JP2000039103A - Controller for electric power plant - Google Patents

Abstract

PROBLEM TO BE SOLVED: To appropriately make the automatic adjustment of dynamic feedforward control signals by taking the influence of mutual intervention into consideration, by calculating an overall evaluation index by calculating the characteristic amounts of the temperature values of steam measured at a plurality of spots along the flow passage of the steam, and changing a plurality of feedforward control signals based on the index. SOLUTION: A data converting function 410 receives the outlet temperature 201 of a primary superheater, temperature 202 of main steam, temperature 203 of reheated steam, and target values 511-513, and processes the received data for extracting each feature. Then an overall evaluation index generating function 425 composes a plurality of characteristic amounts extracted by means of a characteristic amount extracting function 420 into several evaluation indexes, by taking the interactions among the characteristic amounts into consideration. A boiler input amount command (BIR) correcting function 430 calculates a BIR correction factor, by computing the generated evaluation indexes as the antecedent section of a fuzzy rule 432 by means of a fuzzy inference function 431. Therefore, dynamic feedforward control signals can be adjusted appropriately by taking the influence of mutual interventions into consideration.

Description

DETAILED DESCRIPTION OF THE INVENTION

[0001]

The present invention relates to an operation control device for a thermal power plant. In particular, a steam generating means for exchanging the supply water by exchanging heat with a supply gas and a combustion gas generated by burning fuel, and a heat generating means for exchanging heat of the vapor evaporated by the steam generation means with the combustion gas to raise the temperature. When a load of a thermal power plant including an exchanger and a steam turbine driven by the steam changes, a predetermined process amount is controlled to a desired value by using a feedforward control signal corresponding to dynamic characteristics of the plant. The present invention relates to an operation control device for a thermal power plant.

The present invention does not depend on the type of fuel and can be applied to waste incineration power generation as long as the plant satisfies the above configuration.

[0003]

2. Description of the Related Art In the control of a thermal power plant, fluctuations in steam temperature are suppressed mainly by feedback control and feedforward control. In particular, a thermal power plant has a large response delay, and is a control method in which feedforward control is effective. However, a control parameter that determines a control signal in this control method is conventionally manually adjusted by a plant operator while observing a change in a control amount. When the load of the plant changes, a dynamic (transient) feedforward control signal is used to compensate for the non-linearity and the response time delay of the plant. For example, the control parameters for determining the dynamic feedforward control signal for the fuel flow rate are adjusted by the operator himself based on the knowledge and experience of the operator from observation results such as the main steam temperature.

As a method of adjusting the dynamic feedforward control signal, there are JP-A-6-222808 and JP-A-7-44205. These methods adjust a dynamic feedforward control signal based on a characteristic amount of a response waveform of a control amount of a plant.

[0005]

The characteristics of a thermal power plant are complicated, and the effect of changing one operation amount may affect another control amount. For example, if the main steam temperature is controlled mainly by controlling the fuel flow rate and the main steam pressure is controlled mainly by controlling the feedwater flow rate, each manipulated variable does not necessarily affect only the respective control target. Fuel flow rate also affects main steam pressure, and feedwater flow rate also affects main steam temperature.
That is, the process is often an interference system.

In this case, even if the change of the operation amount is determined independently, the desired control accuracy is often not obtained.
The prior art does not describe measures for this interference system.

An object of the present invention is to automatically adjust a dynamic feed-forward control signal appropriately for a plurality of dynamic feed-forward control signals serving as an interference system of a thermal power plant in consideration of the influence of mutual interference. An object of the present invention is to provide an operation control device for a thermal power plant including:

[0008]

According to the present invention, there is provided a means for calculating characteristic values for steam temperature measurement values at a plurality of locations measured by steam temperature measurement means provided at a plurality of locations in a steam flow path. A means for calculating one or a plurality of comprehensive evaluation indices from the characteristic amounts of the above, and a means for changing the plurality of feedforward control signals based on the comprehensive evaluation indices.

[0009]

Embodiments of the present invention will be described.

