JP2007107446A - Performance diagnosis method and diagnosis system for gas turbine - Google Patents

Abstract

<P>PROBLEM TO BE SOLVED: To diagnose performance of a gas turbine, even if the gas turbine is an aging machine whose performance characteristic is changed caused by maintenance or detailed specification of the gas turbine is not known. <P>SOLUTION: A performance diagnosis system comprises: a characteristic modeling means for modeling a performance index of the gas turbine as a function whose input includes an intake temperature and intake pressure, based on operating data of a certain range during a period to be diagnosed of the gas turbine 101; a standardization means converting the performance index in a value (standardized data) in a predetermined intake temperature and intake pressure; and a diagnosis means inputting the value of the performance index included in data of a certain range during a period to be diagnosed into the standardization means to determine deterioration/recovery of the performance based on time series increase and decrease of the standardized data. In this case, a base load operation data extraction means 131 is introduced to generate a certain range of operating data to be input to the characteristic modeling means and the diagnosis means. <P>COPYRIGHT: (C)2007,JPO&INPIT

Description

  The present invention relates to a method and a diagnostic system for diagnosing the performance of an operating gas turbine facility.

  The performance of a gas turbine varies greatly depending not only on operating conditions such as fuel flow rate but also on atmospheric conditions such as intake air temperature. For this reason, it is not possible to diagnose performance deterioration or abnormality simply by arranging performance measurement values in time series. In order to cope with this, various diagnostic methods have been proposed.

  For example, Patent Document 1 describes that evaluation of actual machine data is performed under certain common conditions in order to exclude performance fluctuations due to operating conditions. Patent Document 2 describes a method in which several performance factors are modeled in combination with a plurality of specific operating conditions, and fluctuations due to changes in operating conditions are excluded based on the results. Patent Document 3 describes a moving average processing method for excluding the influence of fluctuations after modeling performance factors and operating conditions in combination as in Patent Document 2.

Japanese Patent Laid-Open No. 11-15516 JP 2003-83089 A Japanese Patent No. 3538670

  However, the conventional method has the following two problems.

  The first problem is the limit of evaluation accuracy. In the above-described prior art, Patent Document 3 discloses that the accuracy related to deterioration determination is roughly 90% for deterioration determination, 2% for tolerance, and 5% for target fluctuation range during moving average processing. ing. The diagnosis of deterioration is made by determining whether the threshold value is lower than 90%. From the viewpoint of identifying the deterioration, it can be judged that the performance deterioration is 10% or more, but the deterioration of 2% or less is presumed to be included in the above-described allowable error range, and the range of 2 to 10%. There is no method or standard for judging the deterioration of

  The second problem is how to handle changes in performance characteristics when maintenance is performed. When a gas turbine is maintained and main parts such as a compressor, turbine, and intake filter are cleaned or replaced, the performance of the equipment is restored and its characteristics are changed. However, when the performance characteristics are modeled based on actual machine data including discontinuous changes in performance due to such maintenance, the accuracy of the model is lowered. Therefore, when trying to diagnose the performance by the conventional method, it is necessary to re-model the performance characteristics using the data for a certain period thereafter and adjust the parameters of the model every time maintenance is performed. As a result, for a certain period after maintenance, performance cannot be diagnosed until a sufficient amount of data for modeling is accumulated. An effective response method for such a problem has not been shown so far.

  The objective of this invention is providing the performance diagnostic method and diagnostic system which can solve the said 1st subject or the 2nd subject further.

  As a result of various analyzes on the limit of accuracy, which is the first problem described above, the inventors have found that "performance load characteristics" and "effect of deterioration included in actual machine data" are required for high-accuracy diagnosis. The knowledge that it is necessary to consider these two factors was obtained.

  Here, the “performance load characteristic” means that the performance characteristic of the gas turbine changes depending on the load factor. For example, the power generation efficiency varies depending on the load factor, and the efficiency decreases as the load factor decreases at the time of partial load. It is necessary to model the performance characteristics appropriately corresponding to such changes in performance characteristics due to the load factor.

  The “effect of deterioration included in actual machine data” refers to the influence of performance degradation that occurs during the period of collecting actual machine data. This will be described below.

  As a method for modeling the performance characteristics of a gas turbine, there are a method using design information such as a performance characteristic function and a method of constructing a model based on operation data of an actual machine. Of these methods, the former method using design information is often not provided by a design operator in general, and is often ignorant to equipment owners and operation / maintenance operators. Even if they are disclosed, performance characteristics are often different from those at the time of design due to repeated maintenance and parts replacement. Therefore, as a more general-purpose method, it is required to construct a performance characteristic model based on actual machine operation data by the latter method. For this purpose, it is necessary to collect data so that the range of the intake air temperature, that is, the atmospheric temperature, which is a typical operation condition, includes the entire operation range. For example, in order to include the range of annual maximum and minimum temperatures, it is desirable that a period of about one and a half years is required as a period between at least the maximum temperature and the minimum temperature. In the case of continuous operation equipment, this corresponds to an operation time of about 4000 to 8000 hours.

  However, the performance of the gas turbine deteriorates even during such a period. For example, it has been reported as a typical example that the power generation output is reduced by about 3% in 5000 hours after the start of operation (for example, Harry G. Stall, Creating Owner's Competitive Advantage through Services Services, GE Powers, GE Powers, GER4208, P.10, (2001)). The problem with this is that the effects of degradation are included in the data collected to build a model in a normal state before the equipment is degraded. Therefore, there is a need for a method capable of identifying a performance characteristic model before deterioration even from actual machine operation data including the influence of deterioration over time.

  In order to cope with the limit of accuracy, which is the first problem described above, the present invention provides a load factor of 100 from the operation data of the gas turbine as a method of considering the aforementioned “performance load characteristics”. Provide a method to extract only data near% or data close to the upper limit of operation. Thus, only the data with a load factor of 100% or near the operation upper limit is extracted, and the characteristic model is constructed based on the extracted data, whereby the characteristic model is improved in the present invention. For this purpose, the following first to third embodiments are proposed.

  In the first embodiment, a certain range of operation data during the diagnosis target period of the gas turbine is used as an input, and power generation output, power generation efficiency, compressor pressure ratio, fuel flow rate, compressor efficiency, turbine efficiency, intake air flow rate, etc. Means for modeling the performance index as a function including at least intake air temperature and intake pressure as input (hereinafter referred to as characteristic modeling means), and a variable including at least the performance index, the intake air temperature, and the intake pressure. , The standardization means for converting into values (standardized data) at predetermined intake air temperature and intake pressure, and the standardized value of the performance index included in a certain range of data during the diagnosis target period A diagnostic method or diagnostic system for a gas turbine having diagnostic means for judging deterioration or recovery of performance by time-series decrease or increase of the standardized data input and output to the means. In order to generate a certain range of operation data that is input to the characteristic modeling unit and the diagnosis unit, at least a power generation output, an intake air temperature, and an intake air A load factor is calculated by a function including pressure as an input, and among a plurality of load factor ranges divided according to a predetermined standard, operation data in the load factor range where the calculated load factor appears most frequently (hereinafter, Base load operation data extraction means for extracting (referred to as base load data) is provided.

According to a second embodiment, in the first embodiment, as the base load operation data extraction means, the relationship between the power generation output, the intake air temperature, and the intake air pressure is determined based on operation data at a plurality of time points during the diagnosis target period. , The function We = f_We (Tci, Pci) that includes the intake air temperature Tci and the intake air pressure Pci and outputs the power generation output We
Using the identified function f_We and the identified function f_We, the power generation output value We _calc according to the intake temperature Tci and the intake pressure Pci of the operation data in the diagnosis target period is calculated, and the measured value We _{calc is} actually measured. Ratio of value We _act A = We _act / We _calc
Or a value _obtained by dividing a value at each time point in the diagnosis target period for A by a moving average value A _mov of a certain period including the time point B = A / A _mav
Means for calculating the load factor, and means for extracting data in which the value A of the load factor, or if the B value is further calculated, is within a certain range. Prepare.

As in the first or second embodiment, a third embodiment is a gas turbine performance diagnosis method or diagnosis system comprising a characteristic modeling means, a reference means, and a diagnostic means, wherein the characteristic modeling means And a characteristic model Tto = f_Tex (representing the relationship between the intake air temperature Tci and the exhaust gas temperature Tto at the maximum load factor in operation of the gas turbine, in order to generate the operation data within the certain range that is input to the diagnosis means. Tci)
Using the functional relationship for each operating data during the evaluation period, and inputs data of the intake air temperature Tci calculates the value Tto _calc exhaust temperature, and calculated the calculated value Tto _calc the exhaust temperature its measured value _{Tto act} deviation ΔTto = Tto _act - Tto _calc
Includes means for extracting data within a certain range.

  In addition, as a result of examining the processing of changes in performance characteristics when performing maintenance, which is the second problem, the inventors have responded to this problem, and at the same time, the above-mentioned “effect of deterioration included in actual machine data” The following fourth embodiment is introduced as a means for considering "."

That is, as the characteristic modeling means in the first to third embodiments, the following characteristic model expression Y = a ₁ × (Tci−Tci ₀₎ indicating the relationship between the performance index Y, the intake air temperature Tci, and the intake pressure Pci. ) + A ₂ × (Pci−Pci ₀ ) + α × t + Y ₀₀
(Here, Tci ₀ is the value of the intake air temperature in a predetermined constant standard intake condition, Pci ₀ is the value of the intake pressure in a predetermined constant standard intake condition, and t is the accumulated operating time or equivalent during the diagnosis target period. operating time, a1, a ₂ are constant coefficients, Y ₀₀ model constants, alpha is representative of the degradation representative of the performance characteristics is performance value of the object diagnosing period early in a standard intake air temperature and pressure)
Means for determining the values of the constants a ₁ , a ₂ , α, Y ₀₀ of
As the standardization means, the following equation using the determined model constants a ₁ and a ₂ : Y ₀ = Y−a ₁ × (Tci−Tci ₀ ) −a ₂ × (Pci−Pci ₀ )
By, and a value Y of the performance index, standard intake air temperature Tci _0, means for converting the value _{Y 0} in the intake pressure Pci _0.

  Here, in the characteristic modeling means, a performance characteristic model can be constructed reflecting the deterioration during the period by introducing and formulating a coefficient α representing the deterioration. Further, at this time, by dividing the term reflecting the deterioration (third term on the right side) and the term for correcting the operating conditions other than the degradation (first term on the right side), the standardization means Only changes in operating conditions excluding the deterioration coefficient can be corrected. Thereby, the evaluation result in the calculation formula of the standardization means is obtained by correcting the performance of the actual machine to the converted value under the standard atmospheric condition by correcting only the fluctuation due to the operating condition. Therefore, by evaluating the performance over time, the tendency of deterioration over time can be extracted separately from the influence of fluctuations in operating conditions.

In addition, by formulating the model as shown in the above equation, it is necessary to readjust and reconstruct the model using data for a certain period after performing maintenance, as in the conventional method. In addition, there is no inconvenience that the performance cannot be evaluated during the data accumulation period, and the performance can be continuously evaluated even if the performance varies due to maintenance. This is because, as described above, the influence of fluctuations in operating conditions and deterioration over time on performance changes is separated, so that the performance can be measured only on the basis of measured values (first term on the right side) and only the influence of fluctuations in operating conditions. This is because the evaluation can be performed by correcting (the second and third terms on the right side). As a result, in this method, the measured value is always input to Y ₀ (the first term on the right side) of the above equation, and the fluctuation due to the operating condition is corrected by the term after the second term on the right side. Regardless of whether or not there is maintenance, performance can be continuously standardized and evaluated.

  Even with aged machines whose performance characteristics have changed due to repeated maintenance and gas turbines with unclear detailed specifications, the performance dependence of performance characteristics, which has been a problem with conventional diagnostic methods, is achieved by the performance diagnosis method and system of the present invention. I was able to solve the problem of sex. In addition, the performance characteristics can be modeled by appropriately excluding the effects of deterioration over time included in the actual machine operation data collected for diagnosis, and the performance is also considered in consideration of the effects of performance changes during maintenance. Can be evaluated over time. As a result, it has become possible to evaluate performance deterioration of gas turbines or performance recovery due to maintenance with higher accuracy than conventional methods.

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

  FIG. 1 shows a processing flow example of a gas turbine deterioration diagnosis method according to the present invention. The processing procedure consists of steps 1 to 4.

  In step 1 (hereinafter referred to as base load operation data extraction step), base load operation data is extracted from time-series operation data of the actual machine. Base load operation data refers to operation data near a load factor of 100%, excluding partial load conditions. However, in the operation plan of the target gas turbine, when the load factor is not 100%, for example, when continuously operating at a load factor of 90%, or when operating at a load factor of 70% at night, these constants The operation data near the load factor may be extracted instead of the base load operation data. In the present invention, such partial load data in the vicinity of the constant load factor are also collectively referred to as base load operation data for easy explanation.

  In step 2 (hereinafter referred to as model constant determination step), a model constant of the performance characteristic model of the gas turbine is determined based on the base load operation data extracted in step 1. The performance characteristic model is implemented as a program module that calculates and outputs a predicted value of performance with the operating conditions of the gas turbine as input. Model constants refer to constants specific to the target gas turbine set in these program modules. In the present invention, the model and the model constant refer to a program module that receives data input, calculates and outputs a result, and a constant set by the program module.

  The performance here refers to, for example, a measured value such as a power generation output, or a value such as a power generation efficiency (energy ratio between the power generation output and the fuel input amount) calculated based on the measured value. In addition, the performance index is not limited to the two examples described above, but refers to all types of performance whose values change with deterioration. Particularly typical examples include power generation output, power generation efficiency, compressor or turbine pressure ratio, intake flow rate or exhaust flow rate, exhaust heat utilization efficiency, fuel flow rate, compressor efficiency, turbine efficiency, and the like. In the following, performance values are distinguished by appropriately calling performance values and performance types as performance indicators. The operating conditions are typically the temperature and pressure of the intake air. In addition to this, the operating conditions such as the intake air humidity, the fuel flow rate, the amount of steam and water injected into the combustor, and the overall operating conditions are also included. May be.

  In step 3 (hereinafter referred to as the standardization step), using the model constant determined in step 2, the performance measurement value of the base load operation data is changed to the equivalent value (standardization data) when the standard condition is corrected. Convert. As the standard conditions, for example, standard fixed conditions such as standard atmospheric conditions (intake air temperature 15 ° C., atmospheric pressure 1 atm, relative humidity 60%) defined by ISO may be adopted. As a result, the time series data of the actual machine becomes the time series data of the performance when the influence of fluctuations in the operating conditions is corrected and aligned under the constant operating conditions.

  In step 4 (hereinafter referred to as a diagnosis step), the progress of performance degradation, the performance recovery effect due to maintenance, and the like are diagnosed based on the time-series transition of the standardized data generated in step 3.

  In this method, since only the base load operation data is extracted in the step 1, the subsequent steps 2 and 3 avoid the problem of deterioration of the accuracy of the model due to the partial load characteristic of the gas turbine performance. Can be modeled. For this reason, a highly accurate result can be obtained by diagnosing the performance trend in step 4.

  The contents of the above steps 3 and 4 may be as follows. That is, in step 3, the operation condition data in the base load operation data extracted in step 1 is input to the performance characteristic model of the gas turbine whose model constant is determined in step 2, and the gas turbine corresponding to the operation condition is input. In step 4, the deviation between the prediction result of this performance and the actual measurement value is calculated, and the deterioration is evaluated from the transition of the time-series tendency of the deviation. For example, as the deterioration progresses, the actual measurement value becomes smaller than the predicted result and the deviation increases, so it is better to quantitatively evaluate the progress of deterioration and performance recovery due to maintenance based on the increase or decrease of such deviation. . The advantage of this method is that it does not require a model for standardization and can be diagnosed more easily.

  FIG. 2 shows an example of the base load operation data extraction method of step 1 in FIG. This base load operation data extraction method is hereinafter referred to as an output load factor method. The procedure consists of steps 5-7.

In step 5 (hereinafter referred to as an output characteristic model identification step), a characteristic model representing the relationship between the power generation output, the intake air temperature, and the intake air pressure is identified based on the actual time series operation data. The output characteristic model is a function represented by the following expression that includes the intake air temperature Tci and the intake air pressure Pci as inputs and outputs the power generation output We.
We = f_We (Tci, Pci) (1-1)
Specifically, for example, the function f_We is preferably as follows.
_{We = a e × (Tci-} Tci 0) + b e × (Pci-Pci 0) + α e × t + We 0 ... (1-2)
Here, t represents the operating time, and Tci ₀ and Pci ₀ are standard condition values of the intake air temperature and the intake air pressure. The operating time t only needs to indicate the passage of time, and for example, a time corrected by taking into account factors that affect deterioration, such as equivalent operating time, may be used. In the following description, it is assumed that the operation time t includes such conversion time. This term of operation time t can be omitted when the influence of deterioration over time is considered to be negligible in the set of actual machine operation data to be used, but as described above, the performance over time during the data collection period can be omitted. It is desirable to include this term if it cannot be ignored that it has deteriorated. By the influence of deterioration over time is separated from the section to the coefficients alpha _e, it can be avoided to include bias due time degradation to claim a _e, b _e operating conditions characteristic of the output, the high output characteristics There is an effect that can be modeled in accuracy.

In the formula (1-2), a _e , b _e , α _e and We ₀ indicate model constants. The identification of the model in step 5 is to determine these model constant values. a _e and b _e are coefficients for correcting the power generation output by the deviation of the intake air temperature and pressure from the standard conditions. α _e represents a rate of decrease in power generation output with time t (hereinafter referred to as a degradation coefficient). The degradation coefficient α _e can be omitted when it is considered that there is almost no performance degradation during the period of the actual machine time-series operation data used in step 5. We ₀ indicates the power generation output in the initial stage (before deterioration during the period starts) when Tci ₀ and Pci ₀ are standard condition values.

As a method for determining these model constants a _e , b _e , α _e , and We ₀ , the power generation output calculated by substituting the operating conditions included in the time series operation data of the actual machine into the right side of Equation (1-2) It is preferable to determine such that the error between the time-series calculation result and the time-series data of the power generation output included in the actual machine time-series operation data is minimized throughout the data period. This can be obtained by a known method such as a least square method.

Note that in step 5, actual machine data collected by variously changing operating conditions such as intake air temperature may be used instead of the actual machine time-series operation data. In this case, if the data collection period is short, the deterioration coefficient α _e can be omitted as described above.

  In steps 6 to 7 (hereinafter referred to as a load factor calculation step), the load factor is calculated based on the actual measurement value of the power generation output and the calculated value based on the output characteristic model.

