Hydrogen-containing energy storage system optimization scheduling method considering carbon capture power plant

Abstract

The invention discloses a hydrogen-containing energy storage system optimization scheduling method considering a carbon capture power plant. The method comprises the following steps: analyzing cooperative operation characteristics of a carbon capture unit and a hydrogen energy storage system; according to a hydrogen energy storage operation principle, establishing a hydrogen energy storage output model; introducing a hydrogen energy storage output model, and constructing a hydrogen energy storage-carbon capture combined operation low-carbon scheduling model considering a carbon transaction mechanism; the method comprises the following steps of: selecting unit output as a decision variable, taking system comprehensive cost optimization as a target, considering uncertainty of unit operation constraint, system safety constraint, wind power output and load output, and solving a low-carbon scheduling model; according to the model provided by the invention, the economical efficiency and the low-carbon property of system operation are considered, and the consumption level of new energy is effectively improved.

Description

Technical Field

[0001] The present invention relates to the field of power system optimization and scheduling, and in particular to a method for optimizing and scheduling a hydrogen-containing energy storage system taking into account a carbon capture power plant. Background Art

[0002] The latest data as of 2023 shows that China's thermal power generation accounts for 69.95% of the country's total power generation. Although conventional thermal power units have significant carbon emissions, other regulating equipment has not yet been able to completely replace their core position in power supply, which fully demonstrates that thermal power still plays a vital role in the current power energy structure. With the increasing global attention to green and low-carbon industrial production, how to effectively slow down the continuous deterioration of the greenhouse effect has become an urgent task faced by the world. The power industry has an unshirkable responsibility in improving the clean level of coal-fired units.

[0003] On the source side, carbon capture and storage (CCS) technology is used to convert traditional thermal power units into units with carbon capture function. As a transitional equipment in the process of energy structure transformation, this measure has shown significant results in achieving low-carbon electricity.

[0004] At present, the scale of installed capacity of new energy sources is constantly increasing. However, wind power generation is characterized by strong randomness and volatility, and has anti-peaking characteristics. Large-scale wind power grid connection will significantly increase the peak-shaving pressure of the power system, and problems such as frequent wind abandonment and high pressure of rotating reserve will occur, which may even affect the stable operation of the system. This situation will cause carbon capture units to frequently participate in peak-shaving, further increase coal-fired costs and start-up and shutdown costs, thereby weakening the economy and environmental protection of carbon capture units. Therefore, it is particularly important to fully coordinate the dispatchable resources of sources, loads and storage to realize the consumption of new energy for the low-carbon operation of the power system.

[0005] In terms of energy storage, hydrogen energy storage, as a new form of energy storage, has the advantages of large-scale storage and clean and pollution-free. The wind-hydrogen combined power generation system formed by combining with wind power can effectively alleviate the problem of wind abandonment. Research on various application methods of hydrogen energy storage systems other than energy time shifting is of great significance to the development of hydrogen energy. The hydrogen energy storage system has a fast adjustment speed and can flexibly adjust the output to undertake the system's rotating standby tasks, thereby reducing the rotating standby burden of thermal power units. However, due to the high construction cost and limited capacity of hydrogen energy storage, it cannot fully undertake the system's rotating standby tasks alone and still needs to be used in conjunction with other backup equipment.

[0006] On the load side, guiding users' electricity consumption behavior through price signals can alleviate the regulation pressure on the source side and energy storage devices, and improve the new energy consumption capacity during the off-peak period. Under the dual carbon goals, demand response can be coordinated with other adjustable resources to further optimize system performance.

[0007] In summary, the coordinated optimization of the three sides of source, load and storage is of great significance to the realization of low-carbon economic operation of the power system, but the carbon capture unit on the source side is still subject to the spinning reserve constraint, and the adjustable range is limited. Affected by the conversion efficiency of hydrogen energy storage itself, it is difficult to give full play to its new energy consumption potential by only considering the energy time shift characteristics for low-carbon economic dispatch. After considering the equivalent spinning reserve characteristics of hydrogen energy storage, the spinning reserve allocation plan between the carbon capture unit with excellent low-carbon performance needs to be studied in depth; in low-carbon economic dispatch, the impact of the load-side resources on the dispatch results after the coordinated operation of source and storage has not been fully explored, and other issues need to be solved. Summary of the invention

[0008] In order to solve the problem of low conversion efficiency of hydrogen energy storage system and reduce carbon emissions of power generation system, a clean energy system is constructed. The present invention provides a method for optimizing the scheduling of hydrogen-containing energy storage system taking into account carbon capture power plants. The method introduces wind power, hydrogen energy storage system and carbon capture equipment into the power system. In order to solve the problem of low conversion efficiency of hydrogen energy storage system, the present invention considers the equivalent rotating standby characteristics of hydrogen energy storage in operation to improve energy utilization efficiency. In order to solve the problem of difficulty in reducing output of carbon capture unit during off-peak period and limited regulation capacity of hydrogen energy storage system, the coordinated operation characteristics of source-side carbon capture unit and hydrogen energy storage system are analyzed, and the system performance is further optimized through load-side demand response to improve the stability and economy of system operation.

[0009] The technical solution adopted by the present invention is:

[0010] A method for optimizing the scheduling of a hydrogen-containing energy storage system taking into account a carbon capture power plant comprises the following steps:

[0011] Step 1: Analyze the coordinated operation characteristics of the carbon capture unit and the hydrogen energy storage system;

[0012] Step 2: Establish a hydrogen energy storage output model based on the operating principle of hydrogen energy storage;

[0013] Step 3: Introduce the hydrogen energy storage output model and build a low-carbon dispatch model for hydrogen energy storage and carbon capture combined operation considering the carbon trading mechanism.

[0014] Step 4: Select unit output as the decision variable, take the optimization of system comprehensive cost as the goal, and consider the unit operation constraints and system safety constraints as well as the uncertainty of wind power output and load output, and solve the low-carbon scheduling model.

[0015] In the step 1, the coordinated operation characteristics of the carbon capture unit and the hydrogen energy storage system are analyzed;

[0016] The net output adjustment range of the conventional thermal power part of the carbon capture unit is:

[0017]

[0018] In formula (1): P Jc,t is the net output of the carbon capture unit during period t; They are the upper and lower limits of the output power of the conventional thermal power part of the carbon capture unit;

[0019] Under the comprehensive flexible operation mode, the carbon capture unit can reduce the net output of the power plant by increasing the amount of carbon dioxide captured during the off-peak period, and has a wider adjustment range than conventional thermal power units;

[0020]

[0021] In formula (2), λ is the energy consumed to capture unit CO2; η is the carbon capture efficiency; δ max is the maximum smoke split ratio during period t; m c is the carbon emission intensity of the carbon capture unit; P D Fixed energy consumption for the carbon capture unit.