FIG. 2 shows the basic configuration of a thermal power plant 100 to be used. In the boiler 150, fuel and air are supplied to a burner and burned, and supply water circulated by a water supply pump 140 is evaporated. The overheated steam is guided to the high-pressure turbine 130 via the turbine control valve to drive the high-pressure turbine 130. The steam that has passed through the high-pressure turbine is heated again by the boiler and enters the low-pressure turbine 120. The rotation of the high and low pressure turbines causes the generator 110
To generate power.

Hereinafter, the steam at the inlet of the high-pressure turbine is referred to as main steam,
The steam at the low pressure turbine inlet is called reheat steam.

In the thermal power plant, in addition to the above components, there are also devices such as a condenser for cooling and condensing steam after driving the turbine and a combustion exhaust gas treatment device, but the description is omitted here. .

The operating state of the thermal power plant 100 is measured by a data measuring device such as a generator output measuring device 111, a main steam temperature measuring device 122, a main steam pressure measuring device 123, a reheat steam temperature measuring device 124, and the like. It is transmitted to control device 300. The operation control device 300 grasps the operation state of the plant based on these process data, and controls the fuel flow control valve 162, the air flow control valve 161, the turbine control valve 121, and the water supply pump 1 so that the plant is in a desired state.
40 are controlled.

In the present invention, the type of fuel such as oil or gas is not limited, but when coal is used as the fuel, the pulverizer for pulverizing the coal is controlled to adjust the fuel flow rate.

The structure of the boiler 150 will be described with reference to FIG.

In the boiler 150, a economizer 151, which is a heat exchanger for generating steam and raising the temperature of steam, a furnace water wall 15
2, evaporator 153, primary superheater 154, secondary superheater 15
The fifth, third superheater 156, fourth superheater 157, primary reheater 158, and secondary reheater 159 are arranged at the positions shown in FIG.

The primary reheater and the primary superheater are separated from each other by a partition, and a gas distribution damper 170 for adjusting the distribution ratio of the flow rate of the combustion gas flowing to each side is provided. The order of the flow of water or steam flowing through each heat exchanger is as shown in FIG.

Next, a control method of the thermal power plant 100 will be described with reference to FIG.

The operation control device 300 operates the fuel flow control valve 162, the water supply pump 140, the turbine control valve 121, and the like to satisfy the required load command, and operates the main steam temperature 202, the main steam pressure 204, the reheat The steam temperature 203 and the like are controlled. If these control amounts fluctuate significantly from the target values (set values) 512 to 514 when the load changes, equipment such as the turbine will be damaged. Therefore, it is necessary to minimize fluctuations in the control amounts. However, the thermal power plant has a large time constant of several minutes to several tens of minutes, and it is not easy to control the boiler output. In addition, the physical relationship between the operation amount and the control amount is complicated, and the occurrence of interference between control loops also causes difficulty in control.

The control system of the operation control device 300 includes an FBC (feedback control) controller that determines an operation amount based on PI (proportional / integral) calculators 537 to 540 of a control deviation, and an FFC (feedback control) based on a load command value. (Feed-forward control) controller. FFCs are roughly classified into static FFC controllers 531 to 533 and dynamic FFC controllers 534 to 536. Static FF
C determines the input amount (fuel flow rate, feed water flow rate, etc.) required to obtain the boiler output that matches the load command value 520. The dynamic FFC determines an input amount for correcting a fluid flow delay or a heat transfer delay.

Hereinafter, the boiler input amount command determined by the dynamic FFC is referred to as BIR (Boiler InputRegulation).

The necessity of BIR and the characteristics of the plant will be described.

For example, when the load is increased, the flow rate of water supplied to the boiler is increased in order to increase the flow rate of steam supplied to the turbine. At the same time, the fuel flow rate is increased in proportion to the increase in the feedwater flow rate. However, in the steam pipe located on the upstream side (the side of the economizer 151), the heat transfer speed due to fuel combustion is lower than the flow speed of the feedwater flow. In addition, the steam enthalpy drops transiently. On the other hand, in the steam pipe on the downstream side (the reheaters 158 and 159 side), the enthalpy does not decrease immediately after the feedwater flow rate increases, but rather the enthalpy of the steam increases due to an increase in the combustion gas temperature due to an increase in the fuel flow rate.