In step 6, first, the output characteristic model (specifically, equation (1-2)) in which the model constant is determined in step 5 is added to the operation condition value (in the above example) of the actual machine time-series operation data in the deterioration diagnosis target period. The measured values of the intake air temperature and pressure) are input to calculate the value of the power generation output (this is referred to as the model calculation value _Wecalc ). Next, as shown by the following equation, the ratio A of the actual power generation output measured value We _act of the actual machine time-series operation data to the model calculated value We _calc is calculated (this is called the load factor calculated value A).
A = We _act / We _calc (2-1)
In the subsequent step 7, as shown in the following formula (2-2), a value B _obtained by dividing the value of the ratio A at a certain time point by the moving average value A _mav for a certain period including that time point is calculated (this Is referred to as a load factor calculation value B). By taking the ratio with the moving average in this way, when the fluctuation of the load factor calculation value A is large, the error fluctuation range of the calculation load factor is sufficiently small, and the plant performance is deteriorated with time and seasonal. It is possible to balance the effects of performance fluctuations reasonably.
B = A / A _mav (2-2)
In this case, as a method of taking the moving average period, for example, it is preferable to take one week immediately before the target time point or a data period of about 100 to 200 points. There are the following reasons for this. For example, when driving data is stored at intervals of 1 hour as a typical measurement record, moving average over a period of 1 to 2 days (24 to 48 points), for example, Saturdays and Sundays of weekend holidays When the power demand decreases and the load factor falls, the moving average period is included in this period, and the calculation result of the load factor in Equation (2-2) is overestimated. There is sex. In this case, the load factor actually decreases on the weekend, but the load factor does not decrease in calculation, and the load factor cannot be accurately evaluated. On the other hand, if the moving average is performed over a period of one month or longer, there is a risk that the deterioration in performance in units of one week cannot be captured because the period is too long. Considering these, when processing based on data at one hour intervals, if the moving average is performed with the above-mentioned period or data points, the effects of various operating condition fluctuations and deterioration over time may be reflected well. It is possible and suitable.

  It should be noted that the period of the actual machine time series data when calculating the load factor in these steps 6 to 7 and the period of the actual machine time series data used when determining the model constant in the above-described step 5 may be different. For example, in step 5, a constant of the output characteristic model is determined in a certain period of the actual machine time series data, and in steps 6 to 7, this model constant can be applied to the entire period for which the load factor is to be evaluated. . In this way, the model constant can be determined efficiently with a small amount of data without using all the data in the target period for degradation evaluation.

  Step 7 can be omitted when the fluctuation range of the calculation result of the ratio A according to the equation (2-1) in step 6 is sufficiently small or the value of the ratio A is sufficiently close to 1. In this case, the value of the ratio A may be a load factor calculated value.

  In step 8 (extraction step), data in which the calculated load factor in steps 6 to 7 is within a certain range is extracted. Specifically, the load factor is calculated from the operation data at a plurality of points in time during the diagnosis target period using a function including at least the power generation output, the intake air temperature, and the intake pressure as inputs, and the load factors are divided by a predetermined method. Base load data that is operation data in the load factor range where the appearance ratio of the calculated load factor is the largest in the range is extracted, and this is used as the operation data in the certain range. If the range is large, it may be about 100 ± 25% for long-term data including equipment maintenance / outage periods, but about 100 ± 3% for gas turbines with many base load operations, In particular, when the load factor is relatively constant, a range of 100 ± 1% may be extracted.

  In the method shown by the equations (1-1), (1-2), (2-1), and (2-2) of this embodiment (output load factor method), there are three types of intake air temperature, pressure, and power generation output. The load factor can be calculated from information alone. Accordingly, it is possible to effectively extract base load operation data that takes into account differences in operation conditions with a small amount of information and a large amount of calculation.

  FIG. 3 shows another example of the base load operation data extraction method of step 1 in FIG. This method is hereinafter referred to as an exhaust temperature method. The procedure consists of steps 9-10.

In step 9 (hereinafter referred to as the exhaust temperature calculation step), the exhaust temperature corresponding to the intake air temperature in the actual time series operation data based on the characteristic model (hereinafter referred to as the exhaust gas temperature characteristic model) indicating the relationship between the intake air temperature and the exhaust gas temperature. Calculate the predicted value of. As shown in the following equation, the exhaust gas temperature characteristic model is input with the intake air temperature Tci as input, and calculates and outputs the turbine exhaust temperature Tto at this time according to a certain functional relationship.
Tto = f_Tex (Tci) (3-1)
Examples of the turbine exhaust temperature Tto include the gas temperature of the turbine final stage, the gas temperature of the turbine intermediate stage, or the upper limit value gas temperature tower of the combustion temperature management index for turbine control.

  As a calculation procedure of the exhaust gas temperature characteristic model, a relational expression incorporated in the operation control logic of the gas turbine can be generally used. In general, the operation control of a gas turbine is such that the upper limit temperature to be protected as the exhaust temperature is set by a certain functional relationship when several operating conditions such as the intake air temperature and the amount of refrigerant injected into the combustor are given. Yes. During operation, the equipment is controlled so that the exhaust temperature is less than or equal to this upper limit value. This upper limit temperature corresponds to the exhaust temperature during base load operation of the facility. Therefore, when this relational expression is used as a model expression of Expression (3-1), the actual control state is reflected as it is, and the exhaust temperature at the base load operation can be accurately predicted. As a result, base load operation data can be extracted with higher accuracy, and degradation diagnosis can be finally performed with higher accuracy.

When the control logic cannot be used as the exhaust temperature characteristic model, it can be simply expressed as the following equation and modeled based on actual machine operation data and plan values.
_{Tto = a to × (Tci-} Tci 0) + b to × (Gs-Gs 0) + T to ... (3-2)
Here, Gs in the refrigerant injection amount to the combustor, but Gs ₀ is its value at standard conditions, when the type of the gas turbine is not refrigerant injection, the second term the right side will be omitted. Further, if there is a driving operation condition other than the intake air temperature that has a strong influence on the exhaust gas temperature, it may be used instead of Gs, or the term may be further added in the same manner as the first and second terms. Examples of such conditions include compressor outlet temperature and turbine intermediate stage gas temperature. The gas temperature of the turbine intermediate stage refers to the gas temperature between a plurality of cascade stages between the inlet and the outlet of the turbine. Further, a _to , b _to , and T _to in the above equations are model constants, and in particular, T _to is the exhaust temperature under standard conditions. These model constants can be determined by fitting based on a plurality of actual machine operation data, plan values, test operation data, or the like. That is, the exhaust temperature value calculated by substituting the intake air temperature and the refrigerant injection amount on the right side using multiple sets of exhaust temperature data corresponding to the intake air temperature and the refrigerant injection amount, and the actual exhaust gas temperature value The values of these model constants should be determined so that the sum of squared errors is minimized. For this, a known method such as a least square method can be used. According to this method, even if there is no information on the exhaust temperature control logic, it is possible to easily model if there is information on operation data and plan values for a set of intake air temperature, refrigerant injection amount, and exhaust temperature.

Note that the expression (3-2) may be further simplified to omit the refrigerant injection amount term, and the expression (3-3) shown below may be used. Even with a steam-injected gas turbine, with a control-type facility that maintains a constant ratio between the fuel flow rate and the steam-injection flow rate, the relationship between the exhaust temperature and the intake air temperature can be modeled with sufficiently high accuracy even with this method. The advantage in this case is that the exhaust temperature can be estimated easily with fewer variables.
_{Tto = a to × (Tci-} Tci 0) + T to ... (3-3)
In step 10 (hereinafter referred to as the extraction step), the predicted value of the exhaust temperature is calculated by the above-described equation (3-1) or equations (3-2) and (3-3), and the deviation of the actually measured value from this is calculated. Data that falls below a predetermined value is extracted. The extraction condition may be determined based on, for example, that the deviation is within ± 1 to 2 ° C. In particular, when the actually measured value is lower than the predicted value, it is preferable to further narrow the allowable range of deviation. In such a case, the operating state is on the partial load state side due to a decrease in output or a decrease in the amount of heat generated by the fuel. If data on the partial load side is eliminated as much as possible in this way, operation data can be extracted with higher accuracy near a load factor of 100%, and deterioration can be diagnosed with higher accuracy in the end.

  This method (exhaust temperature method) has an advantage that it is not necessary to model complicated characteristics of the load factor from actual machine data as in the embodiment (output load factor method) described in FIG. Since the 100% load output of the gas turbine varies depending on conditions such as the intake air temperature, the fuel flow rate, and the refrigerant injection amount, the load factor corresponding to the operation state cannot be calculated simply from the measured output value alone. For this reason, FIG. 2 shows a calculation method based on the output load factor method, but it still requires a certain amount of calculation and processing procedure to build a model. On the other hand, in the exhaust temperature method, the relationship between the exhaust temperature and the intake air temperature usually has a control logic or a simple relational expression used for control in many cases. You can use these existing equations without building your own. Therefore, it is possible to build a model in a labor-saving manner and a highly accurate model from the beginning (because it is actually used for control, it is normal that the operation data of the actual machine is controlled and operated according to its value) Can be used to efficiently build and operate a diagnostic system.

  Moreover, the information used with the method shown by Formula (3-1)-(3-3) is only intake air temperature and exhaust gas temperature, or also refrigerant | coolant injection amount, and 2-3 pieces. In this method, it is possible to determine whether or not the load factor is in the vicinity of the steady load by representing how various differences in various operating conditions affect the load factor only by these few conditions. Therefore, the extraction of the base load operation data considering the difference in the operation conditions can be effectively performed with a small amount of information and a calculation amount separately from the case of FIG.

  In the exhaust gas temperature method, the base load operation data can be extracted effectively with such a small amount of variables because the exhaust gas temperature has the following characteristics. In other words, the exhaust temperature is determined thermodynamically mainly by three factors, that is, the intake flow rate, the fuel flow rate, and the refrigerant injection flow rate. These three factors are determined in common from the result of the exhaust gas temperature control of the gas turbine. And exhaust gas temperature control is controlled so that the load factor of a gas turbine becomes near the maximum. Therefore, it can be said that the relationship between the intake air temperature and the exhaust gas temperature, which is the main input / output of the exhaust gas temperature control, is an input / output relationship that summarizes the effects of the above three factors affecting the load factor. By focusing on this characteristic, the exhaust temperature method can reduce the input variables for determining the load factor to the above two or three items.

  In the above description, the base load operation data extraction method in step 1 includes a method of using control mode information in addition to the above-described method. The operation control mode of the gas turbine is roughly divided into exhaust temperature control in a 100% load region or output control in accordance with the target output. In the exhaust gas temperature control, a target value of the exhaust gas temperature is set in advance with a certain function relationship in accordance with the intake air temperature, and the driving operation is controlled so that the exhaust gas temperature during operation becomes the target value. This is to prevent the temperature of the high temperature portion of the gas turbine from exceeding the heat resistance temperature of the material. The output control is mainly operated so that the output becomes a target value at the time of partial load.

  When a control signal indicating the operation mode (hereinafter referred to as an operation mode signal) is acquired from a part of the control device or the control system, the base load operation data is obtained from the time series data. Can be extracted efficiently. For this purpose, for example, data indicating that the operation mode signal indicates exhaust temperature control in a 100% load region may be extracted as base load data.

  Such a method has an effect that the base load operation state can be accurately grasped according to the control state of the equipment, and the obvious partial load data can be efficiently excluded beforehand. However, on the other hand, such an operation mode signal is often not included in the collection items of actual machine operation data. In this case, it is necessary to add or modify equipment for acquiring and transmitting this signal from the control device or the control system. On the other hand, in the base load extraction method of FIG. 2 and FIG. 3 described above, base load operation data can be efficiently extracted using only existing measurement data without such modification.

  Further, as another method of extracting the base load operation data in the step 1, a method of determining and extracting the load factor based on the compressor inlet guide blade opening degree may be used. In this method, the ratio of the inlet guide blade opening to the maximum opening set in normal operation is less than 100%, for example, 97 to 99% or less, and the remaining data is used as a base. It should be extracted as road operation data. In the gas turbine that variably controls the inlet guide blade opening, the inlet guide blade opening is manipulated in order to control the combustion conditions and the combustion temperature by changing the intake flow rate. The inlet guide blade opening degree is constant regardless of weather conditions such as the intake air temperature when the gas turbine is in base load operation near the maximum load factor. For this reason, in such a type of gas turbine, the opening degree of the inlet guide blade may be a good guideline for the load factor. However, since the inlet guide blade angle is often not manipulated unless the load factor falls below a certain level, the accuracy for determining the load factor may not be sufficient only with the opening degree information. Therefore, although the base load operation data extraction method based on the inlet guide blade opening degree may have a rough determination accuracy of the load factor, it is possible to perform simple processing without performing complicated processing as described in the above example. There is an advantage that the range of base load operation data can be extracted.

  With reference to FIGS. 4 and 5, an example of a detailed procedure for determining the model constant in step 2 in FIG. 1 will be described below. In step 2, as described above, the model constant of the performance characteristic model of the gas turbine is determined based on the base load operation data extracted in step 1. At this time, if the target gas turbine is used for an energy service business or an aged machine, etc., the owner of the facility or the operator of operation and maintenance must Is generally unknown. In particular, the model constant is design information of the manufacturer of the target equipment, and is generally hardly disclosed. Even if they are disclosed, performance characteristics are often different from those at the time of design due to repeated maintenance and parts replacement.

  In such a case, it is necessary to construct a performance characteristic model from actual operation data. For this purpose, it is necessary to collect data so that the range of the intake air temperature, that is, the atmospheric temperature, which is a typical operation condition, includes the entire operation range. For example, in order to include the range of annual maximum and minimum temperatures, it is desirable that a period of about half a year is required as a period between at least the maximum temperature and the minimum temperature. However, the performance of the gas turbine deteriorates even during such a period. The problem with this is that the effects of degradation are included in the data collected to build a model in a normal state before the equipment is degraded. Therefore, there is a need for a method capable of identifying a performance characteristic model before deterioration even from actual machine operation data including the influence of deterioration over time.

  In order to cope with this, in the present invention, after modeling the performance characteristics of actual machine data in consideration of the influence of deterioration, by excluding the calculation part reflecting the deterioration from this model, the initial performance before the deterioration progresses A method for obtaining a characteristic model is provided.

  This is schematically explained as follows using FIG. That is, the performance characteristic model used in the present invention calculates the performance by inputting the operating condition 14 such as the atmospheric condition and the model constant 12 specific to the target machine determined by the design condition to the performance characteristic model 11, and the calculation result 15 When outputting (performance calculation value), a model constant (hereinafter, particularly referred to as a deterioration coefficient 13) for reflecting the progress of deterioration in the performance calculation is added. As a usage of this characteristic model, when the model constant 12 is identified, the model constant 12 and the degradation are determined using the time series data of the base load operation of the actual machine extracted in the above-described step 1 (base load operation data extraction step). The coefficient 13 is determined. As an initial performance characteristic model before performance deterioration occurs, a characteristic model excluding the deterioration coefficient 13 and the performance calculation portion using the same is used as the characteristic model. That is, the characteristic model before performance degradation is obtained by omitting the degradation coefficient 13 and the calculation part related thereto in FIG.

An example of such a performance characteristic model modeling method is shown below. Expressions (4-1), (4-2), and (4-3) are examples of modeling methods provided by the present invention, and these are collectively referred to as Expression (4). Equation (4-1) calculates the performance Y by adding the performance correction amount ΔY due to deviation from the standard condition to the performance Y ₀ when the operating condition is the standard condition. At this time, the equation (4-2) indicates that the performance correction amount ΔY is a function f_opr (hereinafter referred to as an operation condition correction function) of at least one or more operation conditions x _i (i = 1, 2,...). Calculate as The above-described model constant 12 in FIG. 4 is included in the coefficients and constant terms used in the operating condition correction function f_opr. Further, the equation (4-3) is calculated by a function f_dgr (hereinafter referred to as a reference value temporal decrease function) so that the performance Y ₀ under the standard condition is changed according to the progress of deterioration. The reference value temporal decrease function f_dgr includes the operating time t as a variable, and in addition to this, the initial performance value Y ₀₀ (a value under standard conditions and a constant) before the deterioration occurs and the elapsed operating time t. At least one constant coefficient α _j (j = 1, 2,...) (Deterioration coefficient 13 in FIG. 4) for simulating the progress of performance degradation is included as a constant.

Here, the performance Y is typically power generation output, power generation efficiency, compressor pressure ratio, fuel flow rate, compressor efficiency, turbine efficiency, and intake air flow rate. Y is not limited to these, and is an index that changes in value due to deterioration of equipment or the effect of maintenance. The operating conditions indicate the environmental conditions such as the atmospheric temperature and pressure described above, and the operating conditions such as the fuel flow rate. The standard conditions are, for example, the standard atmospheric conditions determined by ISO and the operating conditions corresponding to the atmospheric conditions. Indicates the value of.
Y = ΔY + Y ₀ (4-1)
ΔY = f_opr (x _i ) (4-2)
Y ₀ = f_dgr (t) (4-3)
The characteristic of these equations (4) is that the influence of the change in the performance characteristics due to deterioration is expressed by the second term on the right side of equation (4-1), equation (4-3) indicating the performance under standard conditions. )). Strictly speaking, the change in the performance characteristics due to the deterioration extends to the operating condition correction function f_opr (formula (4-2)) of the correction term ΔY (the first term on the right side of the formula (4-1)). However, the inventors have found that analysis of the performance characteristics of the gas turbine, the effect of the correction term [Delta] Y, as compared with the effect on the time course of standard conditions in terms performance Y _0, was found to be relatively small. Therefore, the deterioration over time of the performance is modeled as a reference value deterioration function f_dgr that changes the value of the performance value Y ₀ under the standard conditions in accordance with the deterioration as described above. A modeling method has been devised in which the operating condition correction function f_opr for correcting the performance is constant regardless of deterioration. This method models the complicated effects of gas turbine performance degradation, focusing only on the aging of the output value under standard conditions, as described above, and omits the effect on performance correction due to differences in operating conditions. Yes. Due to this simplification, the present system can separate and evaluate the time-dependent deterioration of the gas turbine performance and the complicated characteristics of the performance change depending on the operating conditions in a labor-saving and efficient manner.

A specific example of the model formula of the performance characteristic model 11 of this formula (4) is as shown in formula (5-1). In this equation, x _i0 represents a value under a standard condition of at least one operating condition x _i (i = 1, 2,..., N). The symbol Σ indicates that the term a _i × (x _i −x _i0 ) is added to i = 1, 2,... N (the description of Σ is the same hereinafter). The coefficient a _i (i = 1, 2,...) Is a correction coefficient for the performance Y according to the deviation of the i-th operating condition x _{i from} the standard condition x _i0 . α is a deterioration coefficient of the performance Y according to the operating time. Constant term Y ₀₀ represents an initial value prior to the Performance values Y ₀ at standard conditions, the performance is degraded. In the present invention, the initial value before performance deterioration refers to the initial value during the target period.
Y = Σa _i × (x _i −x _i0 ) + (α × t + Y ₀₀ ) (5-1)
_{Y = Σa i × (x i} -x i0) + Y 00 ... (5-2)
In the equation (5-1), the coefficient a _i (i = 1, 2,...) And the constant term Y ₀₀ correspond to the model constant 12 in FIG. As a method of determining the values of a _i , α, and Y ₀₀ , a method such as a known least square method or maximum likelihood estimation method of multiple regression analysis using the base load actual machine time-series operation data extracted in step 1 is used. Calculate with

  If the model constant is determined in this way in the equation (5-1), a model equation showing the performance characteristics before the progress of deterioration can be obtained by removing the term of deterioration with time as shown in the equation (5-2). In this method, the performance degradation due to the gas turbine operating condition variation and deterioration is separated by separating the term of performance deterioration with time and the operating condition variation term in the extremely simple form shown in equation (5-1). Can be simulated simply and easily.

Table 1 shows a preferable correspondence example between the performance evaluation index Y and the operating condition variable x _i when the performance characteristic is modeled by the equation (5-1). In Table 1, ◎ indicates that it is particularly desirable to use as an operating condition for modeling the target performance index, and ○ indicates that the model can be additionally used when the accuracy of the model is insufficient. It is.

As shown in Table 1, among the performance indicators Y, the power generation output, power generation efficiency, compressor pressure ratio, fuel flow rate, compressor efficiency, turbine efficiency, and intake air flow rate are modeled with sufficiently high accuracy by being expressed as follows: Can be Incidentally, the compressor pressure ratio can higher accuracy is good, or a further characteristic model when the function of intake air temperature and humidity as a function of intake air temperature alone without using the intake air pressure to the variable x _{i.
Y = a 1 × (Tci-} Tci 0) + a 2 × (Pci-Pci 0) + α × t + Y 00 ... (5-3)
In addition, as for how to use the variable marked with ○ in Table 1, it may be combined as a data extraction condition in the above-described base load operation data extraction step 1 instead of being incorporated in the modeling equation as described above. That is, the determination conditions of the step 8 and the step 10 for determining the extraction data in the above-described base load operation data extraction step 1 are further added with the conditions of the upper and lower limit allowable ranges of the values of the variables marked with ○. Also good. In this way, although it affects the characteristic model of the performance index, it does not affect centrally. The influence of the fluctuation of these variables is preliminarily determined in the data extraction stage (step 1) before the characteristic model is constructed. Can be excluded. Therefore, when modeling the performance characteristics in step 2, it is possible to model with high accuracy by focusing on the operating conditions that have the main influence.

  When the performance characteristic model formula is not linear as in formulas (5-1) to (5-3), the model constant may be determined by the procedure shown in FIG. That is, the initial values of the model constant 12 and the degradation coefficient 13 are first set (step 20), and then the performance is calculated by inputting the operating condition 14 into the performance characteristic model 11 in which these constants are set (result ( The performance calculation value 15) may be output (step 21), and it may be determined (step 22) whether the performance calculation value 15 is within a predetermined error range with respect to the actual measurement value. If the performance calculation value 15 is not within a predetermined range with respect to the actual measurement value, the model constant 12 and the deterioration coefficient 13 are corrected (step 23), and the above steps 21 to 22 are executed again. It is good to repeat until the determination result of 22 falls below a certain range. The values of the model constant 12 and the deterioration coefficient 13 when the termination condition of the step 22 is satisfied are values finally determined. These can be performed by a method such as a known nonlinear least square method.

  An example of the detailed procedure for standardization in step 3 in FIG. 1 will be described below with reference to FIG. In step 3, as described above, using the model constant 12 determined in step 2, the time series data of the actual performance of the gas turbine is converted into performance equivalent values under standard conditions. As shown in FIG. 6, a model that performs this (hereinafter referred to as a standardized model 17) inputs a model constant 12 and operation data 16, and sets the performance value of the actual machine that changes according to the operation conditions to a certain level. It is converted into an equivalent value (hereinafter referred to as standardized data 18) when corrected under standard conditions, and this is output. Here, as the model constant 12, the value determined in the above-described step 2 can be used. Further, the operation data 16 is a collective term for data obtained by combining the operating conditions 14 of the actual machine and the actual measured value of the performance Y of the actual machine at this time.

Model type of the reference model is as shown in equation (6-1), the reference data _{Y 0,} the performance values Y and previously Formula (4-2) in said operating conditions correction function f_opr _{(X i)} Calculate based on. More specifically, for example, in the form corresponding to the above-described expression (5-1), as in the expression (6-2), in the form corresponding to the expression (5-3), as in the expression (6-3). Good. In these cases, as the model constant a _i , the one previously obtained by the equation (5-1) can be used. In this method, the standardization calculation can be efficiently executed using the model constant 12 determined in the previous step 2 without creating a new standardization model from the beginning.
_{Y 0 = Y - f_opr (X} i) ... (6-1)
_{Y 0 = Y - Σa i ×} (x i -x i0) ... (6-2)
_{Y 0 = Y - a 1 ×} (Tci-Tci 0) - a 2 × (Pci-Pci 0) ... (6-3)
It should be noted that the period of the actual machine time series data used for determining the model constant in the step 2 described above may be different from the period of the actual machine time series data for standardizing the actual machine data in the step 3. For example, in step 2, model constants of the performance characteristic model are determined in a certain period of the actual machine time-series data, and in step 3, the model constants are applied to the entire period for which performance degradation or performance recovery tendency due to maintenance is to be evaluated. Can be applied. In this way, the model constant can be determined efficiently with a small amount of data without using all the data in the target period for degradation evaluation. This is a useful method for evaluating a period including a time when performance is restored by maintenance. For example, if maintenance is performed at a facility whose performance has deteriorated over time, and the performance has recovered significantly at once, the actual operation data including such performance discontinuity periods will be used. If the model constants of the performance characteristic model are determined, the accuracy of the model is deteriorated. In such a case, for example, the model constant of the performance characteristic model is determined (step 2) before the maintenance is performed (or after), and the model constant is maintained when the performance is standardized (step 3). It is good to calculate the performance standardized data using the same value without changing the value before and after the implementation.

  FIG. 7 shows an example of an embodiment of a gas turbine diagnostic system according to the present invention.

  In this system, first, operation data collected at a certain period of time for the gas turbine 101 is transmitted from the transmission unit 111 and received by the reception unit 113 via the communication line 112. The received information is processed by the calculation means 102 and output to the output means 103. Here, the communication line 112, the transmission means 111, and the reception means 113 may be any known information transmission means and transmission / reception means thereof. For example, any communication means such as the Internet or a wired / wireless dedicated information line and transmission / reception means thereof may be used. Can be used.

  The internal configuration and processing system of the calculation means 102 are as follows. The input unit 130 inputs the information received from the reception unit 113 to the base load operation data extraction unit 131 shown below. Based on the actual machine operation data input from the input unit 130, the base load operation data extraction unit 131 extracts the base load operation data by executing the contents of step 1 and outputs the data. The model constant determination unit 132 executes the contents of the above-described step 2 using the base load operation data output from the previous base load operation data extraction unit 131 as input information, and sets the value of the model constant 12 determined thereby. Output. The standardization unit 133 executes the contents of the above-described step 3 using the value of the model constant 12 output by the previous model constant determination unit 132 and outputs the standardized data 18. Here, the functions of the means 131 to 133 may be distributed at any location on the information path from the data collection means attached to the gas turbine 101 to the final output means 103. For example, the base load operation data extraction unit 131 can be provided in a stage before the information is transmitted by the transmission unit 111. In this way, the information transmitted through the communication line 112 is only the base load data after extraction, so that the amount of information communication can be reduced, and the execution of the base load operation data extraction means 131 on the calculation means side is unnecessary. Therefore, the calculation load can be reduced.

  The result processed by the calculation means 102 as described above is transmitted to the output means 103 via the information line 114 and output. Specifically, the output means 103 may be any known means such as a display device such as a computer display, electronic data storage means such as a hard disk or memory, and information printing / drawing means such as a printing machine. The data output format in the output means 103 is output as a trend graph indicating time-series transition of the standardized data or time-series record data.

  As an example, the positional relationship between the installation locations of the gas turbine 101, the calculation means 102, and the output means 103 in this system is assumed to be in a location different from the installation site of the gas turbine 101. In this way, the deterioration status of a large number of facilities can be intensively monitored and grasped at a remote monitoring center or the like. In addition, since the calculation means 102 can be operated in the management of the diagnostic operator, and the calculation means can be updated to a new model and the calculation method can be improved, it can be operated flexibly and efficiently in the long term. .

  However, the positional relationship between the installation locations is not limited to that described here, and may be arbitrary. For example, the output unit 103 may be installed at the installation site of the gas turbine 101. This is when a business operator (referred to as a site business operator here) where the gas turbine 101 is installed receives a performance diagnosis service for the gas turbine 101 from another business operator (referred to as a diagnostic business operator). This is a preferred form. The site operator can obtain only the information of the diagnosis result of degradation that is finally required without installing and maintaining extra equipment such as the calculation means 102.

  Alternatively, for example, the output unit 103 is arranged at the head office of the installation company (site company) of the gas turbine 101 as another place different from the installation site of the gas turbine 101 and the installation site of the calculation unit 102. May be. This is suitable when the department that develops and examines the maintenance plan based on the diagnosis result information of the deterioration state of the gas turbine 101 is located at a site different from the site, such as the head office of the site operator.

  The example which evaluated the time-dependent change of the performance of a gas turbine by the method of this invention using FIGS. 8-10 is shown below.

  FIG. 8 is raw data of the transition of the power generation output during operation of a certain gas turbine for about 17,000 hours. The time course of the fluctuations is not only greatly waving in the annual cycle due to annual fluctuations in the intake air temperature, but also due to fluctuations in the load factor during operation and daily fluctuations in the intake air temperature. In this state, the degree of deterioration cannot be determined.

  In contrast to this, FIG. 9 omits the base load operation data extraction step 1 in the method of the present invention, identifies the model constant (step 2), and normalizes it to the value at the standard intake air temperature and pressure. The result output in (Step 3) is shown. Here, it was converted into an equivalent value under the conditions of an intake air temperature of 15 ° C. and a relative humidity of 60% determined by ISO. When this result is seen, although the big up-and-down fluctuation seen by FIG. 8 is cancelled | dissolved to some extent, the fluctuation | variation of an annual cycle still remains large, and it is difficult to determine degradation of performance.

  FIG. 10 shows that the method according to the present invention extracts base load operation data (step 1), identifies model constants (step 2), and calculates values at standard intake air temperature and pressure. Shows the result of normalization (step 3) and output. The triangle mark in the figure indicates the timing of engine replacement, blade replacement, and other parts replacement. Looking at the time course of the standardized data, it is clear that the performance recovered immediately after the maintenance was performed, and then decreased over time. In particular, in (2) and (5) indicating engine replacement, the performance was significantly recovered, and in (1) indicating turbine blade replacement, performance was significantly recovered for a while immediately after the replacement. However, after that, the performance deteriorates with time. In addition, in (3) and (4) where other parts were replaced due to an abnormality, the performance dropped sharply by about 1% immediately before the replacement, and this decrease was recovered by replacing the parts. Recognize. In addition, the vertical fluctuation range of the standardized data from time to time is within the relative ratio ± 1%, and the vertical fluctuation is uniform. It can be said that a general performance degradation can be identified in units of almost 1%. In this way, unlike FIG. 8, in FIG. 9, it is possible to evaluate the vertical fluctuation of the performance due to the progress of deterioration and the execution of maintenance with high accuracy. This is an effect of the base load operation data extraction step 1 in the method of the present invention.

  FIG. 11 shows an example of a display screen that is preferably provided in the gas turbine performance diagnosis system of the present invention. The display screen 140 is an example of a screen of the display device showing the output unit 103 (FIG. 7). The display screen 140 includes an original graph 141, an object 142, and an extraction graph 143 described below. The original graph 141 is a graph 141 that displays the time series change of the operation data (the original data) at a plurality of points in time during the diagnosis target period for the performance index. The object 142 is an object such as a button or a display menu arranged on the display screen. When the object 142 is clicked or selected on the screen, the base load operation data extraction means extracts the base load operation data from the original data. Be started. The extraction graph 143 is a graph that displays a time-series change of base load operation data (hereinafter referred to as extraction data) extracted by the base load operation data extraction means. In place of the original graph and the extracted graph, a graph (hereinafter referred to as an extracted superimposed graph) that is displayed superimposed on a single graph by changing the symbol or color of the plot so that the original data and the extracted data can be distinguished is provided. May be. Further, a graph 144 (hereinafter referred to as a standardized graph) that displays a time series change of the standardized data output from the standardizing means may be provided.

  Although the number of the extraction execution buttons 142 is one in the figure, it is not necessary to limit to this, and various base load operation data extraction methods such as the output load factor method, the exhaust temperature method, and the other methods described above can be used. A plurality of corresponding buttons may be arranged so that selection of an extraction method and extraction conditions (such as setting of upper and lower limit ranges) can be designated. At this time, it is more preferable that the plurality of buttons allow a plurality of simultaneous selections, and that an AND condition (product set) of each extraction result by a plurality of selected extraction methods be an extraction result.

  The extraction of the base load operation data greatly affects the accuracy of the performance diagnosis and is extremely important, as described above by comparing the cases of FIG. 9 and FIG. Since the display screen 140 includes the extraction execution button 142 and the original graph 141, the extraction graph 143, or the extracted overlapping graph as described above, how the base load operation data important for diagnosis is extracted. When the user wants to confirm, it can be displayed quickly.

  Further, when the standardized graph 144 is also provided, the user can see the base load extraction status in comparison with the performance transition status shown in the standardized graph. Thus, it is possible to comprehensively judge the performance degradation status and the base load extraction status affecting the user, and assist the user in performing the diagnostic work intuitively and with high accuracy.

  When a plurality of extraction execution buttons 142 are provided according to the extraction method as described above, the user of this system observes the extraction status of the base load operation data on the screen, for example, and the extraction is sufficiently appropriate. The extraction method and combination can be changed when it is determined that it has not been completed. Since the extraction result and the deterioration diagnosis result according to this change are immediately reflected in the extraction graph 143 and the standardized graph 144, the user can easily try various extraction methods and combinations thereof on the screen and display them. The results (extracted graph, standardized graph) can be compared. As described above, the present system can interactively display the base load operation data extraction status corresponding to the extraction method according to the user input, and thus can efficiently assist the user in selecting the most accurate extraction method.

  In the gas turbine performance deterioration diagnosis method described above, the diagnosis accuracy can be further improved by the following. That is, at the time of base load operation data extraction in step 1, it is preferable that the operation conditions are further narrowed down to data within a certain range (under AND conditions). As such operating conditions, for example, conditions relating to process input such as refrigerant injection quantity such as steam injection or temperature / pressure / heat quantity thereof, or temperature / flow rate / pressure conditions of a reheat cycle are applicable.

  Similarly, when calculating the output load factor method in the base load operation data extraction in step 1 and determining the performance characteristic model in steps 2 and 3, the model is divided into a plurality of intake air temperature condition ranges. It is also an effective method. The output of gas turbines improves when the intake air temperature decreases, but in practice, there are many operations that suppress the output in the region where the intake air temperature is low in accordance with the capacity of the generator. Performance characteristics may change in the intake air temperature range. This method can flexibly cope with such characteristic changes.

The flowchart which shows an example of the performance degradation diagnostic method of this invention. The flowchart which shows an example of the base load driving | operation data extraction method in the performance degradation diagnostic method of this invention. The flowchart which shows another example of the base load driving | operation data extraction method in the performance degradation diagnostic method of this invention. The figure which shows the input / output of an example of a performance characteristic model in the performance degradation diagnostic method of this invention. The flowchart which shows an example of the model constant identification procedure of a performance characteristic model in the performance degradation diagnostic method of this invention. The figure which shows the input / output of an example of the standardization model in the performance degradation diagnostic method of this invention. The block diagram which shows an example of the diagnostic system using the performance degradation diagnostic apparatus of this invention. The trend figure which shows the raw data of a time-dependent change of gas turbine performance (output). The trend figure which shows the result of having normalized the data of FIG. 8, without extracting base load operation data. FIG. 9 is a trend diagram showing a result of standardizing the data of FIG. 8 after extracting base load data by the method of the present invention. The figure which shows the example of a display screen of the diagnostic system using this invention.

Explanation of symbols

  DESCRIPTION OF SYMBOLS 1 ... Base load operation data extraction process, 2 ... Model constant determination process, 3 ... Standardization process, 4 ... Diagnosis process, 5 ... Output characteristic model identification process, 6 ... Load factor calculation process, 7 ... Load factor calculation process, 8 ... Extraction process, 9 ... Exhaust temperature calculation process, 10 ... Extraction process, 11 ... Performance characteristic model, 12 ... Model constant, 13 ... Degradation coefficient, 14 ... Operating condition, 15 ... Performance calculation value, 16 ... Operation data, 17 ... Standardized model 18 ... Standardized data 101 ... Gas turbine 102 ... Calculating means 103 ... Output means 131 ... Base load operation data extracting means 132 ... Model constant determining means 133 ... Standardizing means 140 ... Display screen.

Claims (22)

Based on a range of operating data during the gas turbine diagnostic period, at least one of the performance indicators of the gas turbine is characteristically modeled as a function that includes at least the intake air temperature and the intake air pressure as inputs.
Based on the functional relationship of the characteristic model, a standardized model that converts the performance index into standardized data that is a value at a predetermined intake air temperature and intake air pressure, and a variable that includes at least the performance index, the intake air temperature, and the intake air pressure. Model as a function that outputs the normalized data as input,
Using the standardized model, the value of the performance index included in a certain range of operation data during the diagnosis target period is converted into standardized data and output, and the standardized data output is time-sequentially A method for diagnosing performance of a gas turbine that determines deterioration or recovery of performance by a significant decrease or increase,
As a certain range of operation data during the diagnosis target period, a load factor is calculated from a plurality of time operation data during the diagnosis target period by a function including at least a power generation output, an intake air temperature, and an intake pressure as inputs. Base load data that is operation data in the load factor range in which the calculated load factor appearance ratio is the highest among a plurality of load factor ranges divided by the above-described method is extracted, and the operation data in the certain range is extracted. A method for diagnosing performance of a gas turbine, characterized in that:   2. The gas turbine according to claim 1, wherein the performance index includes at least one selected from a power generation output, a power generation efficiency, a compressor pressure ratio, a fuel flow rate, a compressor efficiency, a turbine efficiency, and an intake air flow rate. Performance diagnosis method. 2. The method of extracting the base load data according to claim 1, wherein the relationship between the power generation output, the intake air temperature, and the intake air pressure is determined based on the operation data at a plurality of points in time during the diagnosis target period based on the intake air temperature Tci and the intake air pressure Pci. Function We = f_We (Tci, Pci) that outputs power generation output We
Identified as
Using the identified function f_We, a power generation output value We _calc corresponding to the intake air temperature Tci and the intake pressure Pci of the operation data in the diagnosis target period is calculated, and the ratio A = of the actually measured value We _{act to} the calculated value We _calc We _act / We _calc
Or a value _obtained by dividing the value of each A at each time point in the diagnosis target period by the moving average value A _mav for a certain period including the time point B = A / A _mav
As the load factor,
Gas turbine performance diagnosis characterized by a method of extracting data in which the value of A with respect to the load factor, or further, if the value of B is calculated, is within a predetermined range Method. Based on a range of operating data during the gas turbine diagnostic period, at least one of the performance indicators of the gas turbine is characteristically modeled as a function that includes at least the intake air temperature and the intake air pressure as inputs.
Based on the functional relationship of the characteristic model, a standardized model that converts the performance index into standardized data that is a value at a predetermined intake air temperature and intake air pressure, and a variable that includes at least the performance index, the intake air temperature, and the intake air pressure. Model as a function that outputs the normalized data as input,
Using the standardized model, the value of the performance index included in a certain range of operation data during the diagnosis target period is converted into standardized data and output, and the standardized data output is time-sequentially A method for diagnosing performance of a gas turbine that determines deterioration or recovery of performance by a significant decrease or increase,
The range of operation data during the diagnosis target period includes an intake air temperature Tci at the maximum load factor in operation of the gas turbine, an exhaust gas temperature, a gas temperature at an intermediate stage of the turbine, or a combustion temperature management index for control. A characteristic model Tto = f_Tex (Tci) indicating the relationship with the upper limit value Tto
Using the function relationship, the original data which is operation data of a plurality time points during the diagnosis period, and inputs data of the intake air temperature Tci calculates the value Tto _calc exhaust temperature, and calculated value Tto _calc the exhaust temperature its measured value _{Tto act} deviation ΔTto = Tto _act - Tto _calc
Is a data turbine performance diagnostic method characterized in that the data is extracted from data within a predetermined range. 2. The method of claim 1, wherein the characteristic modeling method uses a performance index Y from a predetermined standard operating condition value x _{i0 of} at least one operating condition x _i (i = 1, 2,..., N). An operation condition correction function f_opr (x _i ) that corrects the influence of deviation and a reference value temporal decrease function f_dgr (t) that represents a decrease over time according to the cumulative operation time or equivalent operation time t of the performance value at the standard condition value The sum is expressed by the following characteristic model formula,
Y = f_opr (x _i ) + f_dgr (t)
An operation condition correction function f_opr (x _i ) and a reference value temporal decrease function f_dgr (t) in the characteristic model formula are identified based on the certain range of operation data. Performance diagnostic method. 6. The standardized model for converting the performance index into standardized data that is a value at a predetermined intake air temperature and intake air pressure based on the functional relationship of the characteristic model, at least the performance index and the intake air temperature A method of modeling as a function that outputs a variable including the intake pressure and outputs the normalized data,
The value Y of the performance index is expressed by the following equation using the identified operating condition correction function f_opr (x _i ): Y ₀ = Y−f_opr (x _i )
A method for diagnosing performance of a gas turbine, characterized in that the value is converted into a value under standard conditions by calculation and output. In claim 1, the characteristic modeling method represents the relationship between the performance index Y, the intake air temperature Tci, and the intake air pressure Pci by the following characteristic model equation:
_{Y = a 1 × (Tci-} Tci 0) + a 2 × (Pci-Pci 0) + α × t + Y 00
(Here, Tci ₀ is the intake air temperature under a predetermined standard intake condition, Pci ₀ is the intake pressure under a predetermined standard intake condition, t is the accumulated operating time or equivalent operation time during the diagnosis target period, a ₁ and a ₂ are model constants representing performance characteristics, α is a constant coefficient representing degradation, and Y ₀₀ is a performance value at the beginning of the target diagnosis period at standard intake air temperature and pressure)
A method for diagnosing performance of a gas turbine, characterized in that the values of constants a ₁ , a ₂ , α, and Y _{00 in} the characteristic model formula are determined based on the certain range of operation data. 8. The standardization model for converting the performance index into standardized data that is a value at a predetermined intake air temperature and intake air pressure based on the functional relationship of the characteristic model, at least the performance index and the intake air temperature. A method of modeling as a function that outputs a variable including the intake pressure and outputs the normalized data,
The value Y of the performance index is expressed by the following equation using the determined model constants a ₁ and a ₂ : Y ₀ = Y−a ₁ × (Tci−Tci ₀ ) −a ₂ × (Pci−Pci ₀ )
A method for diagnosing performance of a gas turbine, characterized in that it is converted into a value Y ₀ at a standard intake air temperature Tci ₀ and intake air pressure Pci ₀ by the calculation of 5. The characteristic modeling method according to claim 4, wherein the performance index Y is obtained from a predetermined standard operating condition value x _{i0 of} at least one operating condition x _i (i = 1, 2,..., N). An operation condition correction function f_opr (x _i ) that corrects the influence of deviation and a reference value temporal decrease function f_dgr (t) that represents a decrease over time according to the cumulative operation time or equivalent operation time t of the performance value at the standard condition value The sum is expressed by the following characteristic model formula,
Y = f_opr (x _i ) + f_dgr (t)
An operation condition correction function f_opr (x _i ) and a reference value temporal decrease function f_dgr (t) in the characteristic model formula are identified based on the certain range of operation data.
Based on the functional relationship of the characteristic model, a standardized model that converts the performance index into standardized data that is a value at a predetermined intake air temperature and intake pressure is a variable that includes at least the performance index, the intake air temperature, and the intake air pressure. as input, a method of modeling as a function that outputs the reference data is, the value Y of the performance index, the operating conditions were identified correction function f_opr (x _i) with the following equation Y ₀ = Y - f_opr (x _i )
A method for diagnosing performance of a gas turbine, characterized in that the value is converted into a value under standard conditions by calculation and output. 5. The characteristic modeling method according to claim 4, wherein the relationship between the performance index Y, the intake air temperature Tci, and the intake air pressure Pci is expressed by the following characteristic model equation:
_{Y = a 1 × (Tci-} Tci 0) + a 2 × (Pci-Pci 0) + α × t + Y 00
(Here, Tci ₀ is the intake air temperature under a predetermined standard intake condition, Pci ₀ is the intake pressure under a predetermined standard intake condition, t is the accumulated operating time or equivalent operation time during the diagnosis target period, a ₁ and a ₂ are model constants representing performance characteristics, α is a constant coefficient representing deterioration, and Y ₀₀ is a performance value at the beginning of the target diagnosis period at the standard intake air temperature and pressure)
A method of determining values of constants a ₁ , a ₂ , α, and Y _{00 in} the characteristic model formula based on the certain range of operation data;
Based on the functional relationship of the characteristic model, a standardized model that converts the performance index into standardized data that is a value at a predetermined intake air temperature and intake pressure is a variable that includes at least the performance index, the intake air temperature, and the intake air pressure. Is used as a function for outputting the normalized data, and the value Y of the performance index is expressed by the following equation using the determined model constants a ₁ and a ₂ : Y ₀ = Y−a ₁ × ( _{Tci-Tci 0) - a 2} × (Pci-Pci 0)
A method for diagnosing performance of a gas turbine, characterized in that it is converted into a value Y ₀ at a standard intake air temperature Tci ₀ and intake air pressure Pci ₀ by the calculation of Characteristic modeling means for modeling a range of operation data during a diagnosis period of the gas turbine as an input and modeling at least one of the performance indicators of the gas turbine as a function including at least an intake air temperature and an intake pressure as inputs.
Standardization means for converting the performance index into standardized data that is a value at a predetermined intake temperature and intake pressure, with at least a variable including the performance index, intake air temperature, and intake pressure as inputs;
Degradation or recovery of performance due to time-series decrease or increase in the standardized data output by inputting the value of the performance index included in a certain range of operation data during the diagnosis target period to the standardizing means A performance diagnostic system comprising a diagnostic means for determining
As means for generating the certain range of operation data input to the characteristic modeling means and the diagnosis means, at least power generation output, intake air temperature, and intake air from operation data at a plurality of time points during the diagnosis target period. A load factor is calculated by a function including pressure as an input, and is a base that is operation data in a load factor range in which the calculated load factor appears most frequently among a plurality of load factor ranges divided by a predetermined method. A gas turbine performance diagnosis system comprising base load operation data extraction means for extracting load data. 12. The base load operation data extraction means according to claim 11, wherein the relationship between the power generation output, the intake air temperature, and the intake air pressure is determined based on the original data that is operation data at a plurality of time points during the diagnosis target period. Function We = f_We (Tci, Pci) that includes pressure Pci as input and outputs power generation output We
Means to identify as,
Using the identified function f_We, a power generation output value We _calc corresponding to the intake air temperature Tci and the intake pressure Pci of the operation data in the diagnosis target period is calculated, and the ratio A = of the actually measured value We _{act to} the calculated value We _calc We _act / We _calc
