A method for determining the load setting value of a gas-steam combined cycle unit

Abstract

The present invention relates to the field of gas turbine technology, and in particular to a method for determining a set value of a gas turbine load for a gas-steam combined cycle unit, comprising: obtaining a first transfer function based on the set value of the gas turbine load and the actual load value of the gas turbine, obtaining a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine, obtaining a third transfer function using the first transfer function and the second transfer function, subjecting the third transfer function to feedback control and Smith predictive feedforward processing to obtain an optimized set value of the gas turbine load, so that the unit can accurately and quickly track load instructions and reduce parameter fluctuations. Smith predictive feedforward is introduced on the basis of feedback control to compensate for the pure delay characteristics of the steam turbine, so that the unit can recover stability more quickly during load changes. The Smith predictive control quantity is multiplied by a coefficient K as the feedforward control quantity of the PID, so as to reduce the impact on the control system after the unit characteristics change.

Description

Technical Field

[0001] The present invention relates to the technical field of gas turbines, and in particular to a method, device, equipment and storage medium for determining a load setting value of a gas turbine in a gas-steam combined cycle unit. Background Art

[0002] The combined gas-steam cycle power generation method, characterized by fast start-up and shutdown, low emissions, and high efficiency, has experienced rapid development in recent years. A combined gas-steam cycle unit typically consists of a gas turbine, a steam turbine, and a waste heat boiler (HRSG) (a "one-on-one" unit). The gas turbine utilizes the high-temperature, high-pressure gas generated by fuel combustion to generate power within the turbine, while the HRSG absorbs heat from the gas turbine exhaust to generate superheated steam, which enters the steam turbine to generate power. During power generation, the grid dispatcher only specifies the power generation load of the entire combined cycle unit. The unit coordinated control system must distribute the grid dispatcher's load instructions to the gas turbine (gas turbine) and steam turbine (steam turbine). After the steam turbine completes warm-up, the main control valve is fully opened, and sliding pressure operation begins, no longer controlling the steam turbine's power generation load. At this point, the steam turbine load is directly affected by the gas turbine's exhaust temperature and flow rate. Ultimately, the unit coordinated control system must convert the grid dispatcher's instructions into the gas turbine's load setpoint.

[0003] Gas turbines have a very fast load response time, quickly reaching their setpoints. In contrast, steam turbine load changes experience a certain delay. This is because changes in gas turbine load cause changes in exhaust temperature and flow, which in turn alter the heat absorbed by the waste heat boiler (HRSG), causing changes in main steam pressure, which ultimately manifests as changes in steam turbine load. Therefore, when the grid dispatcher issues a load change command, the coordinated control system must rationally adjust the gas turbine load setpoint to ensure that the unit's load quickly tracks the grid load command while avoiding overshoot that could cause fluctuations in unit parameters.

[0004] At present, the calculation of the turbine load setting value of the gas-steam combined cycle unit usually combines the total load instruction P with the actual turbine load P S0 The difference is used to obtain the set value of the gas turbine load. In order to alleviate the influence of the delay characteristics of the steam turbine, the gas turbine load set value P G Fine-tune, such as P G Apply bias or change P G However, due to the inherent delay of the steam turbine side, using the parameters on the steam turbine side to adjust the gas turbine load set value is prone to overshoot, resulting in unit parameter fluctuations and affecting the service life of the equipment. Therefore, it is necessary to design a method for determining the gas turbine load set value of a gas-steam combined cycle unit so that the unit can smoothly transition during the load change process and reduce parameter fluctuations. Summary of the Invention

[0005] The purpose of the present invention is to provide a method for determining a set value of a gas-steam combined cycle engine load, so as to solve the problem that the set value of a gas-steam combined cycle engine load easily causes fluctuations in unit parameters and affects the service life of the equipment.

[0006] To solve the above technical problems, the present invention provides a method for determining a load setting value of a gas turbine of a gas-steam combined cycle unit, comprising:

[0007] Obtaining a first transfer function based on a combustion engine load setting value and an actual combustion engine load value;

[0008] obtaining a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine;

[0009] obtaining a third transfer function using the first transfer function and the second transfer function;

[0010] The third transfer function is subjected to feedback control and Smith estimation feedforward processing to obtain an optimized combustion engine load setting value.