Therefore, when the fuel BIR and the gas distribution damper BIR are not provided (in the case of only the static FFC), the response of the steam temperature at the outlet of each heat exchanger at the time of increasing the load is not uniform depending on the load change condition. It shows a characteristic in which it rises and then falls, and settles to a target value after the end of the load change.

Therefore, in order to compensate for the transient decrease in steam enthalpy generated on the upstream side, it is necessary to transiently increase the fuel flow rate and increase the combustion gas temperature. The control signal for determining this transiently required fuel flow is the fuel BIR
It is.

The gas distribution damper 170 plays a role to keep the ratio of the amount of heat absorbed between the main steam side and the reheat steam side at an appropriate level.
It is. The gas distribution damper distributes the combustion gas from the reheater located downstream of the steam pipe to the evaporator located upstream of the steam pipe and the primary superheater 154 when the load is increased. Correct the enthalpy deviation between the two.
In order to correct this deviation, a control signal for determining the distribution ratio of the combustion gas flow rate is a gas distribution damper BIR.

FIG. 6 shows the relationship between the static FFC signal and the dynamic FFC signal (fuel BIR) for the fuel when the load increases.
When the load command changes on the ramp, the static FFC signal indicates an amount of fuel increase corresponding to the load change. On the other hand, the fuel BIR instructs an increase in the fuel according to the dynamic characteristics of the plant in a time zone after the load change starts and after the load change ends.

The control command for the final fuel flow rate is the sum of the static FFC signal and the fuel BIR.

In this embodiment, for the purpose of suppressing fluctuations in the main steam temperature and the reheat steam temperature, the BIRs (the fuel BIR and the gas distribution damper B, respectively) for controlling the fuel flow rate and the gas distribution damper are used.
BIR automatic adjustment device 40 for automatically adjusting the
0 is provided.

FIG. 1 shows a basic configuration of the present invention.

The thermal power plant is roughly divided into a plant body 100 composed of devices such as boilers and turbines, and an operation control device 300 for controlling them. Plant body 10
In order to control 0, it is necessary to first grasp the state of the plant.

For this purpose, various process data 210 such as steam temperature and steam pressure are stored in the process data measuring device 20.
It is measured using 0. Process data measurement device 20
0 sends the necessary information 220 of the measured data to the operation control device 300 and also stores the data in its own storage device.

The operation control device 300 grasps the state of the plant, and creates a control signal 310 of the component equipment of the plant in accordance with the operation condition such as a load change and the like.
Control 0.

The control system uses both feedback control and feedforward control.

The feedforward control includes a control (static feedforward control, hereinafter referred to as BID) signal based on a static characteristic corresponding to a change in the load of the plant and a dynamic signal for responding to a response time delay or non-linear characteristic of the plant. Control (Dynamic feedforward control: hereinafter referred to as BIR)
There is.

The BID signal is an amount determined by the static characteristics of the plant, and can be determined relatively easily. On the other hand, since the BIR signal is related to the dynamic characteristics of the plant and varies depending on load change conditions such as a load change rate and a load change width, it is difficult to appropriately determine the BIR signal.

Conventionally, since the coordinator or the operator adjusts the BIR signal by trial and error while monitoring the process data, the quality of the BIR signal depends on the knowledge and experience of the operator. Since the quality of the BIR signal greatly affects the main control amount of the plant, it is a very important control signal in consideration of the influence of damage to plant components and the like.

The present invention provides a method for automating and optimizing the adjustment of a BIR signal.

The operation control device 300 includes the plant control circuit 5
00 and a BIR automatic adjustment device 400 which is a feature of the present invention. An algorithm and control parameters for controlling the plant are programmed in the plant control circuit 500 (see FIG. 5).

An outline of the function of the BIR automatic adjustment device 400 will be described.

