JP2014234767A - Cogeneration facility operation support device - Google Patents

Abstract

PROBLEM TO BE SOLVED: To provide an operation schedule calculation device which can optimize a power transmission amount or a steam supply amount with respect to required electric energy and a required amount of steam in a gas turbine and steam generation equipment in a power generation facility.SOLUTION: An operation support device, for a gas turbine facility which generates electric power by injecting water or steam into a combustion section and a cogeneration facility which supplies a steam utilization facility with steam generated by an exhaust heat recovery boiler using combustion exhaust gas of the combustion section, comprises: setting means which sets a required amount of steam as a first element and a required steam temperature/required steam pressure as a second element; first calculation means which calculates one of either the first element or the second element with the other element as a reference; first back calculation means which compares a set value and a calculated value of the other element, obtains a value of the one element from a deviation through back calculation and executes repeated calculations until a difference between a back calculation value and the set value of the one element becomes not more than an allowable value; and control means which controls the gas turbine facility with the back calculation value of the one element, confirmed to be not more than the allowable value by the first back calculation means, as a required steam condition.

Description

  The present invention relates to an operation support apparatus for a power generation facility such as a gas turbine and a steam generation facility or a cogeneration power generation facility equipped with a steam generation facility. TECHNICAL FIELD The present invention relates to an operation support device for a cogeneration power generation facility that determines an operation schedule that can secure a sufficient amount of air supply steam.

  In a cogeneration power generation facility in which a gas turbine and a steam generation facility are configured as one cogeneration power generation unit, electric power and steam are generated as a result of operation, and the generated power and steam are used at a use destination such as an industrial facility. For this reason, the generation amount of cogeneration power generation facilities is determined by the amount of use (the amount of power used and the amount of steam used) at the use site of industrial facilities, etc., and is individually required depending on the difference in use location and purpose of use. There are operations that focus on electric power and operations that focus on the amount of steam, and there are cases where switching is used at an appropriate timing.

  For example, Patent Document 1 is known as a cogeneration power generation facility in which a gas turbine and a steam generation facility are configured as one cogeneration power generation unit.

JP 2004-190558 A

  In response to these requirements, only one or two operators are operating the cogeneration power generation facilities. Therefore, operating in accordance with the requirements is a heavy burden on the operator, and the power plant can operate optimally. Therefore, it is not in a situation where high efficiency operation is possible.

  As described above, the cogeneration power generation facility is required to secure the optimum amount of generated power or generated steam, and it is essential to secure the required amount. Although it is necessary to perform an operation commensurate with the amount of steam, it has been difficult to optimally operate the amount of generated power and the amount of generated steam in order to satisfy the required power amount and the required steam amount.

  From the above, in the present invention, in a power generation facility having a power generation facility such as a gas turbine and a steam generation facility, an optimal transmission power amount or an optimal air supply steam amount is set according to the user's demand for power amount and steam amount. An operation schedule calculation device for determining a schedule that can be secured is provided.

  In order to solve the above-mentioned problems, the present invention comprises a gas turbine equipment that injects water and steam into a combustion section and rotationally drives a generator, and an exhaust heat recovery boiler that generates steam using combustion exhaust gas of the gas turbine equipment. An operation support device for a cogeneration power generation facility that supplies steam generated in an exhaust heat recovery boiler to a steam utilization facility, with a required steam flow rate as a first factor as a required steam condition from the steam utilization facility, and a required steam Setting means for setting the temperature / required steam pressure as the second element, and calculating the other element of the first element and the second element based on one element of the first element and the second element The first calculation means and the set value of the other element are compared with the calculated value, and when the two are different, the value of one element is obtained by back calculation from the deviation, and the back calculated value of one element and the set value Repeat until the difference is below the tolerance. Control the gas turbine equipment using the first back calculation means for executing the return operation and the back calculation value of one element that is confirmed to be less than or equal to the allowable value by the first back calculation means as the required steam condition from the steam utilization equipment. It is characterized by being comprised by the control means to do.

  Operation to determine the optimal transmission power amount or schedule for ensuring the optimal air supply steam amount in the power generation facility having a power generation facility such as a gas turbine and a steam generation facility, in response to the user's demand for electric energy and steam amount A schedule calculation device is provided.

The figure which shows the whole structure of a cogeneration power generation equipment operation assistance apparatus. The figure which shows the connection relationship of a cogeneration power generation equipment and a driving assistance device. The figure explaining a schedule calculation input setting function. The figure explaining a schedule calculation input setting function. The figure explaining the relationship of steam temperature / steam pressure / steam flow rate. The figure which showed the example of a signal when calculating a steam flow rate from the setting temperature / setting pressure of required steam. The figure which shows the process of calculating | requiring a vapor | steam temperature and a vapor | steam pressure from the vapor | steam flow volume of FIG. The figure which showed the example of a signal when calculating steam temperature / setting pressure from the setting flow volume of required steam. The figure which shows the process of calculating | requiring a steam flow rate by reverse calculation from the steam temperature / pressure of FIG. The figure which shows the steam / water injection flow rate calculation process at the time of steam / water injection automatic switching. The figure which shows the time change of each part flow volume when a request | required steam flow rate is smaller than a rated steam flow rate. The figure which shows the time change of each part flow volume when a request | required steam flow rate is larger than a rated steam flow rate.

  Hereinafter, embodiments of the present invention will be described in detail with reference to the drawings.

  First, a cogeneration power generation facility to which the driving support device of the present invention is applied will be clarified with reference to FIG. FIG. 2 shows a connection relationship between the cogeneration power generation facility and the driving support device.

  2 includes a gas turbine facility GT, an exhaust heat recovery boiler B, and a steam utilization facility 201. In the cogeneration power generation facility CP, electric power is generated in the gas turbine facility GT, and steam is generated in the exhaust heat recovery boiler B by effectively using the amount of heat held by the combustion exhaust gas in the gas turbine facility GT. Further, the steam generated in the exhaust heat recovery boiler B is used in the steam utilization facility 201.

  For this reason, the purpose of control in the cogeneration power generation facility CP is to control either the amount of power or the amount of steam, or both to the optimum amount. The operation end of each part of the cogeneration power generation facility CP is operated by an operation signal from the cogeneration power generation control device CT, and an optimal control command is sent from the cogeneration power generation facility operation support device SC to the cogeneration power generation control device CT. Hereinafter, the configuration of each part in FIG. 2 will be described in more detail.

  First, the gas turbine equipment GT in the cogeneration power generation equipment CP will be described. The gas turbine equipment GT is rotated by an air compressor COMP that compresses air A, a combustor COMB that performs combustion using compressed air and fuel F, a gas turbine T that is driven by high-pressure combustion gas, and a gas turbine T. A generator G to be driven is provided.

  Moreover, since the combustion exhaust gas after working with the gas turbine GT in the cogeneration power generation plant CP is at high temperature and high pressure, in order to recover this retained energy, the exhaust heat that heats the feed water W with the gas turbine combustion exhaust gas to obtain steam A recovery boiler B is provided.

  Further, the cogeneration power generation equipment CP has a fuel control valve VF for controlling the amount of fuel F supplied to the combustor COMB, exhaust heat as various operation ends for controlling the output electric power and steam to desired values. A supply water control valve VW for controlling the supply amount of the supply water W supplied to the recovery boiler B, an air control valve VA for controlling the air amount for the combustor CNMB, and the like are provided in the air compressor COMP.

