Reservoir dispatching chart drawing method, system and equipment based on power generation optimal dispatching line

Abstract

The invention relates to a reservoir scheduling graph drawing method, system and equipment based on a power generation optimal scheduling line, and the method comprises the steps: building a target function, determining the constraint condition of the target function, and taking the reservoir flood discharge water level as the decision variable of a reservoir scheduling graph model; the relation between the power generation water consumption rate and the water utilization rate in the operation process of the hydropower station is effectively balanced; meanwhile, inputting the collected reservoir and unit characteristic data into the reservoir scheduling graph model, and performing optimization calculation on the reservoir scheduling graph model by using a sine and cosine-particle swarm algorithm to obtain an optimal scheduling line existing in the Xinyi reservoir capacity; based on the optimal scheduling line, the reservoir scheduling graph drawn by combining the auxiliary scheduling lines corresponding to different incoming water frequencies can significantly improve the power generation capacity of the hydropower station, the utilization rate of water energy and the predictability and accuracy of scheduling, so that the overall benefit of the power generation capacity of the hydropower station is maximized; the system and the equipment are used for realizing the method.

Description

Technical Field

[0001] The present invention relates to the technical field of water conservancy projects, and in particular to a method, system and equipment for drawing a reservoir dispatching diagram based on an optimal power generation dispatching line. Background Art

[0002] Reservoir operation charts are crucial tools for the design and management of hydropower stations. Many of a station's performance indicators are correlated with these charts, and they serve as a crucial means of guiding the safe and economical operation of hydropower stations on-site. The concept of reservoir regulation and allocation for hydropower stations, also known as conventional reservoir operation charts or traditional reservoir operation charts, was proposed by Soviet scholar A.A. Morozov in 1926. This concept has gradually evolved into the reservoir operation chart. It primarily consists of three lines (upper and lower base lines, and a reduced output line) centered around guaranteed output. Its advantages are simplicity and ease of use. The derivation process involves working backward from the dead water level to determine the base line based on a typical year, with the emphasis on meeting guaranteed output and guaranteed rate. However, the upper and lower base lines derived from typical years are poorly representative, and there is no objective function for calculating hydropower, resulting in a low-quality hydropower utilization method. Conventional operation charts require the annual reduction of the regulating reservoir to the dead water level, a major factor in reducing the power generation efficiency and guaranteed rate of hydropower stations. Currently, scholars in the field of water resources research mostly use measures such as optimizing three lines, more finely dividing the water level range of each output line, and slowly lowering the water level in the installed capacity area during the water supply period for conventional reservoir scheduling diagrams. These studies have not fundamentally changed the conventional scheduling diagrams of traditional reservoirs.

[0003] In actual reservoir operation, increasing power generation by lowering the reservoir water level and reducing water abandonment is a common approach. While low-water-level operation can indeed reduce water abandonment, runoff varies between high and low periods. If a hydropower station operates at low head for a long period and runoff is relatively low, the power generation water consumption rate will be high. Furthermore, the low head limits the output of the generating units, far from reaching rated output. In some cases, power generation may decrease rather than increase. Therefore, a combination of water utilization and power generation water consumption is crucial to ensure the economic operation of a hydropower station. Power stations require both simple and effective operation methods and, more importantly, safe and economical operation methods guided by theoretical guidance, which conventional reservoir operation charts cannot fully address.

[0004] The invention patent application with publication number CN118114901A proposes a method for optimizing a reservoir power generation scheduling diagram. This method solves the optimal power generation scheduling diagram through an improved marine predator algorithm, solving problems such as repeated parameter adjustment and verification and redundant optimization space in conventional reservoir scheduling diagrams. It has the advantages of fast convergence speed, strong global optimization capability, and low model calculation cost. However, this method focuses on model optimization and runoff generation. The design and construction of the model does not go beyond the framework of the conventional scheduling diagram, and does not deeply consider the main factors affecting the power generation efficiency of the hydropower station. Moreover, the optimized scheduling diagram does not give a reservoir water level control target that takes into account the weather forecast for the future period, and cannot change the limitations of the conventional scheduling diagram in guiding the actual scheduling process of the hydropower station. Summary of the Invention

[0005] In order to overcome the shortcomings of the above-mentioned prior art, the purpose of the present invention is to provide a method, system and equipment for drawing a reservoir scheduling diagram based on the optimal power generation scheduling line. The method constructs an objective function, determines the constraints of the objective function, and uses the reservoir water level at the end of the ten-day period as the decision variable of the reservoir scheduling diagram model, thereby effectively balancing the relationship between the power generation water consumption rate and the water utilization rate during the operation of the hydropower station; the collected reservoir and unit characteristic data are input into the reservoir scheduling diagram model, and the sine cosine-particle swarm algorithm is used to optimize the reservoir scheduling diagram model to obtain the optimal scheduling line within the beneficial storage capacity; the reservoir scheduling diagram drawn based on the optimal scheduling line and combined with the auxiliary scheduling lines corresponding to different water inflow frequencies can significantly improve the power generation of the hydropower station, the utilization rate of water energy, the predictability and accuracy of scheduling.

[0006] In order to achieve the above object, the technical solution adopted by the present invention is:

[0007] A method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line comprises:

[0008] Construct a reservoir operation diagram model;

[0009] The reservoir and unit characteristic data are used as the input of the reservoir operation diagram model, and the optimal operation line and auxiliary operation line are solved by sine-cosine-particle swarm algorithm to draw the reservoir operation diagram.

[0010] Furthermore, the construction of the reservoir scheduling diagram model specifically includes:

[0011] Construct the objective function;

[0012] Determining constraints of the objective function;

[0013] Based on the objective function and constraints, and taking the reservoir water level at the end of ten days as the decision variable, a reservoir scheduling diagram model is constructed.

[0014] Furthermore, the objective function specifically includes:

[0015]

[0016] Where, E is the total power generation; n is the total number of study periods; N t A is the power output of the power station during the period; t is the comprehensive output coefficient of the time period; H t is the period water head; q (f,t) is the power generation flow during the period; Δ t is the length of the time period; W 发t W is the amount of water generated during the period; 入t W is the amount of water entering the reservoir during the period; 弃tis the amount of water abandoned during the period; ΔV is the change in storage capacity during the period; u t is the water consumption rate during the period; V t is the initial storage capacity (water storage capacity) of the time period; V t+1 is the reservoir capacity (water storage) at the end of the period.