[0022] Thermal power units need to reserve sufficient spinning reserve capacity to cope with the uncertainty of load and renewable energy output. The spinning reserve constraints of carbon capture units under flexible transformation are as follows:

[0023]

[0024] In formula (3): U c,t The start and stop status of the carbon capture unit during period t; Spinning reserve capacity up and down for carbon capture units; are the up and down ramp rates of the carbon capture unit respectively; the standby model proposed in the present invention is a 10-min rotating standby, and the value of Δt is 10 min.

[0025] The regulation range of the carbon capture unit under the spinning reserve demand is:

[0026]

[0027] In step 2, the hydrogen energy storage output model is as follows:

[0028]

[0029] In formula (5), P el,t , P elH,t are the input and output power of the electrolyzer during period t; η el is the electrolytic cell efficiency; E hs,t 、E hs,t-1 are the energy stored in the hydrogen storage tank at time t and t-1 respectively; P fcH,t , P fc,t are the fuel cell input and output power in period t respectively; η fc for fuel cell efficiency.

[0030] The step 3 comprises:

[0031] 1: Construct a low-carbon dispatch model for the combined operation of hydrogen energy storage and carbon capture taking into account the carbon trading mechanism, with the minimum system comprehensive cost as the objective function;

[0032] F=min(F p +F o +F v +F y +F s +F b +F q ) (9);

[0033] In formula (9), F is the comprehensive cost of the power system; F p F is the power generation cost of thermal power units; o F is the start-up and shutdown cost of thermal power units; v is the solution loss cost; F y is the carbon trading cost; F s F is the operation and maintenance cost of hydrogen energy storage; b is the standby cost; F q is the cost of power loss;

[0034] 1) Generator power generation cost:

[0035]

[0036] In formula (10), T is the dispatch period; n is the number of thermal power units; P Hi,t is the power generation capacity of the thermal power unit during period t; a i , b i , c i is the power generation cost coefficient of the i-th thermal power unit;

[0037] 2) Start-up and shutdown costs of thermal power units:

[0038]

[0039] In formula (11), U i,t , U i,t-1 are the start and stop states of the i-th thermal power unit in period t and period t-1 respectively; S g,i is the start-up and shutdown cost of the i-th unit;

[0040] 3) Solution loss cost:

[0041]

[0042] In formula (12): K s is the cost coefficient of ethanolamine solution; is the solution operation loss coefficient; EJc,t is the amount of CO2 captured by the carbon capture unit during period t;

[0043] 4) Carbon trading costs:

[0044]

[0045] In formula (13): c tj is the carbon trading price; E c all is the total carbon emissions of the system; σ is the carbon trading quota;

[0046] 5) Hydrogen energy storage operation and maintenance costs:

[0047]

[0048] In formula (14): c el 、c fc are the unit operation and maintenance cost coefficients of electrolyzer and fuel cell respectively; P el,t is the input power of the electrolytic cell during period t; P fc,t are the fuel cell output power during period t respectively.

[0049] 6) Spinning reserve cost:

[0050] The system spinning reserve cost is shown in formula (15). References to the reserve cost of thermal power units [1]: Zhang Yaoxiang Optimization method of solar thermal power generation-thermal power spinning reserve in high-proportion wind power access system [J]. Transactions of the Chinese Society of Electrical Engineering, 2022. Hydrogen energy storage uses abandoned wind to produce hydrogen, and the spinning reserve cost is less than the reserve cost of thermal power units. The electrolyzer reserve cost is approximately replaced by the operation and maintenance cost;

[0051]

[0052] In formula (15), k represents the kth type of equipment, N m To provide a rotating reserve equipment assembly, including conventional thermal power units, carbon capture units and hydrogen energy storage systems; The upper and lower spinning reserve cost coefficients of the kth type of equipment respectively; They are the upper and lower spinning reserve capacities provided for the k-th type of equipment during period t;

[0053] 7) Power loss cost:

[0054] The power loss comes from the wind power abandonment loss and the power loss caused by the low conversion efficiency of the hydrogen energy storage system in the process of absorbing the abandoned wind. The two types of power loss are uniformly measured by the penalty cost of new energy abandonment;

[0055]

[0056] In formula (16): are the wind power forecast value, actual grid-connected power and abandoned wind power in period t respectively; c w Penalty cost factor for wind curtailment;

[0057]

[0058] In formula (17): c w Penalty cost factor for wind curtailment; is the wind power abandoned during period t; el is the electrolytic cell efficiency; η fc for fuel cell efficiency.

[0059] 2: Construct unit operation constraints and system safety constraints:

[0060] (1): Power balance constraint:

[0061]

[0062] In formula (18): P Ji,t is the net output power of the i-th thermal power unit; is the load size in period t after demand response.

[0063] (2): Operation constraints of thermal power units:

[0064]

[0065] In formula (19): U i,t is the start / stop status of the i-th thermal power unit during period t; are the upper and lower limits of the output power of the i-th thermal power unit respectively;

[0066] (3): Constraints on new energy output:

[0067]

[0068] In formula (20): is the wind power forecast value during period t;

[0069] (4): Spinning reserve constraints:

[0070] a. Thermal power unit standby constraints:

[0071]

[0072] In formula (21) and formula (22): are the upper and lower spinning reserve capacities undertaken by the i-th thermal power unit respectively; are the up and down ramp rates of the i-th thermal power unit respectively;

[0073] b. Constraints on equivalent spinning reserve of electrolyzers:

[0074]

[0075] In formula (6), P el,t E is the input power of the electrolytic cell during period t; hs,t The energy stored in the hydrogen storage tank during period t; They are the upper and lower spinning reserve capacities provided for the electrolyzer during period t respectively; is the rated capacity of the electrolyzer; is the upper limit of the storage capacity of the hydrogen storage tank; X t The start and stop status of the electrolytic cell equipment. When it is 1, it means the equipment is started, and when it is 0, it means the equipment is shut down;

[0076] In the startup state, the fuel cell equivalent spinning reserve constraints are as follows:

[0077]

[0078] In formula (7), P fc,t is the input power of the fuel cell during period t; E hs,t The energy stored in the hydrogen storage tank during period t; are the upper and lower spinning reserve capacities provided by the fuel cell during period t, respectively; is the rated capacity of the fuel cell; Y is the lower limit of the storage capacity of the hydrogen storage tank; t The start and stop status of the fuel cell equipment;

[0079] In the shutdown state, the fuel cell equivalent spinning reserve constraints are as follows:

[0080]

[0081] c System spinning reserve constraints:

[0082] According to the method of literature [2]: Xiong Hu. Research on fuzzy opportunity constrained unit commitment with large-scale intermittent power sources [J]. Proceedings of the CSEE, 2013., the spinning reserve constraints under triangular fuzzy parameters are converted into clear equivalence classes;

[0083]

[0084] In formula (23), The upper spinning reserve capacity assumed by the k-th type of equipment during period t; is the load size in period t after demand response are the fuzzy expressions of wind power and load forecast errors respectively; Cr{} is the confidence expression; α is the confidence level of satisfying the system spinning reserve constraint;

[0085]

[0086] In formula (24), is the spinning reserve capacity borne by the kth type of equipment during period t.