  Moreover, in the gas turbine equipment GT, since the temperature of the combustion gas given to the gas turbine T is directly connected to the control of the mechanical power, water or steam is injected. As an operation end for this purpose, The water injection valve VWSP and the steam injection valve VSSP are provided. Water for injection uses the feed water W, and steam for injection uses steam generated in the exhaust heat recovery boiler B. In this case, using water or steam for injection is an operation that affects the output of the cogeneration power generation facility CP (the amount of electricity and the amount of steam), so how much water or steam is used at that time? It is determined in consideration of the control purpose and operating state.

  The cogeneration power generation facility CP is configured as described above, but when it is a large output facility, it is configured by a plurality of (multiple shafts) gas turbine facilities GT. An exhaust heat recovery boiler B is provided for each of a plurality of gas turbines (multiple shafts), or an exhaust heat recovery boiler B is provided in common. In FIG. 2 and the following description, a single-axis facility is assumed, but this can be similarly applied to a multi-axis facility.

  In the cogeneration power generation facility CP configured as described above, the operation end of each unit is driven by a control signal from the power generation control device CT. The power generation control device CT receives the control command from the cogeneration power generation facility operation support device SC and controls the power generation facility. Specific operation ends of the power generation control device CT are the fuel control valve VF, the water supply control valve VW, the air control valve VA, the water injection valve VWSP, the steam injection valve VSSP, and the like described above.

  The operation end of each part of the cogeneration power generation equipment CP is appropriately controlled by a signal from the power generation control device CT. To decide. Here, the optimum control command given by the cogeneration power generation facility operation support device SC is the required power from a power supply command device (not shown) or the steam required by the user such as the steam utilization facility 201 connected to the cogeneration power generation facility CP. It is a schedule signal such as target output and target output arrival time for each axis in which the amount is distributed to a plurality of axes. The schedule signal is, for example, information including the generated power or generated steam amount for each hour in 24 hours tomorrow, and is necessary for generating the planned power and scheduled steam amount for tomorrow's scheduled time as a whole of the cogeneration power generation facility CP. The output of each axis is defined. In the following description, controlling the amount of steam as an output will be described.

  In response to the optimum control command (schedule signal) given by the cogeneration power generation facility operation support device SC, the power generation control device CT that has received the calculation calculates a schedule such as the time of arrival of the gas turbine T of each axis and the target load arrival time. To do. In the example of the optimal control command (schedule signal) in which the output 10 is required as a whole of the cogeneration power generation facility CP at 8 o'clock tomorrow and the first axis bears 3, the power generation control device CT is 7 A schedule is established for the first shaft that sometimes starts the gas turbine T, performs an insertion into the power system of the gas turbine T at 7:10, and bears an output 3 before 8: 5. Further, the power generation control device CT controls the start time, the fuel control valve VF, the water supply control valve VW, and the air control valve VA according to the schedule, and the cogeneration power generation equipment CP is operated to obtain an output.

  Alternatively, in the case of a stop process, a stop schedule is passed from the cogeneration power generation facility operation support device SC to the cogeneration power generation facility CP. The cogeneration power generation equipment CP determines the stop start time according to the schedule calculation result received by each axis, and calculates the schedule such as the stop start time and the disconnection time of the gas turbine GT. In addition, what part of the cogeneration power generation facility operation support device SC and the power generation control device CT is to be shared by the schedule calculation may be determined as appropriate. Here is just one example.

  The cogeneration power generation control device CT receives the schedule calculation result obtained by the cogeneration power generation facility operation support device SC in this way, and the cogeneration power generation facility CP performs the operation according to the schedule calculation result by the received signal.

  In FIG. 2, the functions in the cogeneration power generation facility operation support device SC can be divided into a schedule calculation input setting function 3 and a schedule calculation execution function 4. The following example shows that the operator performs various settings using the schedule calculation input setting function 3, and the schedule calculation execution function 4 sequentially executes necessary calculations according to the given settings. The part of the schedule calculation input setting function 3 can be automatically set instead of the operator. In the schedule calculation execution function 4, when necessary calculations are executed according to the given settings, steam conditions (temperature / pressure / flow rate) in the steam utilization facility 201 are taken in and sequentially referred to.

  FIG. 1 is a diagram illustrating an overall configuration of a cogeneration power generation facility operation support apparatus according to an embodiment of the present invention. In this figure, the part of the schedule calculation execution function 4 represents program processing using a computer, and displays each processing content as processing steps. The schedule calculation input setting function 3 is composed of an input circuit and a display circuit. In this figure, instructions such as instructions and set values given by the operator are displayed and output according to the order of processing, and a schedule is displayed. The processing steps involved in the calculation execution function 4 are shown in association with each other. Since details of the schedule calculation input setting function 3 are shown in FIGS. 3 and 4, the following description will be made while sequentially comparing them.

  In the process of the cogeneration power generation facility operation support device SC, the steam condition (temperature / pressure / flow rate) in the steam utilization facility 201 is referred to. The reason for the reference is that the steam utilization facility 201 of the cogeneration power generation facility CP has a requirement for the steam condition that meets the demand because the steam condition varies depending on the demand of the product or the like of the user. In addition, when referring to the steam conditions (temperature / pressure / flow rate), it can be roughly divided into two processing methods. Therefore, in the processing steps of the schedule calculation execution function 4 shown in FIG. 1, the processing steps S102, S105, S107, S111, S113 are performed. Both the first processing method S41 by and the second processing method S42 by processing steps S101, S104, S106, S110, and S112 are prepared.

  The proper use of the two processing methods is selected according to a request from the customer side of the steam utilization facility 201 or the system. For example, if the demand for the steam condition is to preferentially secure the steam flow rate, the first processing method S41 is adopted if fluctuations in the steam temperature and steam pressure are recognized accordingly. On the contrary, the demand for the steam condition is to preferentially secure the steam temperature and the steam pressure, and the second processing method S42 is adopted if fluctuations in the steam flow rate are recognized accordingly.

  Specific examples of the proper use of the two processing methods are as follows. In the case of manufacturing a product, for example, it is essential to make a production plan in an oil refinery facility or the like. In this case, it is necessary to consider the material price, the purchaseable quantity for each material type, the manufactured product price, the product demand, and the product manufacturing capacity.

  Of these, the product production capacity refers to the machine equipment capacity and steam production capacity of the cogeneration facility, and it is essential to increase the product production capacity to meet the product demand. In such facilities, a primary product is manufactured from purchased materials and the like, and a final product is obtained through a manufacturing process. Of these manufacturing processes, it is important to secure the required steam flow rate in the process of producing materials used for products (primary products before the target product). On the other hand, in the manufacturing stage from the primary product to the final product, it is necessary to use the required steam pressure and temperature as a reference.

  Depending on the circumstances on the steam utilization equipment 201 side, there are cases where it is only necessary to ensure the required steam flow rate, or there are cases where only the required steam pressure and temperature are ensured. Alternatively, it may be necessary to switch between them as needed.