[0011] Preferably, the first transfer function calculation formula is:

[0012]

[0013] Among them, s is the Laplace operator, G G (s) is the first transfer function, P G0 is the actual load value of the gas turbine, P G is the set value of the gas turbine load value, T G is the inertia time constant related to the variable load characteristics of the gas turbine.

[0014] Preferably, the second transfer function calculation formula is:

[0015]

[0016] Among them, G S (s) is the second transfer function, P S0 is the actual load value of the steam turbine, P G0 is the actual load value of the gas turbine, K S is the gain coefficient, T S is the inertia time constant related to the variable load characteristics of the steam turbine, and τ is the pure delay time coefficient related to the heat absorption process of the waste heat boiler.

[0017] Preferably, the third transfer function is calculated as follows:

[0018]

[0019] Where G(s) is the third transfer function and P0 is the actual load of the unit.

[0020] Preferably, performing feedback control and Smith prediction feedforward processing on the third transfer function includes:

[0021] The unit load command is set as the set value of the feedback controller, the actual load value of the unit is set as the controlled parameter, the gas turbine load set value is set as the control quantity, and the third transfer function is subjected to feedback control processing and Smith estimation feedforward processing to obtain an optimized gas turbine load set value.

[0022] Preferably, the Smith prediction feedforward processing includes:

[0023] The Smith predictive control amount is multiplied by the coefficient K as the feedforward amount of the feedback control, and the pure delay characteristic is compensated by the feedforward amount of the feedback control. The feedback controller maintains the stability of the control system, completing the Smith predictive feedforward processing.

[0024] The present invention also provides a device for determining a load setting value of a gas-steam combined cycle unit, comprising:

[0025] A first transfer function module obtains a first transfer function based on a combustion engine load setting value and an actual combustion engine load value;

[0026] A second transfer function module, which obtains a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine;

[0027] a third transfer function module, which obtains a third transfer function using the first transfer function and the second transfer function;

[0028] The combustion engine load setting value optimization module performs feedback control and Smith estimation feedforward processing on the third transfer function to obtain an optimized combustion engine load setting value.

[0029] The present invention also provides a device for determining a load setting value of a gas-steam combined cycle unit, comprising:

[0030] memory for storing computer programs;

[0031] A processor is used to implement the steps of the above-mentioned method for determining the load setting value of the gas turbine of the gas-steam combined cycle unit when executing the computer program.

[0032] The present invention also provides a computer-readable storage medium having a computer program stored thereon. When the computer program is executed by a processor, the steps of the method for determining the load setting value of the gas turbine of the gas-steam combined cycle unit are implemented.

[0033] The present invention provides a method for determining the set value of the load of a gas-steam combined cycle unit. The method obtains a first transfer function based on the set value of the load of the gas turbine and the actual load value of the gas turbine, obtains a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine, and obtains a third transfer function using the first transfer function and the second transfer function. The third transfer function is subjected to feedback control and Smith predictive feedforward processing to obtain an optimized set value of the load of the gas turbine, which enables the unit to track the load instruction smoothly, accurately and quickly, while reducing overshoot and avoiding parameter fluctuations. Smith predictive feedforward is introduced on the basis of PID control to compensate for the pure delay characteristics of the steam turbine, so that the unit can recover stability more quickly during the load change process. The Smith predictive control quantity is multiplied by the coefficient K as the feedforward control quantity of the PID to reduce the impact on the control system after the unit characteristics change. BRIEF DESCRIPTION OF THE DRAWINGS

[0034] The above and / or additional aspects and advantages of the present invention will become apparent and readily understood from the following description of the embodiments in conjunction with the accompanying drawings, in which:

[0035] Figure 1 This is a flow chart of a first specific embodiment of a method for determining a load setting value of a gas turbine in a gas-steam combined cycle unit provided by the present invention;

[0036] Figure 2 A structural diagram of a coordinated control system for a gas-steam combined cycle unit according to the method for determining a combustion engine load setpoint provided by the present invention;

[0037] Figure 3 It is the load transfer function model of the gas turbine and steam turbine of the gas-steam combined cycle unit;

[0038] Figure 4 Calculation logic diagram for the load setting value of the combustion engine of a traditional gas-steam combined cycle unit;

[0039] Figure 5 A calculation logic diagram of the load setting value of the gas turbine of the gas-steam combined cycle unit provided by the present invention;

[0040] Figure 6 The following are the unit variable load curves under different calculation methods of the gas turbine load setting value;

[0041] Figure 7 It is the variable load curve diagram after the unit characteristics change;

[0042] Figure 8 This is a structural block diagram of a device for determining a combustion engine load setting value of a gas-steam combined cycle unit provided by an embodiment of the present invention. DETAILED DESCRIPTION

[0043] The core of the present invention is to provide a method, device, equipment and storage medium for determining the load setting value of the gas turbine of a gas-steam combined cycle unit, so that the gas-steam combined cycle unit can smoothly, accurately and quickly track the load instruction during the load change process, while reducing the overshoot and avoiding parameter fluctuations.

[0044] In order to enable those skilled in the art to better understand the present invention, the present invention will be further described in detail below with reference to the accompanying drawings and specific embodiments. Obviously, the embodiments described are only some of the embodiments of the present invention, and not all of them. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative work are within the scope of protection of the present invention.

[0045] A method for determining a load setting value of a gas turbine in a gas-steam combined cycle unit according to an embodiment of the present invention will be described below with reference to the accompanying drawings.

[0046] Please refer to Figure 1 , Figure 1 This is a flow chart of a first specific embodiment of a method for determining a set value of a gas turbine load in a gas-steam combined cycle unit provided by the present invention; the specific operating steps are as follows:

[0047] Step S101: obtaining a first transfer function based on a combustion engine load setting value and a combustion engine actual load value;

[0048] The first transfer function calculation formula is:

[0049]

[0050] Among them, s is the Laplace operator, G G (s) is the first transfer function, P G0 is the actual load value of the gas turbine, P G is the set value of the gas turbine load value, T G is the inertia time constant related to the variable load characteristics of the gas turbine.

[0051] Step S102: obtaining a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine;

[0052] The second transfer function calculation formula is:

[0053]

[0054] Among them, G S (s) is the second transfer function, P S0 is the actual load value of the steam turbine, P G0 is the actual load value of the gas turbine, K S is the gain coefficient, T Sis the inertia time constant related to the variable load characteristics of the steam turbine, and τ is the pure delay time coefficient related to the heat absorption process of the waste heat boiler.

[0055] Step S103: obtaining a third transfer function using the first transfer function and the second transfer function;

[0056] The third transfer function is calculated as follows:

[0057]

[0058] Where G(s) is the third transfer function and P0 is the actual load of the unit.

[0059] Step S104: performing feedback control and Smith estimation feedforward processing on the third transfer function to obtain an optimized engine load setting value;

[0060] The unit load command is set as the set value of the feedback controller, the actual unit load value is set as the controlled parameter, the gas turbine load set value is set as the control quantity, the third transfer function is subjected to feedback control processing and Smith predictive feedforward processing, the Smith predictive control quantity is multiplied by the coefficient K as the feedforward quantity of the feedback control, the pure delay characteristic of the steam turbine is compensated by the feedback control feedforward quantity, the control system is maintained stable by the feedback controller, the Smith predictive feedforward processing is completed, and the optimized gas turbine load set value is obtained. The structure of the coordinated control system of the gas-steam combined cycle unit using the gas turbine load set value determination method provided by the present invention is as follows: Figure 2 As shown. PID1 is the feedback controller, PID2 is the controller in Smith predictive control, and the engine load setting value of the feedback control is P G1 The engine load setting value of Smith's estimated feedforward is P G2 The sum of the two is the engine load setting value P after speed limiting. G The calculated engine load setting value P G Used to adjust the engine load P G0 , the change of gas turbine load affects the steam turbine load P S0 , thereby making the actual power generation load P0 of the entire combined cycle unit track the load instruction P smoothly, quickly and accurately, while reducing overshoot and avoiding parameter fluctuations.

[0061] This embodiment provides a method for determining the load setpoint of a gas turbine in a combined gas-steam cycle unit. By combining the identified transfer function model with a feedback controller design, Smith predictive control is introduced to overcome the pure delay characteristic of the waste heat boiler's heat absorption process, effectively compensating for this pure delay characteristic. Only the Smith predictive control's feedforward is used to compensate for the pure delay characteristic, while the feedback controller maintains the stability of the control system, allowing the unit to smoothly, accurately, and quickly track load commands while minimizing overshoot and avoiding parameter fluctuations. The Smith predictive control variable is multiplied by a certain coefficient, K, as the feedforward for the feedback control, minimizing the impact on the control system after changes in unit characteristics.