The process data required by the process data measuring device 200 (in this embodiment, the primary superheater outlet temperature 20
1, the main steam temperature 202, the reheat steam temperature 203) and the target values 511 to 513 corresponding to the respective process amounts programmed in advance from the target value calculation circuit 510. The data conversion function 410 processes the data to extract the characteristics of each process data.

Next, the feature value extraction function 420 extracts the feature value of each process data. The plurality of feature amounts extracted here are combined into several evaluation indices by the comprehensive index creation function 425 in consideration of their respective interactions.

In the BIR correction function 430, the evaluation index created by the comprehensive index creation function 425 is
As an antecedent part of 2, the fuzzy inference function 431 operates and B
Calculate the IR correction coefficient.

In the BIR signal update function 433, the current B
A new BIR signal is generated by multiplying the IR signal by the BIR correction coefficient calculated by the BIR correction function 430.

The BIR signal update value is stored in the plant control circuit 50.
It is sent to 0 and becomes the BIR for the next operation.

At the same time, the BIR signal update value is
The result is output to the display screen so that the operator can confirm the change result. At this time, whether to replace the BIR generation circuit of the plant control circuit 500 with the updated value may be determined by the operator's judgment.

Next, the function of the BIR automatic adjustment device 400 will be specifically described.

The data conversion function 410 receives time-series data of the primary superheater outlet temperature 201, the main steam temperature 202, and the reheat steam temperature 203, and sets the respective target values 511-5.
13 is calculated for each time.

In the feature value extraction function 420, the feature value of each data is obtained from the deviation value calculated for each time. Features are
The time zone during the load change (τ _{0 to} τ ₁ ), the time zone from the end of the load change to the steam temperature setting (τ _{1 to} τ ₂ ), and the entire time zone (load change start to steam temperature setting: τ ₀ to) τ ₂ ) (see FIG. 7).

In the present embodiment, the characteristic amount is a time average value of the deviation in each time zone.

Here, τ ₀ is the load change start time,
τ ₁ and τ ₂ are defined by the following equations as functions of the load change time τ _MWD .

[0052]

Τ ₁ = τ ₀ + k ₁ × τ _MWD (1)

[0053]

Τ ₂ = τ ₀ + k ₂ × τ _MWD (2) where k ₁ and k ₂ are constants.

In this embodiment, k ₁ and k ₂ are constants, but the response characteristic of the steam temperature varies not only with the load change time τ _MWD but also with the load change rate, the load change width, the load band, and the like. , K ₁ and k ₂ may be defined as these functions.

In the comprehensive index creation function 425, the fuel BIR
And an overall evaluation index serving as an adjustment index for the gas distribution damper BIR.

In this example, the fuel BIR and the gas distribution damper B
It is intended to suppress fluctuations in the main steam temperature and the reheat steam temperature with the IR as an adjustment target.

Varying the fuel flow rate, ie, the fuel BIR, affects both the temperature of the main steam and the temperature of the reheated steam that are raised by heat exchange with the combustion gas. Further, when the gas distribution damper opening degree, that is, the gas distribution damper BIR is changed, the gas flow distribution between the primary reheater and the primary superheater changes, so that the reheat steam temperature changes. At the same time, the steam temperature at the outlet of the primary superheater also changes, which eventually affects the main steam temperature.

That is, for example, if the fuel BIR is increased by detecting that the main steam temperature has dropped, the effect extends not only to the main steam temperature but also to the reheat steam temperature.
It is conceivable that the reheat steam temperature also increases.

Therefore, in the present invention, an index for comprehensively evaluating three types of process data of the main steam temperature, the reheat steam temperature, and the primary superheater outlet temperature is created, and thereby the BIR is obtained.
Can be adjusted in consideration of the influence of mutual interference.

In this example, the comprehensive evaluation index is calculated for adjusting the fuel BIR and the gas distribution damper. next,
An example of a comprehensive evaluation index for fuel BIR adjustment will be described.