[0017] Furthermore, the constraints specifically include:

[0018] System water balance constraints:

[0019] V t+1 =V t +[Q t -q (f,t) -q (q,t) ]*Δ t (16)

[0020] Where V t is the initial reservoir capacity during period t; V (t+1) is the reservoir capacity at the end of period t; Q t is the inflow of the reservoir during period t; q (f,t) is the power generation flow of the reservoir during period t; q (q,t) is the water discharge of the reservoir during period t;

[0021] Water level constraint:

[0022]

[0023] Where, is the upper water level constraint of the reservoir in period t; is the lower limit water level constraint of the reservoir in period t;

[0024] Storage capacity constraints:

[0025] V t min <V t <V t max (18)

[0026] Where V t min is the upper limit storage capacity constraint of the reservoir in period t; V t max is the lower storage capacity constraint of the reservoir in period t;

[0027] Output constraints:

[0028]

[0029] Where, is the minimum allowable output of the hydropower station at each water head in period t; is the maximum allowable output of the hydropower station at each water head in period t;

[0030] Maximum overcurrent capacity constraint:

[0031]

[0032] Where q t is the total outflow of the reservoir in period t; is the maximum allowable outflow of the reservoir in period t;

[0033] Ecological flow constraints:

[0034]

[0035] Where q t is the total outflow of the reservoir in period t; is the minimum ecological discharge flow of the reservoir;

[0036] Guaranteed output and guaranteed rate constraints:

[0037] N t ≥N p ; P ≥ 90% (22)

[0038] Where N p is the guaranteed output of the hydropower station; P is the guaranteed rate of the hydropower station;

[0039] Penalty function:

[0040] E = E*(P+0.1) (23)

[0041] If the calculated power generation guarantee rate is less than 90%, a penalty function is used to constrain it.

[0042] Furthermore, the reservoir and unit characteristic data include but are not limited to runoff, water level and storage capacity curve, downstream flow tail water level curve, and unit power generation characteristic curve.

[0043] Furthermore, the method of solving the optimal scheduling line and the auxiliary scheduling line by using the sine-cosine-particle swarm algorithm to draw the reservoir scheduling diagram specifically includes:

[0044] The sine-cosine-particle swarm algorithm is used to optimize the reservoir operation diagram model and obtain the optimal operation line;

[0045] By magnifying and reducing the long series of ten-day runoff according to the same multiple of different water inflow frequencies, and then using the sine-cosine-particle swarm algorithm for optimization calculation, the auxiliary dispatching lines corresponding to different water inflow frequencies can be obtained.

[0046] A reservoir scheduling diagram is drawn according to the optimal scheduling line and the auxiliary scheduling lines corresponding to the different water inflow frequencies.

[0047] Furthermore, the sine-cosine-particle swarm algorithm is used to optimize the reservoir operation diagram model to obtain the optimal operation line, which specifically includes:

[0048] Randomly generate scheduling lines based on constraints;

[0049] Solve the objective function value corresponding to each scheduling line;

[0050] The scheduling line is updated using the sine-cosine-particle swarm algorithm;

[0051] Repeat the process of solving the objective function value of the scheduling line and updating the scheduling line until the maximum number of iterations is met. The scheduling line corresponding to the maximum objective function value is the optimal scheduling line.

[0052] Furthermore, the long series of ten-day runoff is magnified or reduced by 0.5 to 2.0 times according to different water inflow frequencies.

[0053] A reservoir scheduling diagram drawing system based on the optimal power generation scheduling line includes:

[0054] Model building module: building reservoir operation diagram model;

[0055] Model solving module: The reservoir and unit characteristic data are used as the input of the reservoir scheduling diagram model, and the optimal scheduling line and auxiliary scheduling line are solved by the sine cosine-particle swarm algorithm to draw the reservoir scheduling diagram.

[0056] A device for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line, comprising:

[0057] Memory: used for storing a computer program to implement the above-mentioned method for drawing a reservoir scheduling diagram based on the optimal power generation scheduling line;

[0058] Processor: used to implement the above-mentioned method for drawing a reservoir scheduling diagram based on the optimal power generation scheduling line when executing the computer program.

[0059] Compared with the prior art, the present invention has the following beneficial effects:

[0060] 1. The present invention constructs an objective function, determines the constraints of the objective function, and uses the reservoir's end-of-ten-day water level as a decision factor in the reservoir scheduling diagram model. This effectively balances the relationship between the power generation water consumption rate and the water utilization rate during the operation of the hydropower station, thereby maximizing the overall benefits of the hydropower station's power generation.

[0061] 2. The present invention solves the reservoir scheduling diagram model through the sine-cosine-particle swarm algorithm to obtain the optimal scheduling line and auxiliary scheduling line; the reservoir scheduling diagram drawn based on the optimal scheduling line and the auxiliary scheduling line provides a reservoir scheduling combined with forecasts, which significantly improves the predictability and accuracy of scheduling, further meets the actual production guidance needs, and effectively avoids the problems of poor representativeness of conventional scheduling diagrams and low water energy utilization in guiding hydropower station scheduling.

[0062] In summary, the present invention constructs an objective function, determines the constraints of the objective function, and uses the reservoir water level at the end of the ten-day period as the decision variable of the reservoir scheduling diagram model, thereby effectively balancing the relationship between the power generation water consumption rate and the water utilization rate during the operation of the hydropower station; at the same time, the collected reservoir and unit characteristic data are input into the reservoir scheduling diagram model, and the reservoir scheduling diagram model is optimized and calculated using the sine cosine-particle swarm algorithm to obtain the optimal scheduling line within the beneficial storage capacity; the reservoir scheduling diagram drawn based on the optimal scheduling line and combined with the auxiliary scheduling lines corresponding to different water inflow frequencies can significantly improve the power generation, water energy utilization, scheduling predictability and accuracy of the hydropower station; the scheduling diagram drawn based on the method of the present invention can improve the power generation efficiency by 5% and the guarantee rate by 8% compared with the conventional scheduling diagram, thereby further meeting the needs of actual production guidance and realizing the maximization of the overall benefit of the hydropower station's power generation. BRIEF DESCRIPTION OF THE DRAWINGS

[0063] Figure 1 Flowchart of the method for drawing a reservoir operation diagram based on the optimal operation line.

[0064] Figure 2 This is a water system map of the upper reaches of the Han River.

[0065] Figure 3 This is the regular dispatching diagram of Ankang Hydropower Station.

[0066] Figure 4 A new dispatching diagram drawn for Ankang Hydropower Station based on the method of the present invention.

[0067] Figure 5 It is a comparison chart of power generation between a long series of conventional scheduling diagrams and the new scheduling diagram of the present invention.

[0068] Figure 6 It is a conventional dispatching diagram for a typical dry year and a water level operation process line of the new dispatching diagram library of the present invention.