[0087] Other constraints include:

[0088] 1). Carbon capture power plant constraints:

[0089] The carbon dioxide capture process is performed by the carbon capture unit. This mechanism causes the grid-connected power of the carbon capture unit to be constrained by the capture energy consumption. In this scenario, the mathematical model of the carbon capture unit in the comprehensive flexible operation mode is as follows:

[0090]

[0091] In formula (25), P D is the fixed energy consumption of the carbon capture unit; λ is the energy consumed to capture unit CO2; E Jc,t is the amount of CO2 captured by the carbon capture unit during period t; m c is the carbon emission intensity of the carbon capture unit; γ is the energy consumed to capture unit CO2; P Hc,t is the power output of the carbon capture unit during period t; P B,t is the energy consumption of carbon capture; P r,t The energy consumed by the unit in the carbon capture process during period t; E c,t is the amount of CO2 captured by the carbon capture unit during period t; E v,t V is the amount of CO2 provided by the liquid storage tank during period t; ca,t M is the volume of solution that needs to be prepared by the liquid storage tank to meet the CO2 supply demand during period t; V and are the molar masses of ethanolamine solution and carbon dioxide, respectively; θ is the amount of analysis in the regeneration tower; ρ v is the concentration of alcoholamine solution; δ v is the density of the alcoholamine solution;

[0092] 2) Hydrogen energy storage system constraints:

[0093]

[0094] In formula (26), is the rated capacity of the electrolyzer; are the maximum and minimum values ​​of the energy stored in the hydrogen storage tank; E hs,t The energy stored in the hydrogen storage tank during period t; is the rated capacity of the fuel cell, Rated capacity of electrolyzer during the period, P el,t The input power of the electrolyzer during period t; E hs,0 、Ehs,T The hydrogen storage capacity of the hydrogen storage tank at the initial moment and the final moment; is the maximum input power of the electrolyzer during period t; is the maximum output power of the fuel cell during period t;

[0095] 3) Demand response constraints:

[0096] When the demand response mechanism operates, the load is redistributed by adjusting the user's electricity consumption behavior. This process ensures that the total load remains constant before and after the transfer.

[0097]

[0098] In formula (27), is the predicted value of load; is the load size in period t after demand response; T is the dispatch period;

[0099] 4). Uncertain constraints on wind power and load output:

[0100] The triangular fuzzy membership function is used to describe the uncertainty of wind power and load output:

[0101] H = (S1, S2, S3) (28);

[0102] In formula (28), H is the membership function; S1 is the lower limit of the parameter; S2 is the historical statistical data; S3 is the upper limit of the parameter;

[0103] The prediction errors of wind power generation and load are used as fuzzy parameters to characterize the uncertainty characteristics of their respective outputs. The specific model construction of the fuzzy parameter is as follows:

[0104]

[0105] In formula (29), The wind power forecast error is The load prediction error, is the wind power forecast value in period t, The predicted value of load during period t, k 1w , k 3w , k 11 , k 31 is the wind power output and load demand forecast error ratio coefficient. The low-carbon dispatch model of hydrogen energy storage-carbon capture combined operation considering carbon trading includes the above equations (9) to (22), (6) to (8), and (23) to (29).

[0106] In step 4, the low-carbon scheduling model is solved, such as Figure 7 shown.

[0107] The present invention provides a method for optimizing the scheduling of a hydrogen-containing energy storage system taking into account a carbon capture power plant, and the technical effects are as follows:

[0108] 1) The present invention constructs a comprehensive and flexible carbon capture working mechanism. The introduction of the source-side carbon capture unit can reduce the carbon dioxide emissions in the traditional scenario system. At the same time, due to the role of the liquid storage tank, carbon capture and carbon emissions can be decoupled and the amount of new energy grid-connected can be increased.

[0109] 2) The present invention can expand the adjustment range of the carbon capture unit under the demand of rotating standby through the coordinated operation of the carbon capture unit and the hydrogen energy storage system, while reducing the loss of electric energy in the hydrogen energy storage process, thereby improving the energy utilization efficiency.

[0110] 3) The present invention considers the demand response mechanism to form source-load-storage coordinated scheduling, which can further improve the low-carbon and economical operation of the system. At the same time, with the continuous increase in the scale of new energy installed capacity, source-load-storage coordinated scheduling has more advantages in economy and new energy consumption.

[0111] 4) By establishing a low-carbon dispatch model for the combined operation of hydrogen energy storage and carbon capture taking into account carbon trading, the model is compared with conventional thermal power dispatch, non-hydrogen energy storage dispatch strategy, and no-load side electricity demand response, so as to obtain the best economic and environmental benefits relative to other scenarios.

[0112] 5) The present invention takes into account the energy time-shift characteristics and equivalent rotating reserve characteristics of the hydrogen energy storage system and introduces demand response on the load side, which has lower standby costs compared with thermal power units. Within a scheduling cycle, after the introduction of demand response, some conventional thermal power units are shut down during peak periods, and the power generation shortfall is borne by the carbon capture units. The comprehensive cost is reduced by 28.17% and carbon emissions are reduced by 59.%. BRIEF DESCRIPTION OF THE DRAWINGS

[0113] The present invention will be further described below in conjunction with the accompanying drawings and examples;

[0114] Figure 1 Flowchart of a low-carbon dispatch strategy approach for a power grid containing renewable energy and taking into account flexible operation of carbon capture.

[0115] Figure 2 This is a schematic diagram of a flexible operation carbon capture structure according to an embodiment of the present invention.

[0116] Figure 3 It is a schematic diagram of the source-load-storage coordinated operation structure framework of the present invention.

[0117] Figure 4 This is the improved IEEE-30 node wiring diagram.

[0118] Figure 5Schematic diagram of the change in the regulation range of the carbon capture unit under spinning reserve demand.

[0119] Figure 6 This is a flow chart of a low-carbon dispatch strategy for a new energy power grid taking into account flexible operation of carbon capture according to an embodiment of the present invention.

[0120] Figure 7 This is a flow chart for solving the low-carbon scheduling model of the present invention. DETAILED DESCRIPTION

[0121] The present invention takes minimizing the start-up and shutdown costs of thermal power units, solution loss costs, carbon emission trading costs, operation and maintenance costs of hydrogen energy storage, spare capacity costs, and power loss costs as optimization goals, constructs a low-carbon economic dispatch model integrating source, load, and storage, and meets the operating constraints of the system and traditional units. The dispatch model constructed is a mixed integer linear programming problem, and the YALMIP tool in MATLAB is used to solve the low-carbon economic dispatch model.

[0122] The carbon capture system absorbs the flue gas containing CO2 from the tower into the absorption tower. The lean liquid absorbs CO2 and converts it into rich liquid and stores it in the rich liquid storage tank. At this time, the storage tank is equivalent to an energy storage device. The system adjusts the inflow and outflow of the rich liquid storage tank according to the load conditions to control the amount of CO2 being processed by the regeneration tower and the compressor, thereby changing the net output power of the carbon capture unit. The rich liquid containing a large amount of CO2 enters the regeneration tower through the heat exchanger and is heated. After heating, the solution is separated from the CO2. Finally, the separated CO2 is compressed by the compressor for transportation and storage, and the lean liquid after the CO2 is separated returns to the absorption tower for the next stage of capture.