The feature amount is calculated in the three time zones (τ ₀ to
τ _1, τ ₁ ~τ _2, corresponding to τ ₀ ~τ ₂₎ Equation (3) -
Defined in (5).

[0062]

(Equation 3)

[0063]

(Equation 4)

[0064]

(Equation 5)

Here, (T _MST , T _MSF , T _MSB ),
(T _HST , T _HSF , T _HSB ), (T _RST , T _RSF , T _RSB ) are the characteristic values of the main steam temperature, the primary superheater outlet steam temperature, and the reheat steam temperature. It is an average value. In addition, the maximum value of the deviation and the time until the maximum deviation occurs may be adopted as the feature amount.

The fuel BIR affects not only the main steam temperature but also the reheat steam temperature. The upstream steam temperature also affects the main steam temperature and the reheat steam temperature with a time delay. In order to take this upstream temperature into consideration in advance, the characteristic amount is calculated from the three steam temperature deviation amounts obtained by adding the primary superheater outlet temperature. A _{1 to} a ₃ , b _{1 to} b ₃ in formulas (3) to (5)
c _{1 to} c ₃ and d _{1 to} d ₃ are coefficients (constants) for adjusting the degree of influence of each steam temperature deviation on the average value.

Further, while the main steam temperature and the reheat steam temperature are controlled variables to be strictly controlled to target values as turbine inputs, the primary superheater outlet steam temperature has a larger allowable range of temperature fluctuation. large. Α _{1 to} α ₃ in the equations (3) to (5)
Is a bias term for the target value of the primary superheater outlet steam temperature.

In this example, the deviation amount of the primary superheater outlet temperature is added in order to consider the influence on the upstream side. However, the secondary superheater is not provided until the high-pressure steam turbine 130 as shown in FIG. There are also a 155, a third superheater 156, and a fourth superheater 157, and the steam temperature deviation in these superheaters may be added.

Although the bias terms (α _{1 to} α ₃ ) are used only for the primary superheater outlet steam temperature, the bias terms are similarly added to the main steam temperature and the reheat steam temperature. Is also good.

The overall evaluation index for adjusting the gas distribution damper BIR can be calculated in the same manner as in the equations (3) to (5).

Next, the function of the BIR correction function 430 will be specifically described. In the BIR correction function 430, based on the comprehensive evaluation index calculated by the comprehensive index creation function 425,
Modify the BIR signal waveform.

Although the BIR signal waveform is not necessarily a perfect square as shown in FIG. 7, basically, the time τ _aff , τ from the start of the input of the BIR signal until the BIR change rate (gradient) becomes relatively gentle. _apd (hereinafter referred to as a BIR rise time), times τ _bff and τ _bpd until the absolute value of the BIR signal begins to decrease to zero (hereinafter referred to as a BIR extraction time), and a total amount S _{ff of the} BIR signal. S _pd (the area of the BIR waveform) is an important factor.

Correction coefficients for these three parameters are obtained by fuzzy inference to correct the BIR signal. For example, the change of the parameter related to the fuel BIR can be performed by using equations (6) to
(8). Here, C _τaff , C _τbff , C
_Sff is the BIR startup time, BIR extraction time,
Correction coefficients obtained by fuzzy inference for the area of the BIR waveform, and τ ′ _aff , τ ′ _bff , and S ′ _ff are values after correction of each parameter.

[0074]

Τ ′ _aff = C _τaff × τ _aff (6)

[0075]

Τ ′ _bff = C _τbff × τ _bff (7)

[0076]

S ′ _ff = C _Sff × S _ff (8) The gas distribution damper BIR can be similarly modified.

Next, a method of obtaining a parameter correction coefficient by fuzzy inference will be described.

FIG. 8 shows a membership function for fuel BIR adjustment with respect to the antecedent part (overall evaluation index) and the consequent part (parameter correction coefficient) of the fuzzy inference. FIG. 9 shows an inference rule table. NB (negatively large), ZE (suitability: zero), PB
Fuzzy variables of (positively large), SM (decrease), ME (do not change), and BG (increase) are assigned.