[0069] Figure 7 The output and outflow process of the conventional scheduling diagram in a typical dry year and the new scheduling diagram of the present invention are shown.

[0070] Figure 8 It is the conventional dispatching diagram for a typical normal water year and the water level operation process line of the new dispatching diagram library of the present invention.

[0071] Figure 9 The output and outflow process of the conventional scheduling diagram in a typical normal water year and the new scheduling diagram of the present invention are shown.

[0072] Figure 10 It is a conventional dispatching diagram for a typical flood year and a water level operation process line of the new dispatching diagram library of the present invention.

[0073] Figure 11 This is the conventional dispatching diagram for a typical flood year, the output and outflow process of the new dispatching diagram of the present invention. DETAILED DESCRIPTION

[0074] The technical solution of the present invention will be described in detail below with reference to the accompanying drawings and embodiments.

[0075] Within the adjustable water level range, when a hydropower station operates at different water levels, the unit output, the amount of water discarded, and the water consumption rate for power generation vary, leading to significant differences in power generation and guaranteed rates. The reservoir scheduling diagram model proposed in this paper assumes that there is an optimal reservoir scheduling line during reservoir operation, namely the reservoir's annual staged water level control line. Using this scheduling line as the reservoir water level control target maximizes the power station's multi-year power generation.

[0076] See also Figure 1 A method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line includes:

[0077] 1. Construct a reservoir operation diagram model;

[0078] The construction of the reservoir operation diagram model specifically includes:

[0079] Constructing an objective function; the objective function of this embodiment is set based on the power generation of the hydropower station; the basic theory relied on for constructing the objective function is as follows:

[0080] The water consumption rate of a hydropower station is closely related to the reservoir water level. The higher the water level, the greater the comprehensive output coefficient of the unit and the lower the water consumption rate. However, for reservoirs with a certain regulatory performance, a high water level during the flood season may cause an increase in water abandonment and a decrease in water utilization. The relevant theoretical relationship is as follows:

[0081] E t =N t *Δ t =A t H t q (f,t) *Δ t (1)

[0082] Where, E t is the power generation during the period; N t The power output of the power station during the period; Δ t A is the length of the time period;t is the comprehensive output coefficient of the time period; H t is the average net water head during the period; q (f,t) is the power generation flow in the period; Formula (1) is the standard theoretical formula for water energy calculation;

[0083]

[0084] Where u t W is the water consumption rate of power generation during the period; 发t Δ is the water consumption for power generation during the period; t1 is the time period length; Δ t2 The length of the period; Formula (2) is the relationship between the period power generation water consumption rate, the period comprehensive output coefficient, and the period average net water head after derivation, and the period power generation water consumption rate is inversely proportional to the period comprehensive output coefficient and the period average net water head;

[0085] E t =A t H t (q (f,t) *Δ t )=A t H t W 发t (3)

[0086] Formula (3) is derived from Formula (1) and is the relationship between the power generation in a period and the comprehensive output coefficient of the period, the average net water head in the period, and the water consumption for power generation in the period;

[0087]

[0088] Where W 入t W is the amount of water entering the reservoir during the period; 弃t is the amount of water discarded during the period; ΔV t is the change in storage capacity (water storage) during the period; formula (4) is the relationship between the power generation during the period and the amount of water entering the reservoir during the period, the amount of water abandoned during the period, the change in storage capacity during the period, and the water consumption rate for power generation during the period, after derivation from formula (2);

[0089] Z t =f(V t ); V t =f(Z t ) (5)

[0090] Where Z t is the water level of the reservoir upstream of the reservoir; V t is the corresponding storage capacity of the reservoir water level; they are a single curve relationship, that is, the water level storage capacity curve;

[0091] q t =q (f,t) +q (q,t) ; G t=f(q t ) (6)

[0092] Where q t is the total outbound flow during the period; q (q,t) G is the water discharge flow rate during the period. t Average water level of the reservoir downstream during the period; G t With q t is the relationship curve of water level and flow rate downstream of the power station;

[0093] H t =(Z t +Z t+1 ) / 2-G t (7)

[0094] Where Z t+1 is the water level at the end of the upstream period of the reservoir; G t Average water level in the downstream area of ​​the reservoir during this period;

[0095]

[0096] Where V t+1 Storage capacity at the end of the period;

[0097] u t =f(1 / H t ) (9)

[0098] A t =f(H t ) (10)

[0099] W 弃t =f(H t ) (11)

[0100] Formulas (9) to (11) describe the water consumption rate u during the period t , comprehensive output coefficient A during the period t , amount of water discarded during the period W 弃t The average net water head H t Inversely proportional, directly proportional, or directly proportional relationship;

[0101]

[0102] η 发t +η 弃t =1 (14)

[0103] Formulas (12) to (14) describe the amount of water discharged from the reservoir during a period and the amount of water abandoned during a period W. 弃t (water abandonment rate η 弃t ), water volume W generated during the period 发t (Water utilization rate η 发t ) between them;

[0104] The objective function specifically includes:

[0105]

[0106] Where, E is the total power generation; n is the total number of study periods; N t A is the power output of the power station during the period; t is the comprehensive output coefficient of the time period; H t is the period water head; q (f,t) is the power generation flow during the period; Δ t is the length of the time period; W 发t W is the amount of water generated during the period; 入t W is the amount of water entering the reservoir during the period; 弃t is the amount of water abandoned during the period; ΔV is the change in storage capacity during the period; u t is the water consumption rate during the period; V t is the initial storage capacity (water storage capacity) of the time period; V t+1 is the reservoir capacity (water storage) at the end of the period.

[0107] Determining constraints of the objective function;

[0108] The constraints specifically include:

[0109] System water balance constraints:

[0110] V t+1 =V t +[Q t -q (f,t) -q (q,t) ]*Δ t (16)

[0111] Where V t is the initial reservoir capacity during period t; V (t+1) is the reservoir capacity at the end of period t; Q t is the inflow of the reservoir during period t; q (f,t) is the power generation flow of the reservoir during period t; q (q,t) is the water discharge of the reservoir during period t;

[0112] Water level constraint:

[0113]

[0114] Where, is the upper water level constraint of the reservoir in period t; is the lower limit water level constraint of the reservoir in period t;

[0115] Storage capacity constraints:

[0116] V t min <Vt <V t max (18)

[0117] Where V t min is the upper limit storage capacity constraint of the reservoir in period t; V t max is the lower storage capacity constraint of the reservoir in period t;

[0118] Output constraints:

[0119]

[0120] Where, is the minimum allowable output of the hydropower station at each water head in period t; is the maximum allowable output of the hydropower station at each water head in period t;

[0121] Maximum overcurrent capacity constraint:

[0122]

[0123] Where q t is the total outflow of the reservoir in period t; is the maximum allowable outflow of the reservoir in period t;

[0124] Ecological flow constraints:

[0125]

[0126] Where q t is the total outflow of the reservoir in period t; is the minimum ecological discharge flow of the reservoir;

[0127] Guaranteed output and guaranteed rate constraints:

[0128] N t ≥N p ; P ≥ 90% (22)

[0129] Where N p is the guaranteed output of the hydropower station; P is the guaranteed rate of the hydropower station;

[0130] Penalty function:

[0131] E = E*(P+0.1) (23)

[0132] If the calculated power generation guarantee rate is less than 90%, a penalty function is used to constrain it.