As a load factor,
Alternatively, a value _obtained by dividing the value of each A at each time point in the diagnosis target period by the moving average value A _mov of a certain period including the time point B = A / A _mov
As a load factor,
Means for extracting data in which the value of A for the load factor, or further, if the B is calculated, the B value is within a predetermined range. Diagnostic system. Characteristic modeling means for modeling a range of operation data during a diagnosis period of the gas turbine as an input and modeling at least one of the performance indicators of the gas turbine as a function including at least an intake air temperature and an intake pressure as inputs.
Standardization means for converting the performance index into standardized data that is a value at a predetermined intake temperature and intake pressure, with at least a variable including the performance index, intake air temperature, and intake pressure as inputs;
Degradation or recovery of performance due to time-series decrease or increase in the standardized data output by inputting the value of the performance index included in a certain range of operation data during the diagnosis target period to the standardizing means A performance diagnostic system comprising a diagnostic means for determining
As a means for generating the certain range of operation data input to the characteristic modeling means and the diagnosis means, the relationship between the intake air temperature Tci and the exhaust gas temperature Tto at the maximum load factor in operation of the gas turbine is shown. Characteristic model Tto = f_Tex (Tci)
Using the functional relationship, the original data which is operation data of a plurality of time points during the diagnosis period, and inputs data of the intake air temperature Tci calculates the value Tto _calc exhaust gas temperature, calculated values of the exhaust temperature Tto _calc and its measured value _{Tto act} deviation ΔTto = Tto _act - Tto _calc
A system for diagnosing performance of a gas turbine, comprising means for extracting data within a predetermined range. 12. The characteristic modeling unit according to claim 11, wherein the performance modeling means determines the performance index Y from a predetermined standard operating condition value x _{i0 of} at least one operating condition x _i (i = 1, 2,..., N). An operation condition correction function f_opr (x _i ) that corrects the influence of deviation, and a reference value temporal decrease function f_dgr (t) that represents a decrease over time according to the accumulated operating time t or equivalent operating time t of the performance value at the standard condition value The operation condition correction function f_opr (x _i ) and the reference value temporal decrease function f_dgr (t) in the following characteristic model expression expressed as the sum of
Y = f_opr (x _i ) + f_dgr (t)
The standardization means refers to the following expression Y ₀ = Y−f_opr (x _i ) using the identified operation condition correction function f_opr (x _i ) as the value Y of the performance index.
A system for diagnosing performance of a gas turbine, characterized in that it is a means for converting to a value under standard conditions by calculating 12. The characteristic modeling means according to claim 11, wherein the characteristic modeling means calculates values of constants a ₁ , a ₂ , α, and Y ₀₀ of the following characteristic model expression indicating the relationship between the performance index Y, the intake air temperature Tci, and the intake pressure Pci. Means for determining based on a range of operating data;
_{Y = a 1 × (Tci-} Tci 0) + a 2 × (Pci-Pci 0) + α × t + Y 00
(Here, Tci _0, Pci ₀ is the intake air temperature at a predetermined standard air condition a predetermined value of the intake pressure, t is the cumulative operation time or the equivalent operating time during diagnosis period, a1, a ₂ Performance characteristics Model constant representing α, α is a constant coefficient representing degradation, and Y ₀₀ is a performance value at the beginning of the target diagnosis period at the standard intake air temperature and pressure in the previous period)
The standardization means is the following equation using the determined model constants a ₁ and a ₂ : Y ₀ = Y−a ₁ × (Tci−Tci ₀ ) −a ₂ × (Pci−Pci ₀ )
The system for diagnosing performance of a gas turbine, characterized in that the value Y of the performance index is converted into a value Y ₀ at a standard intake air temperature Tci ₀ and intake air pressure Pci ₀ . 14. The characteristic modeling means according to claim 13, wherein the performance index Y is obtained from a predetermined standard operating condition value x _{i0 of} at least one operating condition x _i (i = 1, 2,..., N). An operation condition correction function f_opr (x _i ) that corrects the influence of deviation, and a reference value temporal decrease function f_dgr (t) that represents a decrease over time according to the accumulated operating time t or equivalent operating time t of the performance value at the standard condition value The following characteristic model expression expressed as the sum of Y = f_opr (x _i ) + f_dgr (t)
In which the operating condition correction function f_opr (x _i ) and the reference value temporal decrease function f_dgr (t) are identified based on the certain range of operating data,
The standardization means refers to the following expression Y ₀ = Y−f_opr (x _i ) using the identified operation condition correction function f_opr (x _i ) as the value Y of the performance index.
A system for diagnosing performance of a gas turbine, characterized in that it is a means for converting to a value under standard conditions by calculating 14. The characteristic modeling means according to claim 13, wherein the characteristic modeling means calculates the values of constants a ₁ , a ₂ , α, and Y ₀₀ of the following characteristic model expression indicating the relationship between the performance index Y, the intake air temperature Tci, and the intake pressure Pci. Means for determining based on a range of operating data;
_{Y = a 1 × (Tci-} Tci 0) + a 2 × (Pci-Pci 0) + α × t + Y 00
(Here, Tci _0, Pci ₀ is the intake air temperature at a predetermined standard air condition a predetermined value of the intake pressure, t is the cumulative operation time or the equivalent operating time during diagnosis period, a1, a ₂ Performance characteristics Model constant representing α, α is a constant coefficient representing degradation, and Y ₀₀ is a performance value at the beginning of the target diagnosis period at the standard intake air temperature and pressure in the previous period)
The standardization means is the following equation using the determined model constants a ₁ and a ₂ : Y ₀ = Y−a ₁ × (Tci−Tci ₀ ) −a ₂ × (Pci−Pci ₀ )
The system for diagnosing performance of a gas turbine, characterized in that the value Y of the performance index is converted into a value Y ₀ at a standard intake air temperature Tci ₀ and intake air pressure Pci ₀ . Based on a range of operating data during the gas turbine diagnostic period, at least one of the performance indicators of the gas turbine is characteristically modeled as a function that includes at least the intake air temperature and the intake air pressure as inputs.
Input the operation data in the certain range to the characteristic model, predict the performance of the gas turbine according to the operating conditions, calculate the deviation between the predicted result of this performance and the actual measurement value, and change the deviation over time A gas turbine performance diagnostic method for judging deterioration from
As a certain range of operation data during the diagnosis target period, a load factor is calculated from a plurality of time operation data during the diagnosis target period by a function including at least a power generation output, an intake air temperature, and an intake pressure as inputs. Base load data that is operation data in the load factor range where the appearance ratio of the calculated load factor is the highest among a plurality of load factor ranges divided by the reference is extracted, and this is extracted as the operation data in the certain range. A method for diagnosing performance of a gas turbine, characterized in that: Characteristic modeling means for modeling a range of operation data during a diagnosis period of the gas turbine as an input and modeling at least one of the performance indicators of the gas turbine as a function including at least an intake air temperature and an intake pressure as inputs.
Input the operation data in the certain range to the characteristic model, predict the performance of the gas turbine according to the operating conditions, calculate the deviation between the predicted result of this performance and the actual measurement value, and change the deviation over time A gas turbine performance diagnostic system comprising a diagnostic means for determining deterioration from
As means for generating the certain range of operation data input to the characteristic modeling means and the diagnosis means, at least power generation output, intake air temperature, and intake air from operation data at a plurality of time points during the diagnosis target period. A load factor is calculated by a function that includes pressure as an input, and is a base that is operation data in a load factor range in which the calculated load factor appears most frequently among a plurality of load factor ranges divided according to a predetermined standard. A gas turbine performance diagnosis system comprising base load operation data extraction means for extracting load data. Based on a range of operating data during the gas turbine diagnostic period, at least one of the performance indicators of the gas turbine is characteristically modeled as a function that includes at least the intake air temperature and the intake air pressure as inputs.
Input the operation data in the certain range to the characteristic model, predict the performance of the gas turbine according to the operating conditions, calculate the deviation between the predicted result of this performance and the actual measurement value, and change the deviation over time A gas turbine performance diagnostic method for judging deterioration from
The range of operation data during the diagnosis target period includes an intake air temperature Tci at the maximum load factor in operation of the gas turbine, an exhaust gas temperature, a gas temperature at an intermediate stage of the turbine, or a combustion temperature management index for control. A characteristic model Tto = f_Tex (Tci) indicating the relationship with the upper limit value Tto
Using the function relationship, the original data which is operation data of a plurality time points during the diagnosis period, and inputs data of the intake air temperature Tci calculates the value Tto _calc exhaust temperature, and calculated value Tto _calc the exhaust temperature its measured value _{Tto act} deviation ΔTto = Tto _act - Tto _calc
Is a data turbine performance diagnostic method characterized in that the data is extracted from data within a predetermined range. Characteristic modeling means for modeling a range of operation data during a diagnosis period of the gas turbine as an input and modeling at least one of the performance indicators of the gas turbine as a function including at least an intake air temperature and an intake pressure as inputs.
Input the operation data in the certain range to the characteristic model, predict the performance of the gas turbine according to the operating conditions, calculate the deviation between the predicted result of this performance and the actual measurement value, and change the deviation over time A gas turbine performance diagnostic system comprising a diagnostic means for determining deterioration from
As means for generating the certain range of operation data input to the characteristic modeling means and the diagnosis means, the intake air temperature Tci at the maximum load factor in operation of the gas turbine, the exhaust gas temperature, or the intermediate of the turbine Characteristic model Tto = f_Tex (Tci) indicating the relationship with the gas temperature of the stage or the upper limit value Tto of the combustion temperature management index for control
Using the function relationship, the original data which is operation data of a plurality time points during the diagnosis period, and inputs data of the intake air temperature Tci calculates the value Tto _calc exhaust temperature, and calculated value Tto _calc the exhaust temperature its measured value _{Tto act} deviation ΔTto = Tto _act - Tto _calc
A system for diagnosing performance of a gas turbine, comprising means for extracting data within a predetermined range. A display screen provided in the gas turbine performance diagnosis system according to claim 11,
For the performance index, an original graph that displays a time series change of original data that is operation data at a plurality of time points during a diagnosis target period;
An object such as a button or a display menu that starts extraction of base load operation data from the original data by the base load operation data extraction means by clicking or selection on the screen;
An extraction graph that displays a time-series change of the extracted data that is the base load operation data extracted by the base load operation data extraction means;
Alternatively, in place of the original graph and the extracted graph, the original data and the extracted data can be distinguished from each other by changing the symbol or color of the plot so that the graph is superimposed on one graph, or the reference A display screen comprising a graph for displaying a time series change of the standardized data output from the conversion means.

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