In the case of adjusting the fuel BIR, as shown in FIG. 8, the horizontal axis of the membership function of the evaluation index is
Comprehensive evaluation indices T _inT , T _inF , obtained by equations (3) to (5)
T _inB . T _inT, T inF, with respect to the value of T _inB, each of the degree of influence (0-1) is obtained from the membership function of the evaluation index.

On the other hand, in the membership function of the correction coefficient, the horizontal axis represents the parameter correction coefficients C _Sff , C _τaff , and C _τbff , and the vertical axis represents the degree of influence.

The degree of influence on T _inT , T _inF , and T _inB of the _antecedent part is determined for each fuzzy rule number shown in FIG. 9, and the minimum degree of influence is determined among them. For the fuzzy variables (SM, ME, BG) indicated in the consequent at that time, the area from the base of the membership function triangle to the value of the minimum influence degree of the antecedent and the position of the center of gravity are calculated. This is calculated for all rule numbers, and the position of the center of gravity obtained by superimposing all areas is set as the value of the correction coefficient. The correction coefficient for the gas distribution damper BIR can be calculated in a similar manner.

The fuzzy inference of this example uses the method of Mamdani, and the defuzzification uses the composite centroid method, but the present invention is not limited to this method.

The use of fuzzy inference is not an essential condition, and the relationship between the comprehensive evaluation index and the parameter correction coefficient may be converted into a function or a table in advance.

The specific method of correcting the BIR waveform is defined as fuel BIR
This will be described with reference to FIG. First, from the BIR waveform ABCD before correction, the BIR rise time and the BIR extraction time are corrected by equations (6) and (7) to obtain a waveform AB "CD". Next, the corrected area is calculated by the equation (8), and a waveform AB'C'D "equal to the corrected area is obtained.

As described above, even in the interference system that controls the main steam temperature and the reheat steam temperature by using the fuel BIR and the gas distribution damper BIR as the operation amounts, a plurality of process data reflecting the influence of both operation amounts is obtained. Since the BIR signal is corrected by comprehensively evaluating the extracted feature amounts, appropriate adjustment can be performed in consideration of the influence of mutual interference.

Further, according to the present invention, the BIR signal can be appropriately adjusted without depending on the experience of the operator. In addition, the adjustment period can be shortened.

Although the embodiment of the present invention has been described by taking a thermal power plant as an example, the present invention is also applicable to a waste power plant that incinerates waste as fuel.

[0088]

According to the present invention, even in an interference system that controls the main steam temperature and the reheat steam temperature using the fuel BIR and the gas distribution damper BIR as operation amounts, a plurality of systems reflecting the influence of both operation amounts can be used. Since the BIR signal is corrected by comprehensively evaluating the feature values extracted from the process data, it is possible to perform appropriate adjustment in consideration of the influence of the mutual interference.

Therefore, it is possible to control the control variables such as the main steam temperature and the reheat steam temperature with a small deviation from the target value.

[Brief description of the drawings]

FIG. 1 is a diagram showing a basic functional configuration of the present invention.

FIG. 2 is a diagram illustrating a configuration example of a thermal power plant.

FIG. 3 is a diagram illustrating an example of an arrangement of heat exchangers in a boiler of a thermal power plant.

FIG. 4 is a diagram showing an example of the flow of steam and the order of heat exchangers in a thermal power plant.

FIG. 5 is a diagram illustrating a basic system example of a control circuit of a thermal power plant.

FIG. 6 is a diagram illustrating an example of a control signal of a thermal power plant.

FIG. 7 is a view for explaining a feature value of a steam temperature and a BIR signal parameter in the embodiment of the present invention.

FIG. 8 is a diagram showing a membership function in fuzzy inference in the embodiment of the present invention.

FIG. 9 is a diagram illustrating an example of a fuel BIR adjustment fuzzy rule in the embodiment of the present invention.

FIG. 10 is a view for explaining a method of correcting a BIR signal in the embodiment of the present invention.