  In the required steam condition setting unit 301 of the schedule calculation input setting function 3 in FIG. 1, the required steam flow (process step S101), required steam temperature and required steam pressure (process) are processed as required steam condition inputs for the processing steps S101 and S102. Step S102) is given.

  The required steam condition setting unit 301 of the schedule calculation input setting function 3 shown in FIG. 3 uses an input means (not shown) such as a mouse, a keyboard, or a touch panel to request the required steam flow rate (t / h) 304 or the required steam. The values of temperature (° C.) 302 and required steam pressure (kPa) 303 are actually input. Each request amount input here receives the steam conditions required from the steam utilization facility 201 and sets the steam conditions generated by the cogeneration power generation facility.

  Here, the required steam flow rate 304 is given to the processing step S101 of the second processing method S42, and the required steam temperature 302 and the required steam pressure 303 are given to the processing step S102 of the first processing method S41. In the processing of the second processing method S42 described below, the values of the required steam temperature 302 and the required steam pressure 303 are referenced and used, and in the processing of the first processing method S41, the values of the required steam flow rate 304 are referenced and used. There is a relationship.

  FIG. 5 shows a general relationship between the steam flow rate, the steam temperature, and the steam pressure in the fluid. The horizontal axis indicates the steam flow rate, the vertical axis indicates the steam pressure, and the steam temperature is displayed as a variable. The fact that the required steam flow rate is preferentially determined in the processing step S102 means that the vertical line L1 in FIG. 5 is selected, and the combination of the steam temperature and the steam pressure necessary to obtain a predetermined output in a state where the steam flow rate is constant. Means to decide. On the contrary, the fact that the required steam temperature and the required steam pressure are preferentially determined in the processing step S101 means that the horizontal line L2 in FIG. 5 is selected, and it is necessary to obtain a predetermined output with the steam temperature and the steam pressure constant. Means to determine the proper steam flow rate.

  According to the characteristic example of FIG. 5, the characteristics of steam temperatures of X ° C., Y ° C., and Z ° C. (X> Y> Z) are displayed, and it can be seen that the steam conditions differ depending on the temperature. For example, when the steam flow rate is constant, the steam pressure tends to increase as the temperature rises. In addition, in order to respond appropriately to the required steam conditions because each other is affected by changes in steam temperature / pressure / flow rate so that the steam pressure will drop if the steam flow rate increases even if the steam temperature is constant. Therefore, it is important to finely adjust each steam condition.

  In the processing step S105 of FIG. 1, the combination of the steam temperature and the steam pressure is determined with the given steam flow rate constant with reference to the characteristics of FIG. Moreover, in process step S104 of FIG. 1, with reference to the characteristic of FIG. 5, a steam flow rate is determined in the state of the given steam temperature and steam pressure. However, the process of process step S105 and process step S104 is started by the push button PB5 operation by the operator from the schedule calculation start instruction unit 307 of the schedule calculation input setting function 3 shown in FIG. Needless to say, the operation of the push button PB5 by the operator is performed after the required steam condition is set by the operator.

  The push button PB5 instructs to start the schedule calculation, and for example, the steam condition setting process in each time section of 24 hours tomorrow is sequentially executed. The series of processes in FIG. 1 shows a process of a certain time section, and after this setting, the steam condition setting process in the next time section is advanced and executed by operating the push button PB5 each time. However, in the following description, only a process in a certain time section will be described unless otherwise required. In many cases, the time section has a time width of one hour.

  Subsequent operations will be described separately for the first processing method S41 and the second processing method S42. First, the second processing method (temperature / pressure priority setting method) S42 will be described. Here, it is determined whether or not the generated steam flow rate (calculated in the steam flow rate calculation step S104) calculated from the set input required steam temperature / required steam pressure is equivalent to the required steam flow rate (input in the required steam condition input S102). (Comparison judgment step S106 of the set required steam flow rate and the calculated steam flow rate).

  As a result of the comparison in the comparison determination step S106, when the compared steam flow rates are equal (yes), the steam flow rate obtained from the required steam temperature / pressure becomes the required steam flow rate, so that it is determined as required. In this case, the steam flow rate obtained from the required steam temperature / pressure is adopted as the calculation result of the cogeneration power generation facility operation support device SC. That is, this calculated value becomes a control signal for the cogeneration power generation control device CT, and the cogeneration power generation facility CP is operated according to the schedule of the cogeneration power generation facility operation support device SC.

  On the other hand, if it is determined that the compared steam flow rates are different in the determination in the comparison determination step S106 (No), the steam temperature / pressure reverse calculation step S110 by changing the deviation value, the reverse calculation temperature / pressure, and the required steam temperature / pressure are set. The process proceeds to iterative calculation processing in the allowance confirmation step S112.

  Prior to the repeated calculation processing of steps S110 and S112, in the steam injection steam condition setting unit 306 of the cogeneration power generation facility schedule calculation input setting function 3 shown in FIG. The generated steam flow rate (t / h) 324 calculated by calculation, the flow rate difference (t / h) 325 between the required steam flow rates, and the flow rate deviation ratio (%) 326 are displayed so that the operator can visually recognize them. This value is also provided to the steam temperature / pressure reverse calculation step S110 by changing the deviation value.

  In the steam temperature / pressure reverse calculation step S110 by changing the deviation value, any one of the flow rate difference (t / h) 325 and the flow rate deviation rate (%) 326 between the generated steam flow rate (t / h) 324 and the required steam flow rate obtained by calculation is calculated. Are used to determine the corresponding steam temperature / steam pressure by the steam temperature / pressure reverse calculation process by changing the deviation value.

  In the next step process, the back-calculated temperature / pressure and the required steam temperature / pressure allowance confirmation step S112, the steam temperature / steam pressure obtained by the back-calculation and the value input in the required steam condition S101 (required steam temperature / required steam pressure). Compare and judge. And when it is considered that it is unacceptable, it is judged that use is inadequate unlike the required steam temperature / pressure. When it is determined that the use is insufficient (unacceptable), the process proceeds to the steam temperature / pressure reverse calculation step S110 by changing the deviation value. In the process at this time, the deviation values (the generated steam flow rate (t / h) 324 calculated by calculation, the flow rate difference (t / h) 325 between the required steam flow rate 325, and the flow rate deviation ratio (%) 326) are changed appropriately. The steam temperature / steam pressure is recalculated, and the determination step S112 is repeated again until it becomes acceptable. Specifically, for example, when there is a flow rate difference of 10% in the initial display state in the steam condition setting unit 306 for GT injection, and the result of obtaining the steam temperature / steam pressure by back calculation is unacceptable, Assuming a flow rate difference of 8%, the steam temperature / steam pressure is obtained by back calculation and judged again. Repeat this until it is acceptable.

  If it is determined in the allowance confirmation step S112 that the steam temperature / steam pressure obtained by back calculation and the value input in the requested steam condition S101 are acceptable, the condition of the requested steam temperature / pressure is determined.

  The series of processes in the second processing method S42 is performed under the same concept in the first processing method S41. Next, the first processing method S41 will be described. Here, the steam temperature / pressure obtained from the set input required steam flow rate (calculation in the steam temperature / pressure calculation processing step S105) is equal to the input required steam temperature / required steam pressure (required steam condition input S101). It is determined whether or not there is (comparative determination step S107 of required steam temperature / required steam pressure and calculated steam temperature / steam pressure).

  As a result of the comparison in the comparison judgment step S107, when the compared steam temperature / steam pressure is equivalent (yes), the steam temperature / steam pressure determined from the required steam flow rate becomes the required steam temperature / required steam pressure. Judged as street. In this case, the steam temperature / steam pressure obtained from the required steam flow rate is adopted as the calculation result of the cogeneration power generation facility operation support device SC. That is, this calculated value becomes a control signal for the cogeneration power generation control device CT, and the cogeneration power generation facility CP is operated according to the schedule of the cogeneration power generation facility operation support device SC.

  On the other hand, if it is determined that the compared steam temperature / steam pressure is different (No) in the comparison determination step S107, the steam flow reverse calculation step S111 by changing the deviation value, and the reverse calculation flow rate and the required steam flow allowance confirmation step The process proceeds to the iterative calculation process in S113.

  Prior to the repeated calculation processing of steps S111 and S113, the steam injection steam condition setting unit 306 of the cogeneration power generation facility schedule calculation input setting function 3 shown in FIG. Calculated temperature (° C.) 327, Difference in required steam temperature (° C.) 328, Temperature deviation (%) 329, Calculated steam pressure (kPa) 330, Required difference in steam pressure (kPa) 331, Pressure deviation (%) 332 Is displayed and is visible to the operator. This value is also provided to the steam flow reverse calculation step S111 by changing the deviation value.

  In the steam flow reverse calculation step S111 by changing the deviation value, one of the steam temperature calculation value (° C.) 327, the required steam temperature difference (° C.) 328, the temperature deviation (%) 329, and the steam pressure calculation value (kPa) 330, Using either the required steam pressure difference (kPa) 331 or the pressure deviation (%) 332, the corresponding steam flow rate is obtained by a steam flow reverse calculation process by changing the deviation value.

  In the reverse calculation flow rate and the required steam flow allowance confirmation step S113, which is the next stage process, the steam flow obtained by the reverse calculation and the value (requested steam flow rate) input in the required steam flow rate S102 are compared and determined. And when it is judged that it is unacceptable, it is determined that the required steam flow rate is insufficient and the use is insufficient. When it is determined that the use is insufficient (unacceptable), the process proceeds to the steam flow reverse calculation step S111 by changing the deviation value. In the processing at this time, the deviation values (required steam temperature difference (° C.) 328, temperature deviation (%) 329, requested steam pressure difference (kPa) 331, pressure deviation (%) 332) are changed appropriately. The steam flow is recalculated again and the determination step S113 is repeated again until it becomes acceptable. Specifically, for example, when there is a 10% temperature / pressure difference in the initial display state in the steam condition setting unit 306 for GT injection, and the result of obtaining the steam flow rate by back calculation is unacceptable, Assuming a temperature / pressure difference of 8%, the vapor flow rate is calculated by reverse calculation and judged again. Repeat this until it is acceptable.

  If it is determined in the allowance confirmation step S113 that the steam flow obtained by back calculation and the value input in the requested steam condition S102 are acceptable, the condition of the requested steam flow is confirmed.

  In the first process S41 and the second process S42 described above, the repetition process of steps S111 and S113 or the repetition process of steps S110 and S112 selects whether to calculate the difference as an absolute value or as a% value. can do. As a result, the calculated value approaches the target value as a result of the repeated operation, but either the absolute value or the% value may satisfy the condition first, and in this case, it is not repeated until both are satisfied. This is because the subsequent calculation can be performed on the converged side.

  For this reason, with respect to the permissible confirmation steps S112 and S113, the values of the steam temperature / pressure / flow rate used in the subsequent calculations are absolute values from the GT injection steam condition allowable value change setting unit 308 of the schedule calculation input setting function 3. You can specify whether to do with% or with% value. The example of FIG. 3 shows an example in which PB11 is selected from the push buttons PB10 and PB11 for the flow rate, and the% value 316 is selected instead of the absolute value 315. Similarly, select PB12 out of push buttons PB12, PB13 for temperature, select absolute value 317 instead of% value 318, select PB15 out of push buttons PB14, PB15 for pressure, and not absolute value 319, The example which selected% value 320 is shown.

  As a result of the calculation in the above processing method, the determined deviation values are obtained in the processing steps S112 and S113, respectively. At this time, the operator confirms the confirmed value displayed on the GT injection steam condition setting unit 306 of the schedule calculation input setting function 3 in FIG. 3 and the deviation allowable permission push button PB4 of the GT injection steam condition setting unit 306. push. As a result, the conditions of the AND circuits AND1 and AND2 in FIG. 1 are established, and the final value is officially registered in the allowable value change processing step S117. Thereafter, the final value is used as an authorized value.

  In response to the results of the required steam temperature / pressure permissible confirmation processing step S112 and the required steam flow permissible confirmation processing step S113, in the required steam flow / required steam temperature / required steam pressure determination step S114, the schedule of the cogeneration power plant CP It is determined whether the operation is performed according to the required steam flow rate or the required steam flow rate. For this processing, either the temperature pressure priority selection push button PB7 or the flow rate priority selection push button PB8 is selected and pressed by the operator from the GT injection steam selection unit 322 of the schedule calculation input setting function 3 in FIG. Is done. Thereby, the steam conditions used in the steam utilization facility 201 are determined, and the steam supplied to the steam utilization facility 201 is controlled.

  In the schedule recalculation processing step S118 in FIG. 1, the operation state of each time section for 24 hours tomorrow under the corrected steam condition is recalculated. For this process, the schedule calculation recalculation push button PB6 is pressed by the operator from the schedule calculation recalculation processing unit 321 of the schedule calculation input setting function 3 in FIG.

  Next, in selection process step S103, the mode of injection control in the combustor of the gas turbine is determined. In the cogeneration power generation facility, water or steam injection control is performed on the combustor of the gas turbine for the purpose of increasing the power generation output and reducing NOx. Here, automatic switching between steam injection / water injection / steam / water injection is selected as the injection mode of the gas turbine combustor. For this processing, from the GT injection method priority selection unit 305 of the schedule calculation input setting function 3 in FIG. 4, the operator selects the water injection selection push button PB1, the steam injection selection push button PB2, and the water / steam injection selection push button PB3. Is selected and pressed.

  The subsequent processing differs depending on whether steam injection / water injection / automatic switching of steam / water injection is selected as the injection mode of the gas turbine combustor. First, when water injection is selected, since the feed water W is taken from outside the cogeneration power generation facility CP, the change as the cogeneration power generation facility CP does not occur. From this, the operation method in the cogeneration power generation facility operation support device SC is determined from the schedule calculation result for performing water injection in the selection processing step S103.

  On the other hand, when either steam injection / steam / water injection automatic switching is selected, the subsequent processing is assigned in the determination processing step S115. First, when steam injection is selected, a schedule calculation for steam injection is calculated and operated under the steam condition determined in step S114 for determining the required steam flow rate / required steam temperature / required steam pressure.