[0062] Based on the above embodiment, this embodiment uses two simulation examples to describe the method for determining the load setting value of the gas turbine of the gas-steam combined cycle unit, as follows:

[0063] Based on the historical operating data of a gas-steam combined cycle unit, the G G (s) and G S (s)T G , K S 、T S , and the value of τ. By adopting the exhaustive optimization method, the identification results and the ITAE (integral of the absolute value of the error and time) of the operating data are used as indicators, and the identification results are obtained as follows:

[0064]

[0065]

[0066] like Figure 3 As shown, by combining the above two equations, the load transfer function model of the gas turbine and steam turbine of the gas-steam combined cycle unit can be obtained.

[0067] like Figure 4 As shown, the traditional gas turbine load setting value P G The calculation method is: directly calculate the total load command P and the actual turbine load P S0 Make the difference and get E PS , the main steam pressure p T The differential and coefficient K T Multiply the V T , the deviation E between the unit load instruction P and the unit actual load P0 P0 , using V T With E P0 Cooperate with change E PS The limiting rate is finally obtained as P G The speed limit function is mainly used in the final stage of load regulation. P0 When it is smaller, according to the main steam pressure p T The rate of change of EPS Implement speed limit.

[0068] like Figure 5 As shown, the engine load setting value P provided by the present invention is G The calculation is mainly divided into two parts. The main control method is PID feedback control. The difference P0 between the unit load instruction P and the actual load of the unit is obtained by PID feedback control. G1 On the basis of feedback control, the control quantity estimated by Smith is introduced and multiplied by the coefficient K to obtain P G2 As the feedforward control quantity. Since the load change rate of the combined cycle unit's gas turbine and steam turbine is limited to 15MW / min, P G1 With P G2 The final engine load instruction P is obtained after summing and passing through the speed limit link. G It's worth noting that the PID controller should include an anti-integral windup function, which stops integration when the rate of change of the turbine load setpoint reaches the upper rate limit. Limiting the load rate will cause the unit to take a long time to track the grid load command. Without anti-integral windup, the integral term of the PID control will be very large, causing integral windup and affecting control effectiveness.

[0069] Simulation verification:

[0070] like Figure 6 As shown, the initial load of the unit is 300MW. At the 10th second, the unit load instruction P drops from 300MW to 290MW. The traditional method and the method provided by the present invention are used to calculate the gas turbine load setting value P. G Variable load simulation tests were conducted. During the mid-stage of the load change, both models varied their loads at an upper limit of 15 MW / min. When the unit load dropped to near the target load, the method for determining the gas turbine load setpoint provided by the present invention enabled timely adjustment, significantly reducing overshoot. This has positive implications for stabilizing unit parameters during variable load conditions and improving the unit's AGC (automatic generation control) performance.

[0071] Since Smith predictor depends on the accuracy of the object model, especially the pure delay time, the performance of Smith predictor control will decrease when the unit characteristics change. The turbine load setting value P provided by the present invention is G In the determination method, only the Smith estimate is multiplied by the coefficient K (taken as 0.1) as the feedforward control quantity, which has little effect on the control effect. The simulation verification is carried out below.

[0072] If the unit characteristics change, there are:

[0073]

[0074]

[0075] like Figure 7 As shown in the figure, the Smith predictor parameters remain unchanged and the Smith predictor control has model mismatch. Assuming that the initial load of the unit is 300MW, the unit load instruction P is increased from 300MW to 320MW at the 10th second. The traditional method and the method provided by the present invention are used to determine the gas turbine load setting value P. G , and conduct variable load simulation test. The results show that even if the object characteristics change, the gas turbine load setting value P provided by the present invention G It can still keep the parameters of the unit stable during the load change process, reduce overshoot and improve the adjustment speed.

[0076] An embodiment of the present invention provides a method for determining a gas turbine load setpoint for a combined gas-steam cycle unit, combining PID feedback control with Smith predictive feedforward control. During a variable load process, the gas turbine load setpoint can be determined. Using this setpoint to control the gas turbine load enables the unit's power generation load to quickly track grid load instructions, while also ensuring smooth parameter transitions during variable loads and minimizing overshoot. Even if object characteristics change, this method ensures a smooth and rapid transition to the target load during variable loads. The effectiveness of this method was verified through two simulation examples.

[0077] Please refer to Figure 8 , Figure 8 This is a structural block diagram of a device for determining a load setting value of a gas-steam combined cycle unit provided by an embodiment of the present invention; the specific device may include:

[0078] A first transfer function module 100 obtains a first transfer function based on a combustion engine load setting value and a combustion engine actual load value;

[0079] A second transfer function module 200 is configured to obtain a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine;

[0080] A third transfer function module 300 is configured to obtain a third transfer function using the first transfer function and the second transfer function;

[0081] The combustion engine load setting value optimization module 400 performs feedback control and Smith estimation feedforward processing on the third transfer function to obtain an optimized combustion engine load setting value.

[0082] The present embodiment of a gas-steam combined cycle unit fuel engine load setting value determining device is used to implement the aforementioned gas-steam combined cycle unit fuel engine load setting value determining method. Therefore, the specific implementation of the gas-steam combined cycle unit fuel engine load setting value determining device can be seen in the embodiment of the aforementioned gas-steam combined cycle unit fuel engine load setting value determining method. For example, the first transfer function module 100, the second transfer function module 200, the third transfer function module 300, and the fuel engine load setting value optimization module 400 are respectively used to implement steps S101, S102, S103, and S104 in the aforementioned gas-steam combined cycle unit fuel engine load setting value determining method. Therefore, its specific implementation can refer to the description of the corresponding embodiments of each part, and will not be repeated here.

[0083] A specific embodiment of the present invention also provides a device for determining the load setting value of a gas-steam combined cycle unit engine, comprising: a memory for storing a computer program; and a processor for implementing the steps of the above-mentioned method for determining the load setting value of a gas-steam combined cycle unit engine when executing the computer program.

[0084] In the description of this specification, the reference terms "one embodiment", "some embodiments", "example", "specific example", or "some examples" mean that the specific features, structures, materials or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the present invention. In this specification, the schematic representations of the above terms do not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described can be combined in any one or more embodiments or examples in a suitable manner. In addition, those skilled in the art can combine and combine different embodiments or examples described in this specification and features of different embodiments or examples without contradiction.

[0085] Furthermore, the terms "first" and "second" are used for descriptive purposes only and should not be construed as indicating or implying relative importance or implicitly specifying the number of the technical features being referred to. Thus, a feature defined as "first" or "second" may explicitly or implicitly include at least one such feature. In the description of the present invention, "plurality" means at least two, such as two, three, etc., unless otherwise specifically defined.

[0086] Any process or method description in a flowchart or otherwise described herein may be understood to represent a module, segment or portion of code comprising one or more executable instructions for implementing the steps of a custom logical function or process, and the scope of the preferred embodiments of the present invention includes alternative implementations in which functions may be performed out of the order shown or discussed, including performing functions in a substantially simultaneous manner or in the reverse order depending on the functions involved, which should be understood by those skilled in the art to which the embodiments of the present invention pertain.

[0087] The various embodiments in this specification are described in a progressive manner, with each embodiment focusing on its differences from the other embodiments. Reference can be made to the descriptions of the identical or similar parts between the various embodiments. For the devices disclosed in the embodiments, since they correspond to the methods disclosed in the embodiments, the descriptions are relatively simple, and the relevant parts can be referred to the descriptions of the methods.

[0088] The above is a detailed introduction to the method, device, equipment and storage medium for determining the load setting value of the gas turbine of a gas-steam combined cycle unit provided by the present invention. Specific examples are used herein to illustrate the principles and implementation methods of the present invention. The description of the above embodiments is only used to help understand the method of the present invention and its core idea. It should be pointed out that for ordinary technicians in this technical field, without departing from the principles of the present invention, several improvements and modifications can be made to the present invention, and these improvements and modifications also fall within the scope of protection of the claims of the present invention.

[0089] It should be understood that various parts of the present invention can be implemented using hardware, software, firmware, or a combination thereof. In the above-described embodiments, multiple steps or methods can be implemented using software or firmware stored in a memory and executed by a suitable instruction execution system. For example, if implemented using hardware, as in another embodiment, any one of the following technologies known in the art or a combination thereof can be used: a discrete logic circuit having a logic gate circuit for implementing a logic function on a data signal, an application-specific integrated circuit having a suitable combination of logic gate circuits, a programmable gate array (PGA), a field programmable gate array (FPGA), etc.

[0090] Those skilled in the art will understand that all or part of the steps in the method of the above embodiment can be completed by instructing related hardware through a program, and the program can be stored in a computer-readable storage medium. When the program is executed, it includes one or a combination of the steps of the method embodiment.

[0091] In addition, the functional units in the various embodiments of the present invention may be integrated into a single processing module, or each unit may exist physically separately, or two or more units may be integrated into a single module. The aforementioned integrated modules may be implemented in the form of hardware or in the form of software functional modules. If the integrated modules are implemented in the form of software functional modules and sold or used as independent products, they may also be stored in a computer-readable storage medium.

Claims

1. A method for determining a set value of a gas turbine load in a gas-steam combined cycle unit, characterized in that: include: Obtaining a first transfer function based on a combustion engine load setting value and an actual combustion engine load value; obtaining a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine; obtaining a third transfer function using the first transfer function and the second transfer function; Performing feedback control and Smith estimation feedforward processing on the third transfer function to obtain an optimized engine load setting value; Performing feedback control and Smith prediction feedforward processing on the third transfer function includes: The unit load command is set as the set value of the feedback controller, the actual load value of the unit is set as the controlled parameter, the gas turbine load set value is set as the control variable, and the third transfer function is subjected to feedback control and Smith estimation feedforward processing to obtain an optimized gas turbine load set value; The Smith prediction feedforward process includes: The Smith predictive control amount is multiplied by the coefficient K as the feedforward amount of the feedback control, and the pure delay characteristic is compensated by the feedforward amount of the feedback control. The feedback controller maintains the stability of the control system, completing the Smith predictive feedforward processing.

2. The method for determining the load setting value of a gas-steam combined cycle unit according to claim 1, wherein: The first transfer function calculation formula is: Among them, s is the Laplace operator, G G (s) is the first transfer function, P G0 is the actual load value of the gas turbine, P G is the set value of the gas turbine load value, T G is the inertia time constant related to the variable load characteristics of the gas turbine.

3. The method for determining the load setting value of a gas-steam combined cycle unit according to claim 2, wherein: The second transfer function calculation formula is: Among them, G S (s) is the second transfer function, P S0 is the actual load value of the steam turbine, P G0 is the actual load value of the gas turbine, K S is the gain coefficient, T S is the inertia time constant related to the variable load characteristics of the steam turbine, and τ is the pure delay time coefficient related to the heat absorption process of the waste heat boiler.

4. The method for determining the load setting value of a gas-steam combined cycle unit according to claim 3, wherein: The third transfer function is calculated as follows: Where G(s) is the third transfer function and P0 is the actual load of the unit.

5. A device for determining a combustion engine load setting value of a gas-steam combined cycle unit, characterized in that: include: A first transfer function module obtains a first transfer function based on a combustion engine load setting value and an actual combustion engine load value; A second transfer function module, which obtains a second transfer function based on the actual load value of the gas turbine and the actual load value of the steam turbine; a third transfer function module, which obtains a third transfer function using the first transfer function and the second transfer function; A combustion engine load setting value optimization module performs feedback control and Smith estimation feedforward processing on the third transfer function to obtain an optimized combustion engine load setting value; Performing feedback control and Smith prediction feedforward processing on the third transfer function includes: The unit load command is set as the set value of the feedback controller, the actual load value of the unit is set as the controlled parameter, the gas turbine load set value is set as the control variable, and the third transfer function is subjected to feedback control and Smith estimation feedforward processing to obtain an optimized gas turbine load set value; The Smith prediction feedforward process includes: The Smith predictive control amount is multiplied by the coefficient K as the feedforward amount of the feedback control, and the pure delay characteristic is compensated by the feedforward amount of the feedback control. The feedback controller maintains the stability of the control system, completing the Smith predictive feedforward processing.

6. A device for determining the load setting value of a gas-steam combined cycle unit, characterized in that: include: memory for storing computer programs; A processor, configured to implement the steps of the method for determining a load setting value of a gas turbine in a gas-steam combined cycle unit as claimed in any one of claims 1 to 4 when executing the computer program.

7. A computer-readable storage medium, characterized in that The computer-readable storage medium stores a computer program, which, when executed by a processor, implements the steps of the method for determining the load setting value of a gas-steam combined cycle unit according to any one of claims 1 to 4.

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