[Explanation of symbols]

100: thermal power plant, 200: process data measuring device, 201: primary superheater outlet steam temperature data, 20
2: Main steam temperature data, 203: Reheat steam temperature data,
210: various process data, 300: operation control device,
310 ... control signal, 400 ... BIR automatic adjustment device, 41
0: Data conversion function, 420: Feature extraction function, 430
... BIR correction function, 431 ... Fuzzy inference function, 432
... Fuzzy rules, 433 ... BIR signal update function, 50
0: Plant control circuit, 510: Target value calculation circuit

──────────────────────────────────────────────────の Continued on the front page (51) Int.Cl. ⁷ Identification symbol FI Theme coat ゛ (Reference) G05B 13/02 G05B 13/02 N (72) Inventor Masahide Nomura 7-1-1, Omika-cho, Hitachi City, Ibaraki Prefecture No. Hitachi, Ltd.Hitachi Research Laboratories (72) Inventor Yoshio Sato 7-1-1, Omikacho, Hitachi City, Ibaraki Prefecture Within Hitachi Research Laboratories Hitachi Research Laboratory (72) Inventor Toru Kimura Omikamachi, Hitachi City, Ibaraki Prefecture (2-1) Inventor Satoru Shimizu 5-2-1 Omika-cho, Hitachi City, Ibaraki Pref. Hitachi, Ltd. Omika Plant (72) Inventor Eiji Toyama Chiyoda, Tokyo 4-6, Kanda Surugadai, Ward Hitachi, Ltd. F-term (reference) 3L021 AA01 CA06 DA05 EA01 FA12 5H004 GA16 GB04 HA01 HA16 HB01 H B03 JA22 JB08 KA71 KB02 KB04 KB33 KC05 KD03 KD25 LA15 LA18

Claims (10)