  In the case where the steam / water injection automatic switching is performed in the determination processing step S115, the steam / water injection flow calculation step S116 at the time of the steam / water injection automatic switching is considered in consideration of the amount of steam that can be used as the cogeneration power generation facility. Transition to the operation mode in which injection is used together. Further, when the entire amount of steam becomes unusable, the operation mode is switched completely from steam injection to water injection. The process in the steam / water injection flow rate calculation step S116 will be described later with reference to FIG.

  Finally, in the schedule result determination processing step S119, in response to the operator pressing the schedule calculation result determination push button PB9 in the schedule calculation result determination unit 323 of the schedule calculation input setting function 3 in FIG. At the end, the result is confirmed and an optimum control command is sent to the cogeneration power generation control device CT.

3 and 4 are diagrams for explaining the cogeneration power generation facility schedule calculation input setting function 3. FIG. Although this operation is as described with reference to FIG. 1, it is as follows when it demonstrates collectively.
The required steam condition setting unit 301 for GT injection sets the steam condition that is received from the steam utilization facility 201 and is generated by the cogeneration power generation facility. Specifically, the steam temperature 302, the steam pressure 303, and the steam flow rate 304 are numerically input and set as the required steam condition values. Thereafter, the schedule calculation start unit 307 starts the schedule calculation. Actually, the schedule calculation start push button PB5 is selected.

  The steam condition setting unit 306 for GT injection calculates the steam flow rate corresponding to the set steam temperature / steam pressure and displays it on the screen when the requested steam condition is essential as the steam condition to be obtained. The steam flow rate 324 obtained from the required steam temperature / pressure for confirming whether there is a deviation from the required steam flow rate, the flow rate difference 325 of the steam flow obtained from the required steam temperature / pressure with respect to the required steam flow rate, the request A flow rate deviation 326 of the steam flow rate obtained from the steam temperature / pressure with respect to the required steam flow rate is obtained.

  Further, in the GT condition for steam condition setting unit 306, when the steam flow is indispensable as the required steam condition as the required steam condition, the steam temperature / pressure corresponding to the set steam flow is calculated and displayed on the screen. The steam temperature 327 obtained from the required steam flow rate for confirming whether the steam temperature / pressure has a deviation from the required steam temperature / pressure, the temperature difference 328 of the steam temperature obtained from the required steam flow rate with respect to the requested steam temperature, the request A temperature deviation 329 of the steam temperature obtained from the steam flow rate with respect to the required steam temperature is obtained. Similarly, regarding the pressure, a steam pressure 330 obtained from the required steam flow rate, a temperature difference 331 of the steam pressure obtained from the required steam flow rate with respect to the required steam pressure, and a pressure deviation 332 of the steam pressure obtained from the required steam flow rate with respect to the required steam pressure, respectively. Ask.

  Select the allowance allowance push button PB4 when judging whether or not to allow a deviation or the like for the calculation results 324 to 326 relating to the flow rate obtained above, the calculation results 327 to 329 relating to the temperature, and the calculation results 330 to 332 relating to the pressure. To do.

  In the GT injection steam condition permissible value change setting unit 308, when permission is not permitted, the steam flow rate change change item selection push button PB10 is selected by clicking the steam flow rate difference when the flow rate is mainly adjusted to match the required steam flow rate. Then, the flow rate difference setting value is input to the steam flow rate difference setting field 315. When the flow rate deviation is mainly performed, the steam flow deviation change item selection push button PB11 is selected by clicking, and the flow rate deviation set value is input to the steam flow deviation setting field 316.

  Similarly, when the temperature difference is mainly performed, the steam temperature difference change item selection push button PB 12 is selected by clicking, and the temperature difference setting value in FIG. 1 is input to the temperature difference setting field 317. When the temperature deviation is mainly performed, the steam temperature deviation change item selection push button PB13 is selected by clicking, and the temperature deviation setting value is input to the steam temperature deviation setting field 318. In the case of pressure, the steam pressure difference change item selection push button PB14 is selected by clicking, and the pressure difference set value is input to the pressure difference setting field 319. When the pressure deviation is mainly performed, the steam pressure deviation change item selection push button PB15 is selected by clicking, and the pressure deviation setting value is input to the steam pressure deviation setting field 320.

  In FIG. 4, the schedule calculation recalculation unit 321 performs processing in order to recalculate with the input changed data. In practice, the schedule calculation recalculation GT injection steam condition setting unit 306 selects the push button PB6.

  The GT injection method selection unit 305 selects the GT injection method. Actually, when performing only water injection, the water injection push button PB1, when performing only steam injection, the steam injection push button PB2, when using both steam injection and water injection, the steam / water injection automatic switching push button PB3 is provided. select. When selecting the steam condition for GT injection, if the steam temperature / pressure needs to match the required steam condition, the temperature / pressure priority push button PB7, and if the steam flow rate needs to match the required steam condition, the flow priority push button PB8. Select. The schedule calculation result determination 323 is used as the determination of the schedule calculation result. Specifically, the schedule calculation result confirmation push button PB9 is selected.

  Next, a specific calculation example by the processing of FIG. 1 will be described with reference to the drawings. Here, the calculation example in the case of the second processing method S42 in FIG. 1 will be described with reference to FIGS. 6 and 7, and the calculation example in the case of the first processing method S41 in FIG. This will be described with reference to FIG.

  First, FIG. 6 is a diagram showing an example of a signal when the steam flow rate is calculated from the set temperature / set pressure of the required steam. Here, the required steam condition input (set steam temperature ST1T and set steam pressure ST1P) set for the processing step S101 by the required steam condition setting unit 301 of the schedule calculation input setting function 3 is shown in the upper part of the figure. In FIG. 1, the setting input is described for every predetermined time section of 24 hours on a certain day. However, in FIG. 6, the input is set in time series as the input of 24 hours.

  Since the cogeneration power plant CP often starts and stops every day, the example of FIG. 6 shows the set steam temperature ST1T and the set steam pressure ST1P in each time zone when starting from time T2 and stopping at time T22. ing. This operation is divided into an early morning start-up process, a daytime normal operation process, and a nighttime stop operation process. In the start-up operation process, the set steam temperature ST1T and the set steam pressure ST1P tend to increase. In the stop operation process, the set steam temperature ST1T and the set steam pressure ST1P tend to decrease.

  In the lower part of the figure, the time-series change of the steam flow rate obtained in the steam flow rate calculation processing step S104 from the set steam condition is displayed with the size ST1F and the ratio ST1FB. Here, the magnitude ST1F obtained by calculation and the required steam flow rate 304 (dotted line) initially set are shown in comparison. Further, the ratio ST1FB between the calculated steam flow rate ST1F and the initially set required steam flow rate 304 (dotted line) is shown in comparison with the allowable deviation value ST1FBX.

  According to this example, during the period from time T3 to time T21, the generated steam flow rate ST1F exceeds the initially set required steam flow rate 304 (dotted line). From this, it can be said that the cogeneration power generation facility CP is in a state where a sufficient steam flow rate can be secured for use with the steam utilization facility 201 and the steam injection, but there is a possibility that it is larger than necessary. Further, regarding the ratio ST1FB, the allowable deviation value ST1FBX is exceeded in the period from time T18 to time T21. This means that, during this period, more steam than necessary is generated in proportion, and it is better to operate within the allowable range.

  The vapor flow rate at the lower part of FIG. 6 obtained by calculation is provided to the operator by a monitor or the like (not shown), and the operator sees the display result and allows the deviation allowable permission push button PB4 and deviation type selection push button of FIG. (PB10 to PB15) are being operated.

  FIG. 7 shows a process for obtaining a more appropriate steam temperature and steam pressure by inverse calculation from the steam flow rate obtained by the calculation of FIG. In the upper part of FIG. 7, the flow rate obtained by the calculation shown in the lower part of FIG. 6 is shown as a flow rate difference and a flow rate deviation ratio (%). However, the flow rate in the upper part of FIG. 7 is displayed as a deviation amount instead of an absolute value. Further, here, it is proposed that the flow rate difference obtained first is indicated by a solid line, and the flow rate difference change value indicated by a dotted line is corrected to be operated. That is, the flow rate difference should be operated lower than the initial setting during the period from time T3 to time T18, and the flow rate difference should be operated higher than the initial setting during the period from time T18 to time T21. Similarly, the flow rate deviation rate (%) indicates that the flow rate deviation rate should be operated higher than the allowable deviation value ST1FX in the period from time T18 to time T21.

  The lower part of FIG. 7 shows the temperature / pressure obtained by reverse calculation under the changed flow rate difference condition. This figure shows the desired signal waveform finally obtained, and it can be seen that it is improved when compared with the set temperature / pressure signal waveform in the upper part of FIG.

  FIG. 8 is a diagram showing a signal example when calculating the steam temperature / pressure from the set flow rate of the required steam. Here, the required steam condition input (set steam flow rate ST2F) set for the processing step S102 by the required steam condition setting unit 301 of the schedule calculation input setting function 3 is shown in the upper part of the figure. In FIG. 1, the setting input is described for each predetermined time section of 24 hours on a certain day. However, in FIG. 8, the input is set in time series as the input of 24 hours.

  Since the cogeneration power generation equipment CP often starts and stops every day, the example of FIG. 8 shows the set steam flow rate ST2F in each time zone when starting from time T2 and stopping at time T22. This operation is divided into an early morning start-up process, a daytime normal operation process, and a nighttime stop operation process. The set steam flow rate is rapidly increased during the start-up operation process, and is almost constant during the normal operation process. In the process, the set steam flow rate ST2F tends to decrease.

  In the lower part of the figure, the time-series changes in the steam temperature / pressure obtained in the set steam flow rate calculation processing step S105 are displayed with magnitudes ST2T and ST2P and ratios ST2TB and ST2PB. Here, the magnitudes ST2T and ST2P obtained by calculation are compared with the initially set required steam temperature 302 and pressure 303 (dotted line). Further, the ratios ST2TB and ST2PB of the steam temperature / pressures ST2T and ST2P obtained by calculation and the initially set required steam temperature 302 and pressure 303 (dotted line) are shown in comparison with the allowable deviation values ST2TBX and ST2PBX.

  According to this example, in the normal operation period from time T6 to time T18, the magnitude ST2T of the generated steam temperature exceeds the initially set required steam temperature 302 (dotted line). Further, during the operation period from time T3 to time T18, the generated steam pressure ST2P exceeds the initially set required steam pressure 303 (dotted line). From this, it can be said that the cogeneration power generation equipment CP is in a state in which sufficient steam temperature and pressure for use with the steam utilization equipment 201 and steam injection can be secured, but it may be larger than necessary.

  Further, regarding the ratios ST2TB and ST2PB, the temperature deviation ratio ST2TB exceeds the allowable deviation value ST2TBX during a part of the normal operation, and the pressure deviation ratio ST2PB exceeds the allowable deviation value ST2PBX in the starting operation process.

  The steam temperature / pressure in the lower part of FIG. 8 obtained by the calculation is provided to the operator by a monitor (not shown), etc., and the operator selects the deviation allowance push button PB4 in FIG. The push buttons (PB10 to PB15) are operated.

  FIG. 9 shows a process for obtaining a more appropriate steam flow rate by inverse calculation from the steam temperature pressure obtained by the calculation of FIG. In the upper part of FIG. 9, the temperature / pressure obtained by the calculation shown in the lower part of FIG. 8 is shown as temperature difference / pressure difference, temperature deviation ratio / pressure deviation ratio (%). However, the illustration of the temperature / pressure in the upper part of FIG. 9 is displayed not as an absolute value but as a deviation amount. In addition, here, it is proposed that the temperature difference / pressure difference obtained first is indicated by a solid line, and the temperature difference / pressure difference change value indicated by a dotted line should be corrected to be operated.

  In other words, the temperature is operated with the temperature difference lower than the initial setting during the period from the time T3 to the time T18, and the temperature difference is operated higher than the initial setting during the period from the time T18 to the time T21. Yes. Similarly, the temperature deviation ratio (%) indicates that the temperature deviation ratio should be operated higher than the allowable deviation value ST2TBX in the period from time T18 to time T21.

  Similarly, it is indicated that the pressure difference should be operated lower than the initial setting during the period from time T3 to time T18, and that the pressure difference should be operated higher than the initial setting during the period from time T18 to time T21. ing. Similarly, the pressure deviation ratio (%) indicates that the pressure deviation ratio should be increased from the allowable deviation value ST2FBX during the period from time T18 to time T21.

  The lower part of FIG. 9 shows the flow rate obtained by reverse calculation under the changed temperature difference / pressure difference condition. This figure shows the desired signal waveform finally obtained, and it can be seen that it is improved when compared with the signal waveform of the set flow rate in the upper part of FIG.

  Through the processing described above, the steam condition in each time section of 24 hours is corrected and determined, and the operation amount of each operation end of the cogeneration power generation facility CP necessary to achieve this steam condition can be determined. In order to achieve the steam conditions, the amounts of the feed water W, air A, and fuel F may be optimally controlled.

  FIG. 10 is a diagram illustrating a detailed flow of the steam / water injection flow rate calculation processing step S116 at the time of automatic switching of steam / water injection. Here, the steam / water injection is performed from the viewpoint of controlling the power generation amount of the cogeneration power generation facility CP. Although steam injection is performed in this control, since the steam to be injected uses a part of the steam generated in the exhaust heat recovery boiler B, the amount of steam sent to the steam utilization facility 201 is affected accordingly. As a result, the relationship between the required steam flow required by the steam utilization facility 201 and the steam flow required for the cogeneration power generation facility CP (necessary steam flow) needs to be adjusted appropriately.

  For this reason, in the process of process step S116 of FIG. 10, the injection method is selected by the process in the selection step S103 of steam injection / water injection / steam / water injection automatic switching as the premise. In this selection, any one of steam injection, water injection, and automatic steam / water injection switching is selected. In the process step S116, the process at the time of automatic switching of the steam / water injection is emphasized, and the process in the case of the steam injection and the water injection will be briefly described.

  As will be described in detail below, first, when water injection is selected by the processing in the selection step S103 of steam injection / water injection / steam / water injection automatic switching, the water injection is performed in the steam / water injection flow rate calculation processing step S116. In step S803, the schedule calculation is performed with the pattern of operating the cogeneration power generation facility. For example, the water injection amount for the output determined from the viewpoint of power generation output control, which is the purpose of water injection, is determined in advance as a pattern for driving, and the water injection amount for the required output at that time is calculated and determined according to the pattern . Note that the operation pattern may be proportional to the output, or limited in the small output range or the large output range.

  When the steam injection and the steam / water injection automatic switching are selected in the selection step S103 of the steam injection / water injection / steam / water injection automatic switching, the optimum steam flow / required steam temperature / pressure is further determined in the determination step S114. Recalculate steam flow or temperature / pressure. These values are obtained from the steam conditions obtained by correction in the process of FIG. Of these, in the case of steam injection, schedule calculation is performed in step S805 in a pattern in which the cogeneration power generation facility is operated by steam injection based on the steam condition determined in the steam required steam temperature / pressure determination step S114. In this case as well, the configuration can be the same as in the case of water injection. For example, the water injection amount for the output determined from the viewpoint of power generation output control, which is the purpose of water injection, is determined in advance as a pattern for driving, and the water injection amount for the required output at that time is calculated and determined according to the pattern .

  When steam / water injection automatic switching is selected, it is basically preferable to adopt steam injection and shift to combined use with water injection when it becomes difficult to cope with steam injection. This is based on the idea of avoiding as much as possible water injection, which has a large output fluctuation range but remains problematic in terms of stress on the metal. Therefore, in the comparison judgment step S801 between the required steam flow rate and the rated steam flow rate, the required steam flow rate is compared with the rated steam flow rate of the cogeneration power generation facility. Here, the required steam flow rate is a steam flow rate required by the steam utilization facility 201, and is a flow rate for each time zone determined by correction by the calculation in FIG.

  If the required steam flow rate is larger than the rated steam flow rate by this comparison (yes side of comparison judgment step S801), it is necessary to send the entire amount of steam generated in the exhaust heat recovery boiler B to the steam utilization equipment 201, and steam is injected. The flow rate cannot be secured. For this reason, it is essential to cover the flow rate exceeding the rated steam flow rate with water injection. In this case, the process proceeds to the processing step S803 of the water injection schedule described above. Note that when the required steam flow rate is smaller than the rated steam flow rate, the flow rate for steam injection can be ensured. Therefore, the flow rate exceeding the rated steam flow rate is handled by steam injection.

  FIG. 12 is a diagram showing the change over time in the flow rate of each part when the required steam flow rate is larger than the rated steam flow rate. The upper part of FIG. 12 shows the required steam flow rate DS2F in each time zone of 24 hours on a certain day, and the required steam flow rate DS2F becomes the rated steam flow rate of the cogeneration power generation equipment CP between time T3 and time T18. Yes. Therefore, during this period, it is necessary to send the total amount of steam generated by the cogeneration power generation facility CP to the steam utilization facility 201.

  On the other hand, the required injection amount NS2F determined from the viewpoint of power generation amount control is required between time T3 and time T18 regardless of the above circumstances. For this reason, when the injection control is performed with steam, the total amount (necessary steam NS2F) determined from the viewpoint of the required steam flow rate DS2F from the steam utilization facility 201 and the power generation amount control of the cogeneration power generation facility CP. Flow rate) Need to cover TS2F. This state is described as the required steam flow rate TS2F in the third stage of FIG. 12, but such a state that exceeds the rated steam flow rate is essentially unrealizable.

  Therefore, in the steam / water injection flow rate calculation processing step S116, water injection is selected. As shown in the second stage from the bottom of FIG. 12, the steam injection amount JS2F is set to zero, and the required injection amount NS2F is provided as the required water injection amount JW2F by water injection.

  Further, in the comparison judgment step S802 of the present invention, when the required steam flow rate is smaller than the rated steam flow rate (No side of the comparison judgment step S801), water injection is also required under the situation where such steam injection is performed. Judging to be. Here, it is confirmed that the required steam flow rate is smaller than the rated steam flow rate. In this case, the schedule calculation is scheduled in the implementation step S804 in a pattern in which the cogeneration power generation facility is operated by the combined use of water injection and steam injection. Based on these schedule calculation results, the schedule calculation result is determined in step S120.

  FIG. 11 is a diagram showing the change over time in the flow of each part when the required steam flow rate is smaller than the rated steam flow rate. The upper part of FIG. 11 shows the required steam flow rate DS1F in each time zone of 24 hours on a certain day, and the required steam flow rate DS1F is less than the rated steam flow rate of the cogeneration power generation equipment CP in all time zones. Accordingly, during this period, it is possible to send the total amount of steam generated by the cogeneration power generation facility CP to the steam utilization facility 201.

  On the other hand, the required injection amount NS1F determined from the viewpoint of power generation amount control is required between time T5 and time T17 regardless of the above circumstances. In addition, the total required amount of steam NS1F (required steam flow rate) TS1F determined from the viewpoint of the required steam flow rate DS1F from the steam utilization facility 201 and the power generation amount control of the cogeneration power generation facility CP is the rated steam flow rate of the cogeneration power generation facility CP. That's it. This state is described as the required steam flow rate TS1F in the third stage of FIG. 11, but such a state exceeding the rated steam flow rate is essentially unrealizable.

  From this, in processing step S802, combined use of steam injection and water injection is selected and executed. As shown in the first and second stages from the bottom of FIG. 11, the injection using the required steam injection amount JS1F and the required water injection amount JW1F is performed. In this case, it is preferable that the sum of the required steam injection amount JS1F and the required steam flow rate DS1F corresponds to the rated steam flow rate of the cogeneration power generation equipment CP, and the shortage is set as the required water injection amount JW1F.

S101: Required steam condition (temperature, pressure) input step S102: Required steam condition (flow rate) input step S103: Selection of steam injection / water injection / steam / water injection automatic switching step S104: Steam flow rate calculation step S105: Steam temperature / Pressure calculation step S106: Comparison determination step of required steam flow rate and calculated steam flow step S107: Comparison determination step of required steam temperature / pressure and calculated steam temperature / pressure Step S110: Steam temperature / pressure reverse calculation step S111 by changing deviation value S111 : Steam flow reverse calculation step by deviation value step S112: Reverse calculation temperature / pressure and required steam temperature / pressure allowable confirmation step S113: Reverse calculation flow rate and required steam flow allowable confirmation step S114: Determination of required steam flow or required steam temperature / pressure Step S115: Comparison between steam injection and automatic switching of steam / water injection Step S116: Steam / water injection flow rate calculation at the time of automatic switching of steam / water injection Step S117: Schedule calculation result determination step SC: Cogeneration power generation facility operation support device CT: Cogeneration power generation control device CP: Cogeneration power generation facility W: Feed water F: Fuel A: Air VW: Feed water flow rate adjustment valve VF: Fuel flow rate adjustment valve VA: Air flow rate adjustment valve VWSP: Water injection flow rate adjustment valve VSSP: Steam injection flow rate adjustment valve 201: Steam utilization equipment 301: Required steam condition setting unit for GT injection 302: Steam temperature set value 303: Steam pressure set value 304: Steam flow rate set value 305: GT injection method priority selection unit 306: GT injection steam condition unit 307: Schedule calculation start unit 308: GT injection steam condition allowable value change Part 315: Steam flow rate difference setting column 316: Steam flow rate deviation setting column 317: Steam temperature difference setting column 31 : Steam temperature deviation setting column 319: Steam pressure difference setting column 320: Steam pressure deviation setting column 321: Schedule calculation recalculation unit 322: Steam condition selection unit for GT injection 323: Schedule calculation result determination unit 324: Required steam temperature / pressure Vapor flow rate 325 calculated from: Required flow rate difference of steam flow rate calculated from required steam temperature / pressure 326: Flow rate deviation of required steam flow rate from required steam temperature / pressure 327: Steam temperature 328 determined from required steam flow rate : Temperature difference of steam temperature obtained from required steam flow rate with respect to required steam temperature 329: Temperature deviation of steam temperature obtained from required steam flow rate with respect to required steam temperature 330: Steam pressure obtained from required steam flow rate 331: Steam pressure obtained from required steam flow rate Pressure difference 332 with respect to required steam pressure: Steam obtained from required steam flow rate Pressure deviation PB1: Water injection push button PB2: Steam injection push button PB3: Steam / water injection automatic switching push button PB4: Deviation allowance push button PB5: Schedule calculation start push button PB6: Schedule calculation re- Calculation push button PB7: GT injection steam condition selection (temperature pressure priority) push button PB8: GT injection steam condition selection (flow priority) push button PB9: Schedule calculation result confirmation push button PB10: Steam flow difference change item selection push button PB11: Steam flow deviation change item selection push button PB12: Steam temperature difference change item selection push button PB13: Steam temperature deviation change item selection push button PB14: Steam pressure difference change item selection push button PB15: Steam pressure deviation change item selection push button ST1T: Setting steam for required steam Temperature ST1P: Set steam pressure of required steam ST1F: Set steam temperature / calculated steam flow by set steam pressure / set steam flow ST1FB: Set steam temperature / calculated steam flow by set steam pressure / Steam flow deviation ratio of set steam flow ST2F: Required steam set steam flow rate ST2T: Calculated steam temperature by set steam flow rate / set steam temperature ST2TB: Calculated steam temperature by set steam temperature / Steam temperature deviation ratio of set steam temperature ST2P: Calculated steam pressure by set steam flow rate / Set steam pressure ST2PB: Calculated steam pressure by set steam flow / Steam pressure deviation ratio of set steam pressure ST3T: Steam temperature reverse calculation ST3P: Steam pressure reverse calculation ST4F: Steam flow reverse calculation S801: Comparison judgment step between required steam flow and rated steam flow Step S802: Necessary steam Comparison judgment step S803 between the flow rate and the rated steam flow rate: Schedule calculation is performed with a pattern in which the cogeneration power generation facility is operated by injection Step S804: Schedule calculation is performed with a pattern in which the cogeneration power generation facility is operated by combined use of water injection and steam injection Step S805: Pattern in which the cogeneration power generation facility is operated by steam injection Perform schedule calculation Step DS1F: Required steam flow (Required steam flow <Rated steam flow)
NS1F: Required steam flow (Required steam flow <Rated steam flow)
TS1F: Necessary steam flow of cogeneration power generation equipment (required steam flow <rated steam flow)
JS1F: Necessary steam injection flow rate of cogeneration power generation facilities (required steam flow rate <rated steam flow rate)
JW1F: Necessary water injection flow rate for cogeneration power generation facilities (required steam flow rate <rated steam flow rate)
DS2F: Required steam flow rate (Required steam flow rate ≥ Rated steam flow rate)
NS2F: Necessary steam flow (Required steam flow ≥ Rated steam flow)
TS2F: Necessary steam flow of cogeneration power generation equipment (required steam flow ≥ rated steam flow)
JS2F: Necessary steam injection flow rate for cogeneration power generation facilities (required steam flow rate ≥ rated steam flow rate)
JW2F: Required water injection flow rate of cogeneration power generation equipment (required steam flow rate ≥ rated steam flow rate)

Claims (5)

Consists of gas turbine equipment that injects water and steam into the combustion section and drives the generator to rotate, and an exhaust heat recovery boiler that generates steam using the combustion exhaust gas from the gas turbine equipment. An operation support device for a cogeneration power generation facility that supplies steam generated in a boiler,
Setting means for setting the required steam flow rate as the first element and the required steam temperature / required steam pressure as the second element as the required steam conditions from the steam utilization facility, the first element and the second element The first calculation means for calculating the other element of the first element and the second element on the basis of one of the elements is compared with the set value and the calculated value of the other element. A first inverse calculation means for obtaining a value of the one element from the deviation by reverse calculation, and repeatedly performing an operation until a difference between the reverse calculation value of the one element and a set value is less than or equal to an allowable value; It is comprised by the control means which controls the said gas turbine equipment by making into the required steam conditions from the said steam utilization equipment the back-calculated value of said one element confirmed that it is below the said allowable value by one back-calculating means. Cogeneration power generation characterized by Equipment operation support device. The operation support apparatus for the cogeneration power generation facility according to claim 1,
Second calculation means for calculating one element of the first element and the second element on the basis of the other element of the first element and the second element; and a set value of the one element; Compare the calculated values, and if the two differ, obtain the value of the other element from the deviation by back calculation, and repeat the calculation until the difference between the back calculation value of the other element and the set value is less than the allowable value Second reverse calculation means, and the control means calculates a reverse calculation value of the element, which is confirmed to be equal to or less than the allowable value by the first or second reverse calculation means, from the steam utilization facility. And an operation support apparatus for a cogeneration power generation facility that controls the gas turbine facility. The operation support apparatus for the cogeneration power generation facility according to claim 1 or 2,
Means for comparing the required steam flow rate obtained as the required steam condition from the steam utilization facility with the rated flow rate of the exhaust heat recovery boiler, and the amount of water injected into the combustion section when the required steam flow rate is equal to or higher than the rated flow rate Water control means for controlling the water control when the required steam flow rate is less than or equal to the rated flow rate and the total amount of the required steam flow rate and the amount of steam injected into the combustion section is greater than or equal to the rated flow rate. In addition to water injection by means, the steam control means for controlling the amount of steam to be injected into the combustion section, and the required steam flow rate obtained as the required steam condition from the steam utilization facility is obtained by calculating the reverse power. A driving support device for a cogeneration power generation facility characterized by It is a driving support device of the cogeneration power generation equipment according to any one of claims 1 to 3,
The operation support apparatus for a cogeneration power generation facility, wherein the setting means for setting the required steam condition from the steam utilization facility sets the required steam condition for each time zone in 24 hours on a specific day. Consists of gas turbine equipment that injects water and steam into the combustion section and drives the generator to rotate, and an exhaust heat recovery boiler that generates steam using the combustion exhaust gas from the gas turbine equipment. An operation support device for a cogeneration power generation facility that supplies steam generated in a boiler,
A means for comparing the required steam flow rate from the steam utilization facility with the rated flow rate of the exhaust heat recovery boiler, and a water control means for controlling the amount of water injected into the combustion section when the required steam flow rate is equal to or higher than the rated flow rate. And when the required steam flow rate is equal to or less than the rated flow rate and the total amount of the required steam flow rate and the amount of steam injected into the combustion section is equal to or greater than the rated flow rate, along with water injection by the water control means, An operation support device for a cogeneration power generation facility, characterized by comprising steam control means for controlling the amount of steam injected into the combustion section.

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