[0123] Considering the energy time-shifting characteristics of the carbon capture unit and the hydrogen energy storage system, the two can complement each other's advantages: the carbon capture unit improves the new energy consumption capacity during the off-peak period through the liquid storage tank, and alleviates the peak-shaving pressure of the hydrogen energy storage system. When the carbon capture unit reaches the lower limit of output during the off-peak period, if there is still surplus electricity that cannot be consumed, the hydrogen energy storage system can use it to absorb the excess electricity. During peak hours, the hydrogen energy storage system can replace the high-cost power generation output of the carbon capture unit by outputting electricity.

[0124] The present invention constructs a low-carbon dispatch model for the joint operation of thermal power, wind power, hydrogen energy storage and carbon capture. Taking carbon trading into consideration, the model incorporates the thermal power generation cost, start-up and shutdown cost, carbon trading cost, carbon capture equipment solution loss cost, hydrogen energy storage operation and maintenance cost, standby cost and power loss cost into the optimization objective function. Constraints include: unit power balance constraint, unit total power output constraint, new energy output constraint, rotating standby constraint, carbon capture power plant constraint, hydrogen energy storage system constraint, demand response constraint, system uncertainty constraint, thermal power unit start-up and shutdown time constraint and ramp constraint, liquid storage tank constraint, carbon capture energy consumption limit constraint, demand response satisfaction constraint and DC power flow constraint, etc.

[0125] A low-carbon dispatch model with wind power and hydrogen energy storage combined operation taking into account carbon capture power plants was established. First, the operating principle of the carbon capture unit with comprehensive and flexible operation and the carbon trading working mechanism were introduced. In view of the limitation of the capacity of the energy storage device of the hydrogen energy storage system, various forms of hydrogen energy storage were explored and the coupling relationship with other power generation equipment was adopted to make carbon capture and hydrogen energy storage energy time-shift characteristics and equivalent rotating standby characteristics match. Constraints were set according to the normal operation of the equipment. Finally, the improved IEEE-30 node system was simulated and compared with the original model. The specific method is as follows:

[0126] (I): Analysis of the three-side operation mechanism of source, load and storage:

[0127] Step 1: Analysis of the operating principle of the source-side carbon capture unit:

[0128] Conventional thermal power units have high carbon emissions, making it difficult to achieve low-carbon operation in the power grid. In terms of energy, conventional thermal power units are low-carbonized and shunting equipment and solution storage equipment are installed on them, so that a carbon capture unit can be established in a comprehensive and flexible operation mode. The CO2 emitted by traditional coal-fired power plants enters the adsorption tower through the flue gas bypass, and then is mixed with the solution and stored in the rich liquid storage tank. When the load is low, the rich liquid will be sent to the regeneration tower for CO2 separation, and then compressed and stored by a compressor. During the production process, carbon capture is controlled in real time through the flue gas bypass equipment, and the liquid storage equipment is able to decouple power generation and carbon capture.

[0129] Step 2: Analysis of the operating mechanism of hydrogen energy storage system:

[0130] Hydrogen energy storage systems include electrolyzers, hydrogen storage tanks, and fuel cells, but the capacity of each device is limited. To this end, it is necessary to manage these devices as a whole to achieve low-carbon and economical operation of the power grid. The application of hydrogen energy storage systems can improve the utilization rate of new energy, thereby effectively reducing carbon emissions. There are two main ways for hydrogen energy storage systems to absorb new energy:

[0131] 1) In terms of energy time-shifting characteristics, the present invention proposes a hydrogen energy storage system similar to conventional energy storage methods, that is, when the output of new energy is large and the load demand is small, the surplus wind power is sent to the electrolytic cell to produce hydrogen, and it is stored in the hydrogen storage tank; when the power of new energy is small and the load demand is large, the hydrogen in the hydrogen storage tank is introduced into the fuel cell, converted into electrical energy and enters the power grid, thereby achieving the purpose of energy time-shifting.

[0132] 2) In terms of equivalent spinning reserve characteristics, hydrogen energy storage systems have the advantage of rapid response, and can provide upper and lower spinning reserves by flexibly adjusting the output power, reducing the spinning reserve demand of thermal power units, reducing the net output of thermal power units, and increasing the access capacity of new energy. Although hydrogen energy storage technology can utilize the time-varying characteristics of energy to promote the consumption of new energy, there is a large amount of power loss in the process, resulting in low energy utilization, which limits the consumption effect of new energy.

[0133] Step 3: Analysis of load-side demand response operation mechanism:

[0134] The load-side regulation resources cannot be ignored. By introducing the load response mechanism, the flexible regulation characteristics of the load-side resources can be improved, the advantages of the load side can be fully utilized, and the purpose of "source-load" interaction can be achieved. The power market demand response based on electricity price guidance, that is, through the guidance of load-side pricing, the load is increased during the off-peak period, the consumption rate of new energy is reduced during the peak period, and the power generation cost of new energy is reduced during the peak period, and a 1-hour power dispatch plan is formulated in the day-ahead stage.

[0135] (II): Study on the coordinated operation characteristics of the three sides of source, load and storage:

[0136] Step a: Source-load-storage coordinated operation architecture:

[0137] On the source side, traditional thermal power units and carbon capture devices that have undergone low-carbon transformation can capture the generated CO2, thereby reducing the carbon emissions on the source side of the power plant. On the load side, the demand response mechanism is used to guide the user's electricity consumption mode and increase the load demand during the off-peak period. In order to improve the absorption rate of wind power, a wind power and hydrogen energy joint power generation system is constructed by combining wind power generation technology with hydrogen energy storage technology. By converting the surplus electricity generated by wind power into hydrogen energy, the utilization efficiency of wind energy can be effectively improved. On this basis, an innovative power generation model is proposed, that is, the hydrogen storage system is operated in conjunction with the thermal power unit to jointly provide electricity. At the same time, the demand response mechanism on the load side coordinates with the carbon capture unit and hydrogen energy storage system on the source side, and changes from "source follows load" to "source, load and storage interaction" to ensure that the power system takes into account both low carbon and economic efficiency during operation.

[0138] Step b: Analysis of the coordinated operation characteristics of the carbon capture unit and the hydrogen energy storage system:

[0139] According to the above analysis, both the carbon capture unit and the hydrogen energy storage system can be used for energy time shifting and undertake part of the system's spinning standby tasks. Therefore, it is necessary to conduct in-depth research on the limitations of their operation and their complementary advantages.

[0140] The net output adjustment range of the conventional thermal power part of the carbon capture unit is:

[0141]

[0142] In formula (1): P Jc,t is the net output of the carbon capture unit during period t; They are respectively the upper and lower limits of the output power of the conventional thermal power part of the carbon capture unit.