[Claims] 1. A steam generating means for exchanging heat between a supply gas and a combustion gas generated by burning fuel to evaporate the supply water, and heat-exchanging the vapor evaporated by the vapor generation means with the combustion gas to raise the temperature. An operation control device of a power plant including a heat exchanger to be heated and a steam turbine driven by the steam,
An operation control device that controls a predetermined process amount to a desired value by using a feedforward control signal according to a dynamic characteristic of the plant when a load of the plant changes, wherein measurement is performed at a plurality of locations in a flow path of the generated steam. Means for calculating a characteristic amount for the measured value of the steam temperature, means for calculating an overall evaluation index from two or more of the characteristic amounts, and a plurality of feedforward controls based on the overall evaluation index. And a means for changing a signal. 2. A steam generating means for exchanging heat between a supply gas and a combustion gas generated by burning fuel to evaporate the supply water, and heat-exchanging the vapor evaporated by the steam generation means with the combustion gas to raise the temperature. An operation control device of a power plant including a heat exchanger to be heated and a steam turbine driven by the steam,
An operation control device that controls a predetermined process amount to a desired value by using a feedforward control signal according to a dynamic characteristic of the plant when a load of the plant changes, wherein measurement is performed at a plurality of locations in a flow path of the generated steam. Means for calculating a characteristic amount for the measured value of the steam temperature, means for calculating an overall evaluation index from two or more of the characteristic amounts, and a plurality of feedforward controls based on the overall evaluation index. An operation control device for a power plant, comprising: means for calculating a change value of a signal; and means for displaying a change value of the feedforward control signal. 3. A steam generating means for exchanging heat with a supply gas and a combustion gas generated by burning fuel to evaporate the supply water, and heat-exchanging the vapor evaporated by the steam generation means with the combustion gas to raise the temperature. A superheater for heating, a first steam turbine driven by the superheated steam, a reheater for exchanging heat of the steam whose temperature has been reduced by driving the steam turbine with the combustion gas and raising the temperature again, A second steam turbine driven by the steam after passing through the reheater, fuel supply means to the steam generation means, and a flow rate of the combustion gas in contact with at least one of the superheater and the reheater. An operation control device of a power plant, comprising: a combustion gas flow rate adjusting means for changing a combustion gas flow rate control means for controlling a predetermined process amount to a desired value using a feedforward control signal according to dynamic characteristics of the plant when a load changes. Operation control device Means for calculating a feature quantity of each steam temperature from the steam temperature at the inlet or outlet of the superheater and the reheater and the steam temperature at the inlet of the first and second steam turbines; Means for calculating a comprehensive evaluation index from at least two characteristic amounts; and means for changing the feedforward control signal for at least one of the fuel supply means and the combustion gas flow rate adjusting means based on the comprehensive evaluation index. An operation control device for a power plant. 4. A steam generating means for exchanging heat with a supply water by exchanging heat with a combustion gas generated by burning fuel, and a heat exchange between the vapor evaporated by the steam generation means and the combustion gas to ascend. A superheater for heating, a first steam turbine driven by the superheated steam, a reheater for exchanging heat of the steam whose temperature has been reduced by driving the steam turbine with the combustion gas and raising the temperature again, A second steam turbine driven by steam after passing through a reheater, a fuel supply unit to the steam generation unit, and a flow rate of the combustion gas in contact with at least one of the superheater and the reheater. An operation control device for a power plant including a combustion gas flow rate adjusting means for controlling a predetermined process amount to a desired value using a feedforward control signal according to dynamic characteristics of the plant when a load changes. Operation control equipment Means for calculating a feature quantity of each steam temperature from the steam temperature at the inlet or outlet of the superheater and the reheater and the steam temperature at the inlet of the first and second steam turbines; Means for calculating a comprehensive evaluation index from the two feature amounts; means for calculating the feedforward control signal for at least one of the fuel supply means and the combustion gas flow rate adjusting means based on the comprehensive evaluation index; And a means for displaying a result. 5. The operation control device for a power plant according to claim 3, wherein the time zone mainly includes a time zone from the start to the end of the load change, and the time zone mainly after the end of the load change. A plant operation control device comprising the characteristic amount calculating means for calculating the characteristic amount of the steam temperature separately for a time zone including a large amount of steam temperature. 6. The operation control device for a power plant according to claim 5, wherein, as the characteristic amount of the steam temperature, a value obtained by averaging at least a deviation amount from a target value of the steam temperature for each time period is calculated. Operation control device for power plant. 7. The operation control device for a power plant according to claim 3, wherein the fuel supply means and the combustion gas flow rate adjustment means are based on the characteristic amount of the steam temperature. An operation control device for a power plant, wherein a change rate or a change amount of a control signal for either one of them is calculated by fuzzy inference. 8. The operation control device for a power plant according to claim 3, wherein the characteristic value of the steam temperature is a maximum value or a minimum value of a deviation amount of a steam temperature from a target value. An operation control device for a power plant, wherein at least one of the occurrence times of the maximum deviation is calculated. 9. A steam generating means for evaporating supply water by heat-exchanging a combustion gas generated by burning fuel with supply water, and a heat exchange between the vapor evaporated by the steam generation means and the combustion gas for ascending. An operation control device of a power plant including a heat exchanger to be heated and a steam turbine driven by the steam,
An operation control device that controls a predetermined process amount to a desired value by using a feedforward control signal according to a dynamic characteristic of the plant when a load of the plant changes, wherein measurement is performed at a plurality of locations in a flow path of the generated steam. An operation control device for a power plant, comprising: means for calculating a characteristic value for the measured value of the steam temperature thus obtained; and means for changing a plurality of the feedforward control signals based on the characteristic value. 10. A plurality of combinations of operation amounts and control amounts, wherein said operation amounts control an interfering process which affects a control amount other than the control amount, and a feedforward operation in accordance with dynamic characteristics of said process. In a plant operation control device using a control signal, means for measuring a plurality of process quantities of the plant, means for calculating a plurality of feature quantities from process data measured by the measurement means, two of the feature quantities Means for calculating a comprehensive evaluation index from the above characteristic amounts, further comprising means for calculating change values of the plurality of feedforward control signals based on the comprehensive evaluation index and displaying the change values of the feedforward control signals An operation control device for a plant, comprising at least one of the following means: