjustment amount) for adjusting the current operating state based on the content grasped by the state grasping means 12 and the combustion characteristic grasping means 14 (step S18). At this time, when the maximum amplitude value exceeds the threshold value in a plurality of frequency bands, data collected from another gas turbine 2 of the same type that has already been installed and operated is used, and a mathematical model showing the standard combustion characteristics obtained as a result of the analysis, or constraints such as the limit value of the fuel-air ratio to prevent misfire or flashback during the operation of the gas turbine 2 are stored. Based on the priority (priority level) stored in the basic database (not shown) in the first database 15, adjustment is performed on the frequency band with the highest priority. Here, as an example, the priority of the lowest frequency band is set to the highest, and then the priority is sequentially set higher from the high-frequency side frequency bands. This is because when combustion vibration occurs in the lowest frequency band, there is a high possibility that the gas turbine 2 is in a state where the flame is likely to go out, and in the high-frequency band, the energy due to combustion vibration is large, so the influence of causing damage or the like is strong.

[0071] Also, after selecting the frequency band to be adjusted, the correction amount calculation means 16 then determines the direction in which the current operating state should be adjusted using an optimization method such as the steepest descent method. Note that the optimization method used here is not limited to the steepest descent method.

[0072] At this time, when the combustion characteristics cannot be sufficiently grasped by the combustion characteristic grasping means 14, the correction amount calculating means 16 can determine the adjustment direction based on the information associating the past adjustments in the first database 15 with the changes in the operating state of the gas turbine 2 caused by applying such adjustments, for example, based on the content of the knowledge database as shown in FIG. 14. That is, in FIG. 14, for the first priority adjustment, the bypass valve is opened in the first frequency band, the top hat ratio is reduced in the nth frequency band, for the second priority, the pilot ratio is increased in the first frequency band, and nothing is done to the top hat ratio in the nth frequency band. Also, when sufficient data has not been accumulated in the first database 15, such as immediately after the gas turbine 2 is installed, the adjustment direction can be determined based on the above-described basic database and the mathematical model, constraint information, experience information, etc. stored in the knowledge database that indicate standard combustion characteristics. Note that the knowledge database may store experience information associating "symptoms" set based on the experience (know-how) of skilled adjusters with effective countermeasures for such symptoms.

[0073] When the countermeasure and the correction amount are determined in this way, the output means 17 outputs data indicating the adjustment direction determined by the correction amount calculating means 16 in step S19 to the controller 9. Therefore, based on the data indicating the adjustment direction input from the output means 17, the controller 9 controls the operation mechanism 8 to operate the main fuel flow control valve 28, the pilot fuel flow control valve 32, the top hat fuel flow control valve 30, the bypass valve 35, and the inlet guide vane 26, etc., and changes the bypass valve opening X11, the pilot ratio X12, and the top hat ratio X13. That is, the controller 9 changes the bypass valve opening X11 from xa to xc, changes the pilot ratio X12 from xb to xd, and changes the top hat ratio X13 from xe to xf in response to the adjustment instruction input from the output means 17, and controls at least one of the main fuel flow control valve 28, the pilot fuel flow control valve 32, the top hat fuel flow control valve 30, the bypass valve 35, and the inlet guide vane 26.

[0074] On the other hand, if, as a result of the comparison with the threshold value in step S16 of the flowchart in FIG. 18, the control value has not deviated and there is no sign of combustion vibration, the process proceeds to step S17, and it is determined whether or not the search preconditions are satisfied. These search preconditions are Condition 1: During load setting where the output of the generator 40 continues within a preset threshold range for a predetermined time Condition 2: Combustion vibration has not occurred for a predetermined time. That is, in step S16, a state where it has not been determined that the control value has deviated or there is a sign of combustion vibration has continued for a predetermined time or more Condition 3: The intake air temperature has remained within a preset threshold range for a predetermined time Condition 4: The operator has selected a search permission mode that permits shifting to the search, etc.