[0143] Under the comprehensive flexible operation mode, the carbon capture unit reduces the net output of the power plant by increasing the amount of carbon dioxide captured during the off-peak period, and has a wider adjustment range than conventional thermal power units:

[0144]

[0145] Where: λ is the energy consumed to capture unit CO2; η is the carbon capture efficiency; δ max is the maximum smoke split ratio during period t; m c is the carbon emission intensity of the carbon capture unit; P D Fixed energy consumption for the carbon capture unit.

[0146] Thermal power units need to reserve sufficient spinning reserve capacity to cope with the uncertainty of load and renewable energy output. The spinning reserve constraints of carbon capture units under flexible transformation are as follows:

[0147]

[0148] Where: U c,t The start and stop status of the carbon capture unit during period t; Spinning reserve capacity for carbon capture units; The standby model proposed in the present invention is a 10-minute rotating standby, and the Δt value is 10 minutes.

[0149] The regulation range of the carbon capture unit under spinning reserve demand is

[0150]

[0151] From equations (1) to (4), it can be seen that the net output adjustment range of the source-side carbon capture unit is limited under the demand for rotating reserve, and the carbon capture advantage cannot be fully utilized. In addition, the output is large during peak hours, and the power generation cost is high. In addition, the development of hydrogen energy storage in my country is still in its infancy. Due to the limitation of the capacity of the energy storage device, the hydrogen energy storage system cannot meet the regulation needs of the power system alone, whether it provides rotating reserve or energy time shifting. Exploring various forms of hydrogen energy storage and its coupling relationship with other power generation equipment are issues that need to be solved for the rapid development of hydrogen energy.

[0152] 1) Carbon capture and hydrogen energy storage energy time shift characteristics:

[0153] Due to the anti-peaking characteristics of wind power, the level of wind abandonment is high during the off-peak period of electricity consumption. Considering the carbon capture unit alone, there is a phenomenon of insufficient new energy consumption capacity. In addition, the output of the carbon capture unit is large during the peak period. Although the capture energy consumption limit can reduce the carbon capture energy consumption during the peak period, the load demand keeps its power generation cost at a high level. When only considering the energy time-shifting characteristics of hydrogen energy storage, more electricity is lost during the energy conversion process, the utilization rate of new energy is low, and the wind abandonment effect is not ideal. From the above analysis, it can be seen that considering the energy time-shifting characteristics of the carbon capture unit and the hydrogen energy storage system, the advantages of the two can be complemented: ① The carbon capture unit improves the new energy consumption capacity during the off-peak period through the liquid storage tank, and alleviates the peak-shaving pressure of the hydrogen energy storage system. ② When the carbon capture unit reaches the minimum output during the off-peak period, there may still be a waste of electricity. At this time, the hydrogen energy storage system can absorb the remaining electricity and replace the high-cost carbon capture unit to generate electricity by releasing the stored energy during the peak period of electricity consumption, thereby improving the economy of the power system operation.

[0154] 2) Carbon capture and hydrogen energy storage are combined with equivalent spinning reserve characteristics:

[0155] Based on the operating principle of the hydrogen energy storage system, its output model is as follows:

[0156]

[0157] Where: P el,t , P elH,t is the input and output power of the electrolytic cell during period t; is the efficiency of the electrolytic cell; E hs,t P is the energy stored in the hydrogen storage tank during period t; fcH,t , P fc,t is the input and output power of the fuel cell during period t; η fc for fuel cell efficiency.

[0158] The present invention focuses on the study of hydrogen energy storage participating in power system dispatching. It is assumed that each device of the hydrogen energy storage system operates at a fixed efficiency, and the operating efficiency of the hydrogen storage tank is not considered for the time being. Hydrogen energy storage has a faster adjustment speed and a lower standby cost. When it is used as a standby, it will not compress the online space of new energy sources, and is more suitable for system rotating standby. Lower electrolyzer output will affect its safety and stability, and may cause abnormal operation. The minimum technical output of the electrolyzer is 10% of the equipment capacity. The standby capacity of the electrolyzer is limited by its own constraints and the capacity of the hydrogen storage tank. The equivalent rotating standby constraints of the electrolyzer are as follows:

[0159]

[0160] Where: They are the upper and lower spinning reserve capacities provided for the electrolyzer during period t respectively; is the rated capacity of the electrolyzer; is the upper limit of the storage capacity of the hydrogen storage tank; X t It is the start and stop status of the electrolytic cell equipment. When it is 1, it means the equipment is started, and when it is 0, it means the equipment is shut down.

[0161] The backup capacity of the fuel cell is limited by its own performance and the capacity of the hydrogen storage tank. At the same time, its start-stop characteristics will also affect the backup capacity. In the startup state, the equivalent spinning reserve constraints of the fuel cell are as follows:

[0162]

[0163] Where: are the upper and lower spinning reserve capacities provided by the fuel cell during period t, respectively; is the rated capacity of the fuel cell; Y is the lower limit of the storage capacity of the hydrogen storage tank; t It is the start and stop status of the fuel cell equipment.

[0164] In the shutdown state, 50% of the capacity still has the ability to respond quickly. In the shutdown state, the fuel cell equivalent spinning reserve constraints are as follows:

[0165]

[0166] Assume that the carbon capture energy consumption changes linearly with the increase of the carbon capture unit's power output. The carbon capture energy consumption is highest during the trough period and lowest during the peak period. The regulation range of the carbon capture unit under the spinning reserve demand changes as follows: Figure 5 shown. Figure 5 middle, are the upper and lower limits of carbon capture energy consumption, respectively; They are the upper and lower spinning reserve of the carbon capture unit after hydrogen energy storage assumes spinning reserve; ΔP J1 , ΔP J2, ΔP J3 They are respectively the net output regulation range of conventional thermal power units, carbon capture units and carbon capture units under spinning reserve demand, and after considering the equivalent spinning reserve characteristics of hydrogen energy storage. The hydrogen energy storage system can share part of the spinning reserve capacity of the carbon capture unit, so that the regulation range of the carbon capture unit is related to the size of the spinning reserve capacity undertaken by the hydrogen energy storage. After the hydrogen energy storage system undertakes the system spinning reserve, the standby capacity of the carbon capture unit is reduced, which increases the regulation range of the carbon capture unit.

[0167] (III): Source-load-storage low-carbon economic dispatch model:

[0168] Objective function:

[0169] The present invention aims to optimize the comprehensive cost of the power system, and the objective function is as follows:

[0170] F=min(F p +F o +F v +F y +F s +F b +F q )(9);

[0171] Where: F is the comprehensive cost of the power system; F p F is the power generation cost of thermal power units; o F is the start-up and shutdown cost of thermal power units; v is the solution loss cost; F y is the carbon trading cost; F s F is the operation and maintenance cost of hydrogen energy storage; b is the standby cost; F q The cost of power loss.

[0172] 1) Power generation cost of thermal power units:

[0173]

[0174] Where: T is the dispatching period; n is the number of thermal power units; P Hi,t is the power generation capacity of the thermal power unit during period t; a i , b i , c i is the power generation cost coefficient of the i-th thermal power unit.

[0175] 2) Start-up and shutdown costs of thermal power units:

[0176]

[0177] Where: U i,t is the start / stop status of the i-th thermal power unit during period t; S g,i is the start-up and shutdown cost of the i-th unit.

[0178] 3) Solution loss cost:

[0179]

[0180] Where: K s is the cost coefficient of ethanolamine solution; is the solution operation loss coefficient; E Jc,t is the amount of CO2 captured by the carbon capture unit during period t.

[0181] 4) Carbon trading costs:

[0182]

[0183] Where: c tj is the carbon trading price; is the total carbon emissions of the system; σ is the carbon trading quota.

[0184] 5) Hydrogen energy storage operation and maintenance costs:

[0185] The operation and maintenance costs of hydrogen energy storage are mainly determined by the electrolyzer and fuel cell. The operation and maintenance costs of hydrogen storage tanks are relatively low and are not considered for the time being.

[0186]

[0187] Where: c el 、c fc They are the unit operation and maintenance cost coefficients of electrolyzer and fuel cell respectively.

[0188] 6) Spinning reserve cost:

[0189] The system spinning reserve cost is shown in formula (15). Hydrogen energy storage uses abandoned wind to produce hydrogen. The spinning reserve cost is less than the reserve cost of thermal power units. The electrolyzer reserve cost is approximately replaced by the operation and maintenance cost.

[0190]

[0191] Where: N m To provide a spinning reserve equipment assembly, including conventional thermal power units, carbon capture units and hydrogen energy storage systems; is the upper and lower spinning reserve cost coefficient of the kth type of equipment; They are the upper and lower spinning reserve capacities provided for the kth type of equipment in period t.

[0192] 7) Power loss cost:

[0193] The power loss comes from the wind power abandonment loss and the power loss caused by the low conversion efficiency of the hydrogen energy storage system in the process of absorbing the abandoned wind. The two types of power loss are uniformly measured by the penalty cost of new energy abandonment.

[0194]

[0195] Where: are the wind power forecast value, actual grid-connected power and abandoned wind power in period t respectively; c w is the penalty cost coefficient for wind curtailment.

[0196] Constraints:

[0197] 1) Power balance constraints:

[0198]

[0199] Where: P Ji,t is the net output power of the i-th thermal power unit; is the load size in period t after demand response.

[0200] 2) Operation constraints of thermal power units:

[0201]

[0202] Where: are the upper and lower limits of the output power of the i-th thermal power unit respectively.

[0203] 3) Constraints on new energy output:

[0204]

[0205] 4) Spinning reserve constraints.

[0206] ① Thermal power unit standby constraints:

[0207]

[0208] Where: The upper and lower spinning reserve capacity undertaken by the i-th thermal power unit; are the up and down climbing rates of the i-th thermal power unit respectively.

[0209] ② Hydrogen energy storage reserve constraints: Hydrogen energy storage rotating reserve constraints refer to equations (6) to (8);

[0210] ③ System reserve constraints: The system spinning reserve constraints are as follows, which convert the spinning reserve constraints under triangular fuzzy parameters into clear equivalence classes.

[0211]

[0212]

[0213] Where: is the fuzzy representation of the forecast error of wind power and load; Cr{} is the confidence expression; α is the confidence level of satisfying the system spinning reserve constraint.

[0214] 5) Other constraints.

[0215] ① Constraints on carbon capture power plants:

[0216] The carbon capture unit captures carbon dioxide, so that its grid power is affected by the capture energy consumption. In the comprehensive flexible operation mode, the mathematical model of the carbon capture unit is as follows:

[0217]

[0218] Where: P Hc,t is the power output of the carbon capture unit during period t; P B,t is the energy consumption of carbon capture; P r,t The energy consumed by the unit in the carbon capture process during period t; E c,t is the amount of CO2 captured by the carbon capture unit during period t; E v,t V is the amount of CO2 provided by the liquid storage tank during period t; ca,t M is the volume of solution that needs to be prepared by the liquid storage tank to meet the CO2 supply demand during period t; V and are the molar masses of ethanolamine solution and carbon dioxide, respectively; θ is the amount of analysis in the regeneration tower; ρ v is the concentration of alcoholamine solution; δ v is the density of amine solution.

[0219] ② Constraints of hydrogen energy storage system:

[0220]

[0221] Where: E hs,0 、E hs,T is the hydrogen storage capacity of the hydrogen storage tank at the initial moment and the final moment. is the maximum input power of the electrolyzer during period t; is the maximum output power of the fuel cell during period t;

[0222] ③Demand response constraints:

[0223] The demand response mechanism achieves load redistribution by adjusting users' electricity consumption patterns. This process ensures that the overall electricity demand remains unchanged before and after load transfer.

[0224]

[0225] Where: is the predicted value of the load.

[0226] ④ Uncertainty constraints on wind power and load output:

[0227] The uncertainty of wind power generation and load output is significant, making it difficult to accurately estimate the wind power output and load demand for the next day in the day-ahead scheduling plan. Once there is a mismatch between the power generation capacity on the power supply side and the demand on the load side, it may cause local load interruption, resulting in economic losses.

[0228] In view of this, the power system needs to pre-configure a certain amount of spinning reserve capacity to cope with the uncertainty of wind power and load output. The scale of this reserve capacity needs to be determined based on the size of the forecast error of renewable energy power generation and the forecast error of load. In order to quantify and describe the uncertainty of the system, the triangular fuzzy membership function can be used as an analysis tool.

[0229] H = (S1, S2, S3) (28);

[0230] Where: H is the membership function; S1 is the lower limit of the parameter; S2 is the historical statistical data; S3 is the upper limit of the parameter.

[0231] It should be pointed out that the triangular fuzzy membership adopted in the present invention is only used to determine the spinning reserve capacity in the system spinning reserve constraint. The present invention uses the prediction errors of wind power and load as fuzzy parameters to describe the uncertainty of their respective outputs. The corresponding fuzzy parameter model is as follows:

[0232]

[0233] Where: k 1w , k 3w , k 11 , k 31 is the wind power output and load demand forecast error proportionality coefficient.

[0234] (V): Verification Example:

[0235] The improved IEEE-30 node system is used as an example for simulation analysis. The system consists of four thermal power generating units, of which the G1 unit has been transformed into a low-carbon unit and integrated with carbon capture technology, while the other three units remain as traditional high-carbon emission thermal power units. The wind power installed capacity is set to 200MW. For details of the overall architecture of the system, see the Appendix. Figure 4 The specific parameter information of the thermal power unit is listed in Table 1, the relevant parameters of the hydrogen energy storage system are shown in Table 2, the time period division of the demand response is shown in Table 3, and the carbon capture unit and other relevant parameters are summarized in Table 4. The problem faced in solving the scheduling model belongs to the category of mixed integer linear programming. The professional optimization solver GUROBI is called by the MATLAB platform YALMIP toolbox to solve the low-carbon economic scheduling model proposed in this study.

[0236] Table 1 Technical parameters of thermal power units

[0237]

[0238] Table 2 Hydrogen energy storage system parameters

[0239]

[0240] Table 3 Demand response time division

[0241]

[0242] Table 4 Demand response time division

[0243]

[0244] In order to verify the effectiveness of the scheduling model proposed in the present invention, the following five scenarios are set, as shown in Table 5:

[0245] Table 5 Different scene condition settings

[0246]

[0247] Table 6 Cost comparison in different scenarios

[0248]

[0249] As can be seen from Table 6, in Scenario 1, carbon capture units and hydrogen energy storage systems are not considered. In this scenario, the standby cost, carbon emissions and wind power abandonment are all maintained at a high level, and the low-carbon and economical operation of the power system is insufficient.

[0250] Compared with Scenario 1, Scenario 2 has significant advantages in carbon emissions, new energy consumption and total system cost by introducing low-carbonization carbon capture units. Carbon capture units can capture and store CO2 produced by thermal power units, reducing carbon emissions by 1,420 tons. Compared with traditional thermal power units, carbon capture units have a wider output adjustment range, operate at a lower net output during off-peak periods, reduce power loss costs, and increase the capacity of new energy grid connection.

[0251] A hydrogen energy storage system is introduced in Scenario 3, but only the energy time-shift characteristics of the hydrogen energy storage system are considered. Comparing Scenario 3 with Scenario 2, it can be seen that the system power loss cost and comprehensive cost are reduced, among which the power loss cost is reduced by 33.92%.

[0252] Scenario 4 considers the equivalent rotating reserve characteristics of hydrogen energy storage on the basis of Scenario 3. Compared with thermal power units, the hydrogen energy storage system in Scenario 4 has a lower standby cost. Compared with the first three scenarios, the standby cost is greatly reduced. Compared with Scenario 3, the standby cost is reduced by 80,656 yuan, and the comprehensive cost is reduced by 94,303 yuan.

[0253] Scenario 5 introduces demand response on the load side based on Scenario 4 to improve the dispatchability of the system. After the introduction of demand response, some conventional thermal power units are shut down during peak periods, and the power generation shortfall is borne by the carbon capture units. Compared with Scenario 4, carbon emissions are reduced by 107t, and the total system cost is also reduced.

[0254] The present invention provides an optimization scheduling method for a hydrogen-containing energy storage system taking into account a carbon capture power plant. The method comprehensively analyzes the coordinated scheduling strategies of the source, load, and storage, aiming to achieve the coordinated operation of the carbon capture equipment and the hydrogen energy storage system, thereby promoting the development of a low-carbon economy. By analyzing the operating principles of the source side, the load side, and the energy storage, the role of the carbon capture device, the hydrogen energy storage system, and the demand response are fully utilized to enhance the scheduling flexibility of the power system. A structural framework for the coordinated operation of the source, the grid, and the load is constructed, and the coordinated operation characteristics of the carbon capture device and the hydrogen energy storage system under the demand for rotating standby are studied in depth. The model aims to achieve the optimal comprehensive cost of the system, and establishes a low-carbon economic scheduling model for the coordinated operation of the carbon capture device and the hydrogen energy storage system. A fuzzy membership function is used to describe the uncertainty of the system, and the system's rotating standby demand is clarified. The model proposed in the present invention takes into account both the economy and low carbon nature of the system operation, and effectively improves the level of new energy consumption.

Claims

1. A method for optimizing the scheduling of a hydrogen-containing energy storage system taking into account a carbon capture power plant, characterized in that The following steps are involved: Step 1: Analyze the coordinated operation characteristics of the carbon capture unit and the hydrogen energy storage system; Step 2: Establish a hydrogen energy storage output model based on the operating principle of hydrogen energy storage; Step 3: Introduce the hydrogen energy storage output model and build a low-carbon dispatch model for hydrogen energy storage and carbon capture combined operation considering the carbon trading mechanism. Step 4: Select unit output as the decision variable, take the optimization of system comprehensive cost as the goal, and consider the unit operation constraints and system safety constraints as well as the uncertainty of wind power output and load output, and solve the low-carbon scheduling model.

2. A method for optimizing the scheduling of a hydrogen-containing energy storage system taking into account a carbon capture power plant according to claim 1, characterized in that: In step 1, the coordinated operation characteristics of the carbon capture unit and the hydrogen energy storage system are analyzed. The net output adjustment range of the conventional thermal power part of the carbon capture unit is: In formula (1): P Jc,t is the net output of the carbon capture unit during period t; They are the upper and lower limits of the output power of the conventional thermal power part of the carbon capture unit; In formula (2): λ is the energy consumed to capture unit CO2; η is the carbon capture efficiency; δ max is the maximum smoke split ratio during period t; m c is the carbon emission intensity of the carbon capture unit; P D Fixed energy consumption for the carbon capture unit; Thermal power units need to reserve sufficient spinning reserve capacity to cope with the uncertainty of load and renewable energy output. The spinning reserve constraints of carbon capture units under flexible transformation are as follows: In formula (3): U c,t The start and stop status of the carbon capture unit during period t; Spinning reserve capacity up and down for carbon capture units; are the up and down ramp rates of the carbon capture unit, respectively; The regulation range of the carbon capture unit under the spinning reserve demand is:

3. A method for optimizing the scheduling of a hydrogen-containing energy storage system taking into account a carbon capture power plant according to claim 2, characterized in that: In step 2, the hydrogen energy storage output model is as follows: In formula (5), P el,t , P elH,t are the input and output power of the electrolyzer during period t respectively; η el is the electrolytic cell efficiency; E hs,t 、E hs,t-1 are the energy stored in the hydrogen storage tank at time t and t-1 respectively; P fcH,t , P fc,t are the fuel cell input and output power in period t respectively; η fc For fuel cell efficiency.

4. A method for optimizing the scheduling of a hydrogen-containing energy storage system taking into account a carbon capture power plant according to claim 3, characterized in that: The step 3 comprises: (1): Construct a low-carbon dispatch model for hydrogen energy storage and carbon capture combined operation taking into account the carbon trading mechanism, with the minimum system comprehensive cost as the objective function; F=min(F p +F o +F v +F y +F s +F b +F q ) (9); In formula (9), F is the comprehensive cost of the power system; F p F is the power generation cost of thermal power units; o F is the start-up and shutdown cost of thermal power units; v is the solution loss cost; F y is the carbon trading cost; F s F is the operation and maintenance cost of hydrogen energy storage; b is the standby cost; F q is the cost of power loss; 1) Generator power generation cost: In formula (10), T is the dispatch period; n is the number of thermal power units; P Hi,t is the power generation capacity of the thermal power unit during period t; a i , b i , c i is the power generation cost coefficient of the i-th thermal power unit; 2) Start-up and shutdown costs of thermal power units: In formula (11), U i,t , U i,t-1 are the start and stop states of the i-th thermal power unit in period t and period t-1 respectively; S g,i is the start-up and shutdown cost of the i-th unit; 3) Solution loss cost: In formula (12): K s is the cost coefficient of ethanolamine solution; is the solution operation loss coefficient; E Jc,t is the amount of CO2 captured by the carbon capture unit during period t; 4) Carbon trading costs: In formula (13): c tj is the carbon trading price; is the total carbon emissions of the system; σ is the carbon trading quota; 5) Hydrogen energy storage operation and maintenance costs: In formula (14): c el 、c fc are the unit operation and maintenance cost coefficients of electrolyzer and fuel cell respectively; P el,t is the input power of the electrolytic cell during period t; P fc,t are the fuel cell output power during period t respectively; 6) Spinning reserve cost: The system spinning reserve cost is shown in formula (15); hydrogen energy storage uses abandoned wind to produce hydrogen, and the spinning reserve cost is less than the reserve cost of thermal power units. The electrolyzer reserve cost is approximately replaced by the operation and maintenance cost; In formula (15), k represents the kth type of equipment, N m To provide a rotating reserve equipment assembly, including conventional thermal power units, carbon capture units and hydrogen energy storage systems; The upper and lower spinning reserve cost coefficients of the kth type of equipment respectively; They are the upper and lower spinning reserve capacities provided for the k-th type of equipment during period t; 7) Power loss cost: The power loss comes from the wind power abandonment loss and the power loss caused by the low conversion efficiency of the hydrogen energy storage system in the process of absorbing the abandoned wind power. The two types of power loss are uniformly measured by the penalty cost of new energy abandonment. In formula (16): P w,t , are the wind power forecast value, actual grid-connected power and abandoned wind power in period t respectively; c w Penalty cost factor for wind curtailment; In formula (17): c w Penalty cost factor for wind curtailment; is the wind power abandoned during period t; el is the electrolytic cell efficiency; η fc for fuel cell efficiency; (2): Construct unit operation constraints and system safety constraints: 1): Power balance constraints: In formula (18): P Ji,t is the net output power of the i-th thermal power unit; is the load size in period t after demand response; 2): Operation constraints of thermal power units: In formula (19): U i,t is the start / stop status of the i-th thermal power unit in period t; are the upper and lower limits of the output power of the i-th thermal power unit respectively; 3): Constraints on new energy output: In formula (20): is the wind power forecast value during period t; 4): Spinning reserve constraints: a. Thermal power unit reserve constraints: In formula (21) and formula (22): are the upper and lower spinning reserve capacities undertaken by the i-th thermal power unit respectively; are the up and down ramp rates of the i-th thermal power unit respectively; b. Constraints on equivalent spinning reserve of electrolyzers: In formula (6), P el,t E is the input power of the electrolytic cell during period t; hs,t The energy stored in the hydrogen storage tank during period t; They are the upper and lower spinning reserve capacities provided for the electrolyzer during period t respectively; is the rated capacity of the electrolyzer; is the upper limit of the storage capacity of the hydrogen storage tank; X t The start and stop status of the electrolytic cell equipment. When it is 1, it means the equipment is started, and when it is 0, it means the equipment is shut down; In the startup state, the fuel cell equivalent spinning reserve constraints are as follows: In formula (7), P fc,t is the input power of the fuel cell during period t; E hs,t The energy stored in the hydrogen storage tank during period t; are the upper and lower spinning reserve capacities provided by the fuel cell during period t, respectively; is the rated capacity of the fuel cell; Y is the lower limit of the storage capacity of the hydrogen storage tank; t The start and stop status of the fuel cell equipment; In the shutdown state, the fuel cell equivalent spinning reserve constraints are as follows: c System spinning reserve constraints: Convert the spinning reserve constraints under triangular fuzzy parameters into crisp equivalence classes; In formula (23), The upper spinning reserve capacity assumed by the k-th type of equipment during period t; is the load size in period t after demand response are the fuzzy expressions of wind power and load forecast errors respectively; Cr{} is the confidence expression; α is the confidence level of satisfying the system spinning reserve constraint; In formula (24), is the spinning reserve capacity borne by the kth type of equipment during period t.

5. A method for optimizing the scheduling of a hydrogen-containing energy storage system taking into account a carbon capture power plant according to claim 4, characterized in that: Other constraints include: 1). Carbon capture power plant constraints: The carbon dioxide capture process is performed by the carbon capture unit. The mathematical model of the carbon capture unit in the integrated flexible operation mode is as follows: In formula (25), P D is the fixed energy consumption of the carbon capture unit; λ is the energy consumed to capture unit CO2; E Jc,t is the amount of CO2 captured by the carbon capture unit during period t; m c is the carbon emission intensity of the carbon capture unit; γ is the energy consumed to capture unit CO2; P Hc,t is the power output of the carbon capture unit during period t; P B,t is the energy consumption of carbon capture; P r,t The energy consumed by the unit in the carbon capture process during period t; E c,t is the amount of CO2 captured by the carbon capture unit during period t; E v,t V is the amount of CO2 provided by the liquid storage tank during period t; ca,t M is the volume of solution that needs to be prepared by the liquid storage tank to meet the CO2 supply demand during period t; V and are the molar masses of ethanolamine solution and carbon dioxide, respectively; θ is the amount of analysis in the regeneration tower; ρ v is the concentration of alcoholamine solution; δ v is the density of the alcoholamine solution; 2) Hydrogen energy storage system constraints: In formula (26), is the rated capacity of the electrolyzer; are the maximum and minimum values ​​of the energy stored in the hydrogen storage tank; E hs,t The energy stored in the hydrogen storage tank during period t; is the rated capacity of the fuel cell, Rated capacity of electrolyzer during the period, P el,t The input power of the electrolyzer during period t; E hs,0 、E hs,T The hydrogen storage capacity of the hydrogen storage tank at the initial moment and the final moment; is the maximum input power of the electrolyzer during period t; is the maximum output power of the fuel cell during period t; 3) Demand response constraints: When the demand response mechanism operates, load redistribution is achieved by adjusting the user's electricity consumption behavior; In formula (27), is the predicted value of load; is the load size in period t after demand response; T is the dispatch period; 4). Uncertain constraints on wind power and load output: The triangular fuzzy membership function is used to describe the uncertainty of wind power and load output: H = (S1, S2, S3) (28); In formula (28), H is the membership function; S1 is the lower limit of the parameter; S2 is the historical statistical data; S3 is the upper limit of the parameter; The prediction errors of wind power generation and load are used as fuzzy parameters to characterize the uncertainty characteristics of their respective outputs. The fuzzy parameters are as follows: In formula (29), The wind power forecast error is The load prediction error, is the wind power forecast value in period t, The predicted value of load during period t, k 1w , k 3w , k 11 , k 31 is the wind power output and load demand forecast error proportionality coefficient.

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