[0133] Based on the objective function and constraints, and taking the reservoir water level at the end of ten days as the decision variable, a reservoir scheduling diagram model is constructed.

[0134] This embodiment addresses the problems existing in the actual operation of hydropower stations. Under the premise of pursuing maximum power generation, the reservoir water level at the end of ten days is used as the key factor. By balancing the relationship between the power generation water consumption rate and the water utilization rate, the uniqueness of the reservoir water level control in stages is pursued.

[0135] According to the objective function formula (15), we know that: 入t In the case of confirmation, W 弃t 、u t , ΔV t Three key quantities determine the amount of power generated, and all three are related to the reservoir water level.

[0136] Water inflow during the period (Installed capacity or power generation and water volume under output limit line and ΔV t The sum of the water W is discarded during the period 弃t is zero, then the power generation E=max[W 入t -(V t+1 -V t )] / minu t If the water level at the beginning and end of the time period is the same, that is, ΔV t is also zero. The higher the water level, the higher the water consumption rate u t The smaller it is, the greater the power generation. The power generation is optimal when The power generation is the worst. t >0 The water level of the reservoir rises, the water consumption rate of power generation decreases, and the water consumption for power generation in this period decreases, ΔV t <0 When the reservoir water level drops, the amount of water used for power generation increases, and the water consumption rate for power generation increases. In this case, the higher the water level, the greater the power generation.

[0137] Water inflow during the period When there is water abandonment during the period, the amount of abandoned water is determined by the formula Determine and bring it into the objective function, power generation W 入t 、 V t+1 It is known that the water level is the highest at the end of the period, that is, ΔV when the water level is high at the beginning of the period t The amount of water discarded increases, and the water consumption rate of power generation is low when the water head is high; when the water level is low at the beginning of the period, ΔV t Large water abandonment reduces the amount of water, while low head leads to high water consumption for power generation. To reduce water abandonment, a low initial water level is preferred. This increases power generation in the previous period and lowers the initial water level of the current period, thereby reducing water abandonment in the current period. Therefore, there are periods where water abandonment is inevitable, and the lower the initial reservoir water level, the better. Reducing water abandonment is the key, while reducing water consumption for power generation is secondary.

[0138] During the non-flood season, the inflow is small and stable, and there is no water abandonment. Therefore, the higher the water level control, the lower the water consumption rate for power generation and the greater the power generation. During the flood season, the inflow varies greatly, and water abandonment may occur during this period. Therefore, ΔV should be controlled according to the inflow runoff characteristics. t The size of the power plant can be adjusted to reduce water abandonment while maintaining a high water level to reduce water consumption in power generation, thus ensuring maximum power generation in the period.

[0139] Time period storage tolerance ΔV t It has two functions. One is to determine the amount of water discarded during the period. The size of ΔV t Corresponding reservoir water level Z t 、Z t+1 It also controls the average power generation head H t The level of water consumption in power generation is related to u t The size of the periodic continuous storage tolerance ΔV t (V t+1 -V t ) is composed of the initial storage capacity (V t (Z t ), V t+1 (Z t+1 )……V t+n (Z t+n )) is composed of a series of parameters and is solved through optimization algorithm. The optimal dispatching line is the process of water level in each period corresponding to the maximum objective function. The optimal dispatching line balances the contradiction between water abandonment rate and water consumption rate for power generation in each period, so as to maximize the power generation over many years.

[0140] Based on the above formulas (1)-(14), it can be seen that the reservoir water level is the key factor, and the power generation water consumption rate and water utilization rate are two key elements. Controlling the reservoir water level through the objective function and balancing the relationship between the power generation water consumption rate and water utilization rate are the keys to improving the economic benefits of the hydropower station.

[0141] Second, the reservoir and unit characteristic data are used as the input of the reservoir operation diagram model, and the optimal operation line and auxiliary operation line are solved by the sine-cosine-particle swarm algorithm to draw the reservoir operation diagram.

[0142] The reservoir and unit characteristic data include but are not limited to runoff, water level and storage capacity curve, downstream flow tail water level curve, and unit power generation characteristic curve.

[0143] The method of drawing a reservoir operation diagram by solving the optimal operation line and the auxiliary operation line by using the sine-cosine-particle swarm algorithm specifically includes:

[0144] The sine-cosine-particle swarm algorithm is used to optimize the reservoir operation diagram model and obtain the optimal operation line;

[0145] The sine-cosine-particle swarm algorithm is used to optimize the reservoir operation diagram model to obtain the optimal operation line, which specifically includes:

[0146] Randomly generate scheduling lines based on constraints;

[0147] Solve the objective function value corresponding to each scheduling line;

[0148] The scheduling line is updated using the sine-cosine-particle swarm algorithm;

[0149] Repeat the process of solving the objective function value of the scheduling line and updating the scheduling line until the maximum number of iterations is met. The scheduling line corresponding to the maximum objective function value is the optimal scheduling line.

[0150] The maximum number of iterations set in this embodiment is 1000. The dispatch line is essentially a particle in each population generated by the sine-cosine-particle swarm algorithm during the optimization calculation process. Each particle corresponds to the 36 end-of-decade water levels in a year, and the objective function value corresponds to the power generation solved by each dispatch line. By continuously updating the dispatch line and solving its corresponding power generation, the dispatch line corresponding to the maximum power generation is found, which is the optimal dispatch line. The optimal dispatch line serves as the reservoir water level control line for each stage throughout the year. Using this dispatch line as the reservoir water level target will maximize the power generation of the power station.

[0151] By magnifying and reducing the long series of ten-day runoff according to the same multiple of different water inflow frequencies, and then using the sine-cosine-particle swarm algorithm for optimization calculation, the auxiliary dispatching lines corresponding to different water inflow frequencies can be obtained.