[0075] If these search preconditions are satisfied, the process proceeds to step S20 and it is determined whether or not the search has ended. If it has ended, the process proceeds to step S22, and at the time of completion of the search, from the data of each trial point stored in the first database 15, the optimum point (optimum operating condition) is determined. The optimum operating condition may be the one with the highest combustion stability, or in addition to this, taking into account the thermal efficiency and the efficiency of each element of the gas turbine system 1, the optimum operating condition may be determined. Also, environmental protection may be taken into account, or when the gas turbine system 1 constitutes a combined cycle power generation system (gas turbine combined cycle plant), the plant efficiency of the combined cycle power generation system may be taken into account. Furthermore, the optimum point is not limited to being determined among the data of each trial point, and the results at each trial point may be applied to, for example, a non-linear regression equation or a polynomial, and another point within the condition search area estimated to be optimum may also be used.

[0076] If the search has not ended in step S20, the process proceeds to step S21, where the correction amount calculation means 16 determines the operating conditions to be changed (referred to as the trial point). After predicting the load change amount in step S23 (step S23), in step S24, the output means 17 outputs data on the correction amount corresponding to the operating conditions. This operation repeats the process of FIG. 18 for a plurality of cycles, and by varying the trial points determined in step S21, each parameter of the operating conditions is sequentially varied within a predetermined region. Specifically, at least one of the fuel or air flow rates supplied to the combustor 23 is varied by a predetermined amount as shown in FIG. 22. FIG. 22 is a graph with time on the horizontal axis and the pilot ratio correction amount on the vertical axis. The pilot ratio is automatically toggled between + and - (hereinafter, obtaining data by toggling the pilot ratio, etc. in this way is referred to as "automatic search"), the state of the latest combustion vibration is stored in the database, and control is performed based on the data.

[0077] When the optimal operating conditions are thus found, in the present disclosure, as described above, the load sensitivity representing the correlation between the operating amounts of the fuel flow rate, air flow rate, pilot fuel ratio, and top hat fuel ratio in the gas turbine and the load amount of the gas turbine is read from the second database 18, and according to the operating conditions obtained by this search, the load change amount with respect to at least one of the operating amounts of the fuel flow rate or air flow rate supplied to the combustor is predicted. Then, adjustment is carried out according to this prediction result.

[0078] By using the load sensitivity in this way, even in a gas turbine control method and apparatus that automatically searches for the optimal operating conditions by toggling the operating amounts such as the pilot ratio, the load change amount with respect to at least one of the operating amounts of the fuel flow rate or air flow rate supplied to the combustor is predicted according to the operating conditions obtained by the search, and adjustment is carried out according to the prediction result. Therefore, it is possible to suppress the occurrence of an operation that deviates from the operating state at the ideal fuel flow rate and air flow rate assumed by the initial design value as in the prior art, and the design performance and operating state can be set to the ideal fuel flow rate and air flow rate assumed at the time of design.

[0079] (Function and Effect) In the information processing method, information processing apparatus, and program having the above configuration, during the operation of the gas turbine 2, information related to the operation results of the gas turbine 2 including the CLCSO (combustion load command value) is stored in the first database 15. In a predetermined operating state of the gas turbine 2, a coefficient is calculated for adjusting the acquired CLCSO to the CLCSO that should be obtained from the gas turbine inlet combustion gas temperature TIT calculated based on at least the actually measured exhaust gas temperature and cabin pressure. Based on this coefficient, each CLCSO stored in the first database 15 is corrected. Note that the CLCSO is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature TIT by linear interpolation based on the first gas turbine output (700°C MW) corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 of the gas turbine 2 and the opening degree of the inlet guide vane 26 of the gas turbine 2, the second gas turbine output (1500°C MW) corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 and the opening degree of the inlet guide vane 26, and the output (MW) of the gas turbine 2. According to the present embodiment, by correcting each CLCSO stored in the first database 15, data that cannot be used if not corrected can be effectively used. Therefore, compared with the case where no correction is performed, the time required for data storage in the database storing information related to the operation results of the gas turbine can be shortened.

[0080] (Other Embodiments) As described above, the embodiments of the present disclosure have been described in detail with reference to the drawings. However, the specific configuration is not limited to this embodiment, and design changes and the like within the scope not departing from the gist of the present disclosure are also included.

[0081] For example, the modification of the first database 15 by the database modification means 19 may be performed as follows. FIG. 23 schematically shows a modification example of the first database 15. In this example, it is assumed that the first database 15 includes a database 15b. The database 15b includes information (information indicating a region where combustion vibration is less likely to occur in the relationship between the TH ratio and the PL ratio in association with CLCSO), for example, as shown in FIG. 17, as data D1 to D25, and is included for each of the blocks B1 to B5 obtained by dividing 0 to 100% of CLCSO into 5 equal parts at 20% intervals. Also, it is assumed that the upper limit of the number of data that can be stored in each of the blocks B1 to B5 is 5. Note that the data D1 to D25 are older information as the numbers are smaller. In the database 15b (before modification), for example, the data D1, D6, D11, D16, and D21 included in the block B1 are information with corresponding CLCSO of 0 to 20% (but not including 20%), the data D1 is the oldest information, and the data D16 is the newest information. For this database 15b (before modification), it is assumed that the data multiplied by the coefficient (i.e., adjusted) by the database modification means 19 is DA1. In this example, in the data DA1, by adjustment, the CLCSO of the data D11 is corrected to a value of 20% to 40% (but not including 20%), and the CLCSO of the data D4 is corrected from 60% to 80% (but not including 80%) to a value of 80% to 100%. In this example, the database modification means 19 updates the content of the database 15b to the content of the database 15b (after modification) based on the adjusted data DA1. In the database 15b (after modification), the data D11 is deleted from the block B1. In the block B2, the data D11 is added, and since the data exceeds the upper limit of the number of stored data in the block, which is 5, the oldest data, the data D2, is deleted. In the block B4, the data D4 is deleted. The block B5 already includes 5 data, which is the upper limit value, and since there is no data older than the data D4, the data D4 is not stored in the block B5. According to this modification method, the capacity of the first database 15 can be appropriately managed within a certain range. Note that the upper limit for each block may be set by the number of data or the data amount.Also, the range of the corresponding CLCSO for each block is not limited to 20%.

[0082] In the above embodiment, the correction of the CLCSO is performed in the operating state at the base load. However, for example, a correction based on the value of CLCSO = 0% may be additionally performed.

[0083] 〈Computer Configuration〉 FIG. 24 is a schematic block diagram showing the configuration of a computer according to at least one embodiment. The computer 90 includes a processor 91, a main memory 92, a storage 93, and an interface 94. The above-described gas turbine control device 3 is implemented in the computer 90. The operations of the above-described respective processing units are stored in the storage 93 in the form of a program. The processor 91 reads the program from the storage 93 and expands it in the main memory 92, and executes the above processing according to the program. Further, the processor 91 secures a storage area corresponding to each of the above-described storage units in the main memory 92 according to the program.

[0084] The program may be for realizing a part of the functions to be exerted by the computer 90. For example, the program may exert functions by combination with other programs already stored in the storage or combination with other programs implemented in other devices. In other embodiments, the computer may include a custom LSI (Large Scale Integrated Circuit) such as a PLD (Programmable Logic Device) in addition to or instead of the above configuration. Examples of PLDs include PAL (Programmable Array Logic), GAL (Generic Array Logic), CPLD (Complex Programmable Logic Device), FPGA (Field Programmable Gate Array), etc. In this case, part or all of the functions realized by the processor may be realized by the integrated circuit.

[0085] Examples of the storage 93 include HDD (Hard Disk Drive), SSD (Solid State Drive), magnetic disk, magneto-optical disk, CD-ROM (Compact Disc Read Only Memory), DVD-ROM (Digital Versatile Disc Read Only Memory), semiconductor memory, etc. The storage 93 may be an internal medium directly connected to the bus of the computer 90, or an external medium connected to the computer 90 via the interface 94 or a communication line. Also, when this program is distributed to the computer 90 via a communication line, the computer 90 that has received the distribution may expand the program in the main memory 92 and execute the above processing. In at least one embodiment, the storage 93 is a non-transitory tangible storage medium.

[0086] <Appendix> The information processing method (the information processing method by the gas turbine control device 3), the information processing apparatus, and the program according to the present embodiment are understood as follows, for example.

[0087] (1) The information processing method of the first aspect includes a first step of accumulating, in the database 15, information related to the operation results of the gas turbine 2 including a combustion load command value during operation of the gas turbine 2; and a second step of calculating, in a predetermined operation state of the gas turbine 2, a coefficient for adjusting the acquired combustion load command value to the combustion load command value that should be obtained by the gas turbine inlet combustion gas temperature calculated based on at least the actually measured exhaust gas temperature and the cabin pressure; and a third step of correcting each of the combustion load command values stored in the database 15 based on the coefficient. The combustion load command value is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature by linear interpolation based on the first gas turbine output corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 of the gas turbine 2 and the opening degree of the inlet guide vane 26 of the gas turbine 2, the second gas turbine output corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 and the opening degree of the inlet guide vane 26, and the output of the gas turbine 2. According to this aspect, the time required for data accumulation in the database 15 storing information related to the operation results of the gas turbine 2 can be shortened.

[0088] (2) The information processing method of the second aspect is the information processing method of (1), wherein the predetermined operation state corresponds to the operation state when the gas turbine 2 reaches the base load after startup of the gas turbine 2. According to this aspect, the time required for data accumulation in the database 15 after startup of the gas turbine 2 can be shortened.

[0089] (3) The information processing method according to the third aspect is the information processing method according to (1) or (2), wherein the predetermined operating state corresponds to the operating state after updating the setting of the parameter used in the calculation of the combustion load command value. According to this aspect, it is possible to shorten the time required for data accumulation in the database 15 after updating the setting of the parameter used in the calculation of the combustion load command value.

[0090] (4) The information processing method according to the fourth aspect is the information processing method according to (1) to (3), wherein in the second step, the gas turbine inlet combustion gas temperature is calculated based on the heat balance based on a plurality of measured parameters including the exhaust gas temperature and the cabin pressure. According to this aspect, by using other parameters in addition to the exhaust gas temperature and the cabin pressure, it is possible to calculate the gas turbine inlet combustion gas temperature and the combustion load command value with higher accuracy.

[0091] (5) The information processing method according to the fifth aspect is the information processing method according to (1) to (4), wherein in the second step, the predetermined operating state corresponds to the operating state when the gas turbine is continuously operating, and the gas turbine inlet combustion gas temperature is continuously calculated during operation based on the heat balance based on a plurality of measured parameters including the exhaust gas temperature and the cabin pressure. According to this aspect, by using the exhaust gas temperature, the cabin pressure, and other parameters measured by continuous monitoring (constant monitoring), it is possible to accurately and continuously calculate the gas turbine inlet combustion gas temperature and the combustion load command value.

[0092] (6) The information processing method according to the sixth aspect is the information processing method according to (1) to (5), wherein in the first step, the information related to the operation record of the gas turbine is block-divided for each combustion load command value within a predetermined range and stored in the database, and when the upper limit of each block related to the information is exceeded, the old information is deleted. According to this aspect, it is possible to appropriately manage the information registered in the database.

[0093] (7) The information processing method according to the seventh aspect is any one of the information processing methods from (1) to (6), and further includes a step of controlling the gas turbine 2 by using the database 15 in which each of the combustion load command values is corrected. According to this aspect, the time required to control the gas turbine 2 by using the database 15 can be shortened.

[0094] (8) The information processing apparatus according to the eighth aspect accumulates information related to the operation results of the gas turbine 2 including the combustion load command value in the database 15 during the operation of the gas turbine 2, and in a predetermined operation state of the gas turbine 2, the obtained combustion load command value is adjusted to the combustion load command value that should be obtained by the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure. A coefficient is calculated, and based on the coefficient, each of the combustion load command values stored in the database 15 is corrected. The combustion load command value is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature by linear interpolation based on the first gas turbine output corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 of the gas turbine 2 and the opening degree of the inlet guide vane 26 of the gas turbine 2, the second gas turbine output corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 and the opening degree of the inlet guide vane 26, and the output of the gas turbine 2. According to this aspect, the time required for data accumulation in the database 15 that stores information related to the operation results of the gas turbine 2 can be shortened.

[0095] (9) The program according to the ninth aspect includes a first step of accumulating, in the database 15, information related to the operation results of the gas turbine 2 including the combustion load command value during the operation of the gas turbine 2, and a second step of calculating, in a predetermined operation state of the gas turbine 2, a coefficient for adjusting the acquired combustion load command value to match the combustion load command value that should be obtained at the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure. And a third step of correcting each of the combustion load command values stored in the database 15 based on the coefficient. The combustion load command value is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature by linear interpolation based on the first gas turbine output corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 of the gas turbine 2 and the opening degree of the inlet guide vane 26 of the gas turbine 2, the second gas turbine output corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor 22 and the opening degree of the inlet guide vane 26, and the output of the gas turbine 2. Each step is executed by the computer 90. According to this aspect, the time required for data accumulation in the database 15 that stores information related to the operation results of the gas turbine 2 can be shortened.

Explanation of Signs

[0096] 1 Gas turbine system 2 Gas turbine 3 Gas turbine control device 4 Process quantity measurement unit 5 Pressure fluctuation measurement unit (sensor) 6 Acceleration measurement unit (sensor) 7 NOx measurement unit 8 Operating mechanism 9 Controller 10 Automatic adjustment unit 11 Input means 12 State grasping means 13 Frequency analysis means 14 Combustion characteristic grasping means 15 First database (database) 16 Correction amount calculation means 17 Output means 18 Second database 19 Database correction means 20 CLCSO calculator 22 Compressor 26 Inlet guide vane 62 Learning circuit 90 Computer

Claims

1. A first step of accumulating, in a database, information related to the operation results of the gas turbine including a combustion load command value during operation of the gas turbine; A second step of calculating, in a predetermined operation state of the gas turbine, a coefficient for adjusting the obtained combustion load command value to a combustion load command value that should be obtained by the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure; A third step of correcting each of the combustion load command values stored in the database based on the coefficient; comprising: The combustion load command value is: a first gas turbine output corresponding to a first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor of the gas turbine and the opening degree of the inlet guide vane of the gas turbine; a second gas turbine output corresponding to a second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor and the opening degree of the inlet guide vane; Based on the output of the gas turbine, By linear interpolation, an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature, An information processing method.

2. The predetermined operation state corresponds to the operation state when the gas turbine reaches the base load after startup of the gas turbine The information processing method according to claim 1.

3. The predetermined operation state corresponds to the operation state after updating the setting of the parameters used in the calculation of the combustion load command value The information processing method according to claim 2.

4. In the second step, the gas turbine inlet combustion gas temperature is calculated based on the heat balance based on a plurality of measured parameters including the exhaust gas temperature and the cabin pressure The information processing method according to claim 1.

5. In the second step, The predetermined operation state corresponds to the operation state when the gas turbine is continuously operating, The gas turbine inlet combustion gas temperature is continuously calculated during operation based on the heat balance based on a plurality of measured parameters including the exhaust gas temperature and the cabin pressure The information processing method according to claim 1.

6. In the first step, The information related to the operation results of the gas turbine is block-divided for each combustion load command value within a predetermined range and stored in the database, and when the upper limit of each block related to the information is exceeded, the old information is deleted The information processing method according to claim 1.

7. Further including the step of controlling the gas turbine by using the database in which each of the combustion load command values is corrected The information processing method according to any one of claims 1 to 6.

8. During the operation of the gas turbine, information related to the operation results of the gas turbine including the combustion load command value is stored in a database, In a predetermined operation state of the gas turbine, a coefficient for adjusting the obtained combustion load command value to the combustion load command value that should be obtained by the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure is calculated, Based on the coefficient, each of the combustion load command values stored in the database is corrected, The combustion load command value is The first gas turbine output corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor of the gas turbine and the opening degree of the inlet guide vane of the gas turbine, The second gas turbine output corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor and the opening degree of the inlet guide vane, Based on the output of the gas turbine, By linear interpolation, it is an index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature An information processing device.

9. A first step of storing, in a database, information related to the operation results of the gas turbine including the combustion load command value during the operation of the gas turbine; A second step of calculating, in a predetermined operation state of the gas turbine, a coefficient for adjusting the obtained combustion load command value to the combustion load command value that should be obtained by the gas turbine inlet combustion gas temperature calculated based on at least the measured exhaust gas temperature and the cabin pressure; A third step of correcting each of the combustion load command values stored in the database based on the coefficient; Including The combustion load command value is The first gas turbine output corresponding to the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor of the gas turbine and the opening degree of the inlet guide vane of the gas turbine, The second gas turbine output corresponding to the second gas turbine inlet combustion gas temperature higher than the first gas turbine inlet combustion gas temperature calculated based on the intake air temperature of the compressor and the opening degree of the inlet guide vane, Based on the output of the gas turbine, An index value obtained by non-dimensionalizing the gas turbine inlet combustion gas temperature by linear interpolation, A program for causing a computer to execute each of the above steps.

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