[0152] The long series of ten-day runoff is magnified and reduced by 0.5 to 2.0 times according to different water inflow frequencies, basically covering all inflow runoff processes;

[0153] A reservoir scheduling diagram is drawn according to the optimal scheduling line and the auxiliary scheduling lines corresponding to the different water inflow frequencies.

[0154] In this embodiment, the number of optimal scheduling lines is set to 1, which is 1.0 times the runoff series; the number of auxiliary scheduling lines is set to 4, which are runoff series 0.5 (extremely dry), 0.8 (20% dry), 1.2 (20% abundant), and 2.0 (extremely abundant); the auxiliary scheduling lines are essentially the optimal scheduling lines of the corresponding runoff series after the runoff series is reduced or expanded, and the optimization calculation process is the same as that of the optimal scheduling line.

[0155] During the actual operation of the reservoir, the optimal dispatching line divides the reservoir dispatching diagram into two areas, the upper area for the dry season and the lower area for the flood season. When rainfall and runoff forecasts are not considered, the optimal dispatching line is the reservoir's phased water level process line, which is the target control water level at the end of each period of the reservoir. When the forecast is considered, the water level of the corresponding auxiliary dispatching line is selected as the target control water level at the end of the period in combination with the runoff forecast results of the next period.

[0156] A reservoir scheduling diagram drawing system based on the optimal power generation scheduling line includes:

[0157] Model building module: building reservoir operation diagram model;

[0158] Model solving module: The reservoir and unit characteristic data are used as the input of the reservoir scheduling diagram model, and the optimal scheduling line and auxiliary scheduling line are solved by the sine cosine-particle swarm algorithm to draw the reservoir scheduling diagram.

[0159] A device for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line, comprising:

[0160] Memory: used for storing a computer program to implement the above-mentioned method for drawing a reservoir scheduling diagram based on the optimal power generation scheduling line;

[0161] Processor: used to implement the above-mentioned method for drawing a reservoir scheduling diagram based on the optimal power generation scheduling line when executing the computer program.

[0162] The application effects of the present invention are described in detail below with reference to specific implementation cases.

[0163] Ankang Hydropower Station is located 18 kilometers west of Ankang City in the upper reaches of Han River. Figure 2 As shown, the controlled basin area is 35,700 km 2 It is the fourth of the seven-level cascade development projects on the main stream of the Han River in Shaanxi Province, with a total installed capacity of 852MW (4*200+1*52). It is a large-scale water conservancy hub project with power generation as its main function, and with comprehensive benefits such as flood control, shipping, and tourism. It is the main power station for peak and frequency regulation and accident standby of the Shaanxi power grid.

[0164] The normal water storage level of the power station is 330m, and the corresponding storage capacity is 2.585 billion m 3 The flood season is from May to October. The flood limit water level during the main flood season (July to September) is 325m, the dead water level of the reservoir is 305m, and the dead storage capacity is 1.113 billion m 3 , Xingli reservoir capacity is 1.47 billion m 3 The reservoir has a capacity coefficient of 8% and is a partial annual regulation reservoir. The power station has a designed head of 76.2m, a drawdown depth of 25m, and a guaranteed output of 142MW. The reservoir began impounding in October 1989, with the first unit generating electricity in December 1990, and all units generating electricity in December 1992.

[0165] During the planning, preliminary design and design phase of the power station, the monthly runoff and flood data from 1950 to 1983, totaling 34 years, were used. The average annual runoff was 19.2 billion m 3 The average annual flow rate is 608m 3 / s, and the designed average power generation over many years is 2.857 billion kW·h.

[0166] The dam site has 72 years of monthly runoff data from July 1950 to June 2022, with an average annual runoff of 18 billion m 3 The average flow rate over many years is 570m 3 / s, which served as the basic data for this study.

[0167] The power station has 32 years of actual operation data from 1991 to 2022, with an average annual runoff of 16.44 billion m 3 The average annual flow rate is 521m 3 / s; the actual average power consumption is 2.45 billion kW·h. As the basic data for analysis and comparison, the runoff into the reservoir after the power station was put into operation is in the dry year period. The actual water consumption rate is 5.74m 3 / kW·h, water abandonment rate is 15.1%.

[0168] 1. Analysis of actual operation of power station

[0169] After the Ankang Hydropower Station was put into operation, it basically operated according to the reservoir dispatching diagram designed by Beijing Hydropower Survey and Design Institute. Figure 3 The power station has been in operation for 32 years, with a maximum water inflow of 36 billion m 3 It appeared in 2021, with power generation reaching 4 billion kW·h. Through statistical analysis of the actual operation data of Ankang Reservoir over the years, it was found that the actual power generation index was about 4% lower than the long-term calculation index of the conventional scheduling diagram during the same period. The main reasons are: (1) The water inflow to the reservoir is in a continuous dry period; (2) The power generation head is low according to the conventional reservoir scheduling diagram, and the scheduling process has the mindset that less water abandonment will definitely increase power generation; (3) The power station has a phenomenon of eating up the next year's grain in the current year to ensure the safe operation of the power grid; (4) The policy requires flood control and flood safety, which keeps the reservoir water level low.

[0170] Although the actual water utilization rate is higher than the long series calculated value in the same period, it is still lower than the power generation in the conventional scheduling diagram. The key reason is that the low head operation causes the water consumption rate of power generation to be relatively high.

[0171] 2. Calculation and Analysis of Long Series of Conventional Scheduling Charts

[0172] Based on the runoff data at the Ankang Reservoir dam site, Figure 3The long series regulation calculation of the conventional dispatching diagram in the paper shows that the average power generation of Ankang Hydropower Station over the years is 27.66kW·h. The water level during the water supply period is analyzed and studied at 0.3, 0.4, 0.5, and 0.6 times the installed capacity (i.e., the local optimized water supply period curve). The power generation is different. In order to facilitate the analysis and application of the results of the optimal dispatching line calculation, the conventional dispatching Figure 5 The group lines (upper limit, lower limit, and 3 groups of basic lines) are used as water level control lines, and the calculated power generation and guarantee rate are obviously different, among which the upper limit power generation is the largest rather than the upper basic line.

[0173] 3. Solving the Optimal Scheduling Line of the Scheduling Diagram Model

[0174] The reservoir scheduling diagram model of the present invention uses 72 years of reservoir and unit characteristic data to perform a long-term optimization calculation, resulting in the water level at the end of the 36th decade of the year. This is the scheduling line that maximizes the objective function within the allowable water level range during the operating period. For ease of description and to distinguish it from conventional scheduling diagrams, reservoir scheduling diagrams generated using the present invention's method will be referred to as new scheduling diagrams.

[0175] Aiming at the problem that the optimal dispatching line obtained by long series optimization can only guarantee the overall optimality of the objective function but cannot guarantee the optimality under the annual water inflow conditions, an auxiliary dispatching line is introduced to solve the problem. The auxiliary dispatching line is to scale the 72-year runoff process by 0.5 to 2.0 times and then optimize and calculate it again. In essence, it is also the optimal dispatching line of the corresponding runoff series after the runoff series is reduced or expanded. This paper focuses on the auxiliary dispatching lines of 0.5 (extremely dry), 0.8 (20% dry), 1.2 (20% abundant), and 2.0 (extremely abundant) times of the runoff series (0.5 to 2.0 times basically covers all the runoff processes entering the reservoir). The auxiliary dispatching lines derived from the extremely dry and abundant water years are basically the highest water level line (upper limit) and the lowest water level line (lower limit) controlled by the power station in each period of future operation. The new dispatching diagram consists of the optimal dispatching line (1.0 times) and auxiliary dispatching lines of 0.5 times, 0.8 times, 1.2 times, and 2.0 times, such as Figure 4 shown.

[0176] As shown in Table 1, the optimal dispatching and auxiliary dispatching lines for the Ankang Hydropower Station exhibit a regularity in their timing, consistent with its three-peak and two-valley runoff pattern. The three peaks are the summer rainstorms and floods from late June to mid-July, the autumn floods in September, and the peach blossom flood from mid-April to May. The two valleys are the summer drought from late July to early August and the relatively dry period in early and mid-June following the peach blossom flood. The water level in July should be controlled between 315 and 325 meters. The 0.5-fold extreme low-water line (yellow line) shows a drop in water level after the start of the water supply season to ensure output due to extremely low inflow. The water level recovers with the arrival of the peach blossom flood in April and May. The derived auxiliary dispatching line conforms to the water level control pattern of reduced and expanded runoff, meaning that during dry years, the water level should be higher during the flood season and lower during wet years. The 2-fold water inflow auxiliary dispatching line is a year with particularly abundant water inflow. The water level of Ankang Reservoir needs to be reduced to 305m at the end of June and the end of early September. This is in line with the operating law that the reservoir water level should be lowered in abundant water years, so that power can be generated in advance to reduce water abandonment and increase power generation. In dry years, the water level of the corresponding auxiliary dispatching line should be controlled at a higher level.

[0177] Table 1. Optimal dispatching line water level of Ankang Reservoir (beginning of ten-day period)

[0178]

[0179] In the runoff regulation calculation, the maximum water level of 330m is used to ensure that the power generation flow is 190m 3 / s, the dead water level is 305m, and the water level guarantees the output power flow of 270m 3 / s, both greater than the ecological flow rate of 80m 3 / s, ecological flow does not affect the model solution.

[0180] IV. Comparison of the Long Series of Conventional Scheduling Diagrams with the New Scheduling Diagram of the Present Invention

[0181] like Figure 5 As shown in the figure, according to the optimal dispatch line in the new dispatch diagram as the target water level control line, the water energy calculation of 72 years of ten-day runoff data was carried out, and the average annual power generation of Ankang Hydropower Station was deduced to be 2.905 billion kW·h. Compared with the power generation of 2.766 billion kW·h deduced from the conventional dispatch diagram, the power generation increased by 139 million kW·h, an increase rate of 5%, and the guarantee rate increased by 8% (the guarantee rate of the new dispatch diagram reached 98%). In 70 of the 72 years, the power generation generally increased by 1-10%. Only in 1957 (when the water flow was relatively abundant in mid-July) and 2013 (when the water flow was relatively abundant in mid- and late July) did the power generation decrease by 0.39% and 0.19%, respectively. In the long series calculation, the water consumption rate and water abandonment rate of the conventional and the new dispatch diagrams of the present invention were 5.47m 3 / kW·h、5.12m 3 / kW·h and 16.2% and 17.6% respectively. The optimal dispatch line of the new dispatch diagram of the present invention has a minimum water drawdown level of 315.53m at the end of the year, which is 10.53m higher than the minimum water drawdown level of 305m in the conventional dispatch diagram. The scientific control of the reservoir water level balances the water consumption rate for power generation and the water abandonment rate. This is the result of optimization based on the objective function, and the efficiency improvement is very significant.

[0182] The new scheduling diagram (optimal scheduling line and auxiliary scheduling line) of the present invention can maximize the power generation efficiency of the reservoir. It is simple to use and can further improve the operating indicators (power generation, guarantee rate) in the dry year compared with the conventional scheduling diagram, and provides the staged water level control target during the flood season.

[0183] 5. Comparison and Analysis of the Operation Process of the Typical Annual Routine and the New Dispatch Diagram of the Present Invention

[0184] As shown in Table 2, Figure 6-11 As shown, a typical year is calculated using the conventional scheduling diagram and the new scheduling diagram of the present invention respectively.

[0185] Table 2 Operation results of the conventional dispatching diagram and the new dispatching diagram of the present invention in a typical year

[0186]

[0187] In a typical dry year, the power generation calculated by the optimal dispatch line of the conventional dispatch diagram and the new dispatch diagram of the present invention is 2.482 billion kW·h and 2.622 billion kW·h respectively, and the power generation is increased by more than 5.67% (without considering the water level and electricity at the end of the year). The water level controlled by the new dispatch diagram at the end of the year is higher than that of the conventional dispatch diagram. Figure 8 0.31m above. 0.8 times auxiliary dispatch line is activated, and the water inflow is 14.5 billion m 3 , equivalent to 0.8 times the normal water supply), the power generation was 2.637 billion kW·h, an increase of 155 million kW·h, and the total increase rate was 6.24%.

[0188] In a typical year with normal water flow, the power generation calculated by the conventional dispatching diagram and the optimal dispatching line of the new dispatching method of the present invention is 2.661 billion kW·h and 2.679 billion kW·h respectively. The water level controlled by the optimal dispatching line at the end of the year is higher than that of the conventional dispatching diagram. Figure 8 .31m, the reservoir capacity difference can make up for the electricity consumption by about 92 million kW·h, the additional power generation can be about 110 million kW·h, and the power generation can be increased by about 4.13%.

[0189] In a typical flood year, the power generation calculated by the conventional scheduling diagram and the new scheduling optimal scheduling line of the present invention are 3.21 billion kW·h and 3.289 billion kW·h respectively. The reservoir capacity difference compensation power generation is about 0.95 billion kW·h, the additional power generation is about 174 million kW·h, and the power generation is increased by about 5.42%.

[0190] Compared to conventional scheduling diagrams, the new scheduling diagrams of the present invention significantly increase power generation, whether for long-term series or typical years (abundant, average, or dry). This is primarily due to the new scheduling model increasing the reservoir water level. While this increases water rejection, it significantly reduces the water consumption of units operating at high head. Operating according to the optimal scheduling line ensures maximum overall power generation over many years. When operating according to meteorological runoff forecasts and using auxiliary scheduling lines, power generation can be increased in specific years with incoming water.

[0191] 6. How to use the new scheduling diagram

[0192] The new dispatching diagram of the present invention is simple and straightforward to use. Without considering rainfall and runoff forecasts, the optimal dispatching line of the new dispatching diagram is the reservoir's staged water level process line, which is the target control water level for each period of reservoir operation. Operation is kept as close to the optimal dispatching line as possible while meeting guaranteed output. When moving away from the optimal dispatching line, the target water level should be promptly restored while meeting guaranteed output. Guaranteed output is achieved as long as it is above the dead water level. The new dispatching diagram of the present invention clearly defines the water levels at the beginning and end of each period, and power plant operations can be arranged according to its instructions, allowing for the creation of various power generation plans.

[0193] When considering the forecast, the weather forecast results for the period are combined, and the average flow rate for the period is used as a reference. For example, when the flow rate for the next period is predicted to be 20% lower than the average flow rate, the water level at the end of this period is controlled at 0.8 times the auxiliary scheduling line. When the runoff for the next period is predicted to be 2 times higher than the average runoff for the period, the water level at the end of this period is controlled at 2.0 times the auxiliary scheduling line. As long as it is higher than the dead water level, the output should be guaranteed.

[0194] The common problem of ten-day runoff homogenization in both conventional reservoir scheduling diagrams and the novel reservoir scheduling diagrams of the present invention requires the development of short-term runoff forecasts in conjunction with relatively accurate 3-5 day weather forecasts. The novel reservoir scheduling diagrams of the present invention continuously improve water level control. Incorporating 10-20 day rainfall forecasts and controlling water levels in future periods according to optimal scheduling lines and auxiliary scheduling lines will be an important way to efficiently utilize water resources and increase power generation.

[0195] 7. Characteristics of the New Scheduling Diagram

[0196] The novel reservoir scheduling diagram of this invention is a set of time-dependent water-level control lines closely tied to runoff characteristics, power plant installed capacity, guaranteed output, equipment efficiency (energy losses in generators, turbines, transformers, and the water transmission system), and beneficial reservoir capacity. Changes in runoff characteristics (variations in upstream water intake and replenishment), reservoir siltation, power plant equipment upgrades (capacity increases and equipment replacements to improve efficiency), and capacity expansion can all lead to changes in the novel scheduling diagram (optimal scheduling lines and auxiliary scheduling lines).

[0197] The novel dispatching diagram of the present invention is divided into two areas, upper and lower, by a 1.0 times optimal dispatching line. The lower area is the water level operation area during the flood period, and the upper area is the water level operation area during the dry period.

[0198] The characteristics of the novel dispatching diagram of the present invention are shown in Table 3. When operating according to the derived optimal dispatching line, reducing the guaranteed output increases power generation and improves the guaranteed rate; conversely, increasing the guaranteed output reduces power generation and reduces the guaranteed rate. When the power plant's generating units are increased in capacity or expanded, the guaranteed output increases, and the optimal dispatching line is re-derived. The optimal dispatching line for the main flood season and the auxiliary dispatching line will be raised.

[0199] Table 3 Relationship between guaranteed output and guaranteed power generation of the new dispatching diagram of the present invention

[0200]

[0201] 8. Features of the New Scheduling Diagram of the Present Invention

[0202] The new scheduling diagram of the present invention determines the water level control target at the end of the time period based on the runoff characteristics of the basin, the characteristic parameters of the hydropower station, and the results of short- and medium-term meteorological and hydrological forecasts, thereby formulating the reservoir operation mode for the current time period. Conventional scheduling diagrams formulate the reservoir operation mode for the current time period based on the interval where the water level at the beginning of the time period is located, and there is no future water level control target. During the application of the new reservoir scheduling diagram of the present invention, the water level is operated at a higher level during the dry period and the water level is promptly lowered during the flood period, which is consistent with reality. It is an operation mode that fully reflects the combination of the characteristics of the hydropower station units and the runoff characteristics of the basin, and better meets the actual operation guidance needs of the hydropower station.

[0203] The novel reservoir scheduling system of the present invention enables safe and economical operation, suitable for all types of inflow during flood, normal, and dry seasons. Using forecasts for scheduling provides better results, particularly improving various indicators in dry years. Conventional scheduling charts offer a simple, intuitive, and safe method of operation, making them particularly suitable for operation in flood years.

[0204] In addition to improving power generation efficiency, the new scheduling model of the present invention also increases the guaranteed output rate. A comparative analysis of the three driest years for inflow into the Ankang Reservoir—July 1959-June 1960, July 1997-June 1998, and July 1999-June 2000—shows that conventional scheduling patterns were breached for 7, 23, and 22 consecutive days, respectively, while the new scheduling pattern of the present invention was breached for 0, 13, and 0 days, respectively. This significantly reduces the guaranteed output breach rate of the new scheduling pattern, demonstrating a clear advantage.

[0205] The optimal dispatching line of the new dispatching diagram of the present invention is significantly different from the increased output line of the conventional reservoir dispatching diagram. The increased output line of the conventional reservoir dispatching diagram is obtained by reverse calculation (forward calculation during the flood season) from the annual drawdown water level (multi-year regulation reservoir) or the dead water level (annual regulation reservoir), while the optimal dispatching line is obtained by searching for the best value within the range of water levels available during the entire period. One of the most important achievements of the optimal dispatching line of the Ankang Reservoir is the optimization of the annual drawdown water level, which is 10.53m higher than the lowest drawdown water level of the conventional dispatching diagram (water level 315.53m). This water level is close to the corresponding design head, which increases the peak-shaving capacity of the unit and makes it easy for the unit to reach rated output operation. In historical data and actual reservoir operation over the years, there was water abandonment in June but the probability was very small. There were also many years when no water abandonment occurred in July when the main flood season began. According to conventional dispatching Figure 6 It basically drops to the dead water level at the end of the month, and it takes a long time for the dead water level to reach the rated output. When it drops to the dead water level and encounters a dry year, the reservoir can only operate at a low water level for a long time. This is the biggest flaw in the conventional scheduling diagram.

[0206] Comparing the new scheduling diagram of the present invention, the difference in the ten-day average power generation between the two in June and July is significant, which is a key reason why the optimal scheduling line generates more power than the conventional one. The optimal scheduling line comprehensively improves the operating water level in all time periods, significantly reducing the water consumption rate for power generation. Although the amount of water discarded increases in some periods, the overall power generation efficiency is greatly improved. This is significantly different from the conventional scheduling diagram's one-sided pursuit of reducing water discard to increase power generation.

[0207] In summary, the new scheduling diagram model of the present invention can serve as a new tool for the economic operation of hydropower station reservoirs, replacing conventional scheduling diagrams and increasing reliability and economy. The new reservoir scheduling diagram with the optimal scheduling line as the core is essentially different from the conventional scheduling diagram, and its theoretical basis, objective function, and solution process are significantly different. In addition, the application operation is simple, easy to use, and has higher economic benefits. Reservoirs with regulatory performance can all solve the new scheduling diagram with the optimal scheduling line as the core. Reservoirs that are not primarily used for power generation can be analyzed and solved by changing the objective function.

[0208] Furthermore, the novel scheduling diagram model of this invention can be used for staged water levels, providing a clear end-of-period water level control target. The optimal scheduling line can be used as the staged water level control line. When forecasts are not considered, it can be used as the end-of-period target water level. When forecasts are considered, it can be combined with auxiliary scheduling lines to control the water level. This novel reservoir scheduling diagram can improve guaranteed output and design guarantee rates. Cascade reservoirs on the same river have similar runoff characteristics, so the optimal scheduling lines should have a high degree of similarity.

[0209] The above description is only a specific embodiment of the present invention, but the scope of protection of the present invention is not limited thereto. Any modifications, equivalent substitutions and improvements made by any technician familiar with this technical field within the technical scope disclosed by the present invention and within the spirit and principles of the present invention should be covered by the scope of protection of the present invention.

Claims

1. A method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line, characterized by: include: Construct a reservoir operation diagram model; The reservoir and unit characteristic data are used as the input of the reservoir operation diagram model, and the optimal operation line and auxiliary operation line are solved by sine-cosine-particle swarm algorithm to draw the reservoir operation diagram.

2. The method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to claim 1, characterized in that: The construction of the reservoir operation diagram model specifically includes: Construct the objective function; Determining constraints of the objective function; Based on the objective function and constraints, and taking the reservoir water level at the end of ten days as the decision variable, a reservoir scheduling diagram model is constructed.

3. The method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to claim 2, characterized in that: The objective function specifically includes: Where, E is the total power generation; n is the total number of study periods; N t A is the power output of the power station during the period; t is the comprehensive output coefficient of the time period; H t is the period water head; q (f,t) is the power generation flow during the period; Δ t is the length of the time period; W 发t W is the amount of water generated during the period; 入t W is the amount of water entering the reservoir during the period; 弃t is the amount of water abandoned during the period; ΔV is the change in storage capacity during the period; u t is the water consumption rate during the period; V t is the initial storage capacity (water storage capacity) of the time period; V t+1 is the reservoir capacity (water storage) at the end of the period.

4. The method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to claim 2, characterized in that: The constraints specifically include: System water balance constraints: V t+1 =V t +[Q t -q (f,t) -q (q,t) ]*Δ t (16) Where V t is the initial reservoir capacity during period t; V (t+1) is the reservoir capacity at the end of period t; Q t is the inflow of the reservoir during period t; q (f,t) is the power generation flow of the reservoir during period t; q (q,t) is the water discharge of the reservoir during period t; Water level constraint: Where, is the upper water level constraint of the reservoir in period t; is the lower limit water level constraint of the reservoir in period t; Storage capacity constraints: V t min <V t <V t max (18) Where V t min is the upper limit storage capacity constraint of the reservoir in period t; V t max is the lower storage capacity constraint of the reservoir in period t; Output constraints: Where, is the minimum allowable output of the hydropower station at each water head in period t; is the maximum allowable output of the hydropower station at each water head in period t; Maximum overcurrent capacity constraint: Where q t is the total outflow of the reservoir in period t; is the maximum allowable outflow of the reservoir in period t; Ecological flow constraints: Where q t is the total outflow of the reservoir in period t; is the minimum ecological discharge flow of the reservoir; Guaranteed output and guaranteed rate constraints: N t ≥N p ;P≥90% (22) Where N p is the guaranteed output of the hydropower station; P is the guaranteed rate of the hydropower station; Penalty function: E = E*(P+0.1) (23) If the calculated power generation guarantee rate is less than 90%, a penalty function is used to constrain it.

5. The method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to claim 1, characterized in that: The reservoir and unit characteristic data include but are not limited to runoff, water level and storage capacity curve, downstream flow tail water level curve, and unit power generation characteristic curve.

6. The method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to claim 1, characterized in that: The method of drawing a reservoir operation diagram by solving the optimal operation line and the auxiliary operation line by using the sine-cosine-particle swarm algorithm specifically includes: The sine-cosine-particle swarm algorithm is used to optimize the reservoir operation diagram model and obtain the optimal operation line; By magnifying and reducing the long series of ten-day runoff according to the same multiple of different water inflow frequencies, and then using the sine-cosine-particle swarm algorithm for optimization calculation, the auxiliary dispatching lines corresponding to different water inflow frequencies can be obtained. A reservoir scheduling diagram is drawn according to the optimal scheduling line and the auxiliary scheduling lines corresponding to the different water inflow frequencies.

7. The method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to claim 6, characterized in that: The sine-cosine-particle swarm algorithm is used to optimize the reservoir operation diagram model to obtain the optimal operation line, which specifically includes: Randomly generate scheduling lines based on constraints; Solve the objective function value corresponding to each scheduling line; The scheduling line is updated using the sine-cosine-particle swarm algorithm; Repeat the process of solving the objective function value of the scheduling line and updating the scheduling line until the maximum number of iterations is met. The scheduling line corresponding to the maximum objective function value is the optimal scheduling line.

8. The method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to claim 6, characterized in that: The long series of ten-day runoff is magnified or reduced by 0.5 to 2.0 times according to different water inflow frequencies.

9. A reservoir scheduling diagram drawing system based on the optimal power generation scheduling line, characterized by: include: Model building module: building reservoir operation diagram model; Model solving module: The reservoir and unit characteristic data are used as the input of the reservoir scheduling diagram model, and the optimal scheduling line and auxiliary scheduling line are solved by the sine cosine-particle swarm algorithm to draw the reservoir scheduling diagram.

10. A device for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line, characterized by: include: Memory: used for storing a computer program for implementing a method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line according to any one of claims 1 to 8; Processor: configured to implement a method for drawing a reservoir scheduling diagram based on an optimal power generation scheduling line as described in any one of claims 1 to 8 when executing the computer program.

Images