A stochastic optimization scheduling method for an electric-thermal-gas-hydrogen integrated energy system containing hydrogen storage

Abstract

The application discloses a kind of hydrogen energy storage's electric heating gas hydrogen comprehensive energy system random optimization scheduling method, and comprehensive energy system mainly includes four subsystems of electricity, heat, gas, hydrogen.The dynamic efficiency model of electrolytic cell, fuel cell is analyzed in the application, and the energy conversion equipment, energy storage equipment etc. between multiple energy in system are established corresponding mathematical model.The energy purchase cost, load loss compensation cost, environmental cost and wind and light penalty cost are comprehensively considered, and the total operation cost of electric heating gas hydrogen comprehensive energy system minimization is taken as objective function to carry out scheduling to the generation, heating, gas supply and electrolytic hydrogen production involved in system.The optimization scheduling method proposed in the application can effectively consume wind power, reduce operating cost, reduce environmental pollution, and has good economy and environmental protection.

Description

Technical Field

[0001] This invention relates to improvements in energy dispatching technology, specifically to a stochastic optimization dispatching method for an integrated energy system containing hydrogen energy storage, which is an electric-thermal-gas-hydrogen system, belonging to the field of integrated energy system optimization dispatching technology. Background Technology

[0002] Accelerating the development of non-fossil energy, especially renewable energy sources such as wind power, photovoltaics, and hydropower, is the core of promoting the low-carbon energy transition. With the increasing proportion of new energy grid connection, the problem of wind and solar power curtailment is very serious due to the intermittent and fluctuating output of wind and solar power. Hydrogen energy, as a low-carbon secondary energy source, has developed rapidly, and the use of renewable energy electrolysis to produce hydrogen can effectively improve my country's renewable energy consumption level. Most existing studies integrate hydrogen energy into electrothermal systems to improve system operating economics, but few consider the uncertainty of renewable energy and the fluctuation of load. Therefore, research is needed on the stochastic optimization scheduling of integrated electrothermal-hydrogen energy systems that takes uncertainty into account. Furthermore, the existing hydrogen system equipment models are relatively coarse, only studying the energy consumption characteristics of single equipment and assuming their operating efficiency is constant. In fact, the operating efficiency of hydrogen system equipment is affected by load power during operation, exhibiting a non-linear trend. Therefore, the dynamic efficiency of hydrogen system equipment must be considered in the optimal scheduling of integrated electrothermal-hydrogen energy systems. Summary of the Invention

[0003] In view of the above-mentioned shortcomings of the existing technology, the purpose of this invention is to propose a stochastic optimization scheduling method for a hydrogen-containing energy storage electrothermal gas hydrogen integrated energy system. This method helps to give full play to the role of hydrogen energy in the integrated energy system and promote the consumption of renewable energy.

[0004] The technical solution of this invention is implemented as follows:

[0005] A stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electrothermal-gas-hydrogen system is characterized in that: the integrated electrothermal-gas-hydrogen system includes a power generation system, which includes a wind power generation system, a photovoltaic power generation system, a fuel cell, and a gas turbine; the outputs of the wind power generation system, the photovoltaic power generation system, the fuel cell, and the gas turbine are connected to the load via a power bus; and a storage battery is connected to the power bus to store electrical energy or to output the stored electrical energy to the load via the power bus.

[0006] The electrical load includes a hydrogen electrolyzer and an electric boiler. The output of the power bus is connected to the hydrogen electrolyzer and the electric boiler respectively to supply power to them. The hydrogen output from the hydrogen electrolyzer is connected to a hydrogen storage tank. The output of the hydrogen storage tank is connected to a hydrogen-to-methane unit, a fuel cell, and a mixed hydrogen-natural gas pipeline. The output of the hydrogen-to-methane unit is connected to a natural gas pipeline, which is connected to a mixed hydrogen-natural gas pipeline. The output of the mixed hydrogen-natural gas pipeline is connected to a gas turbine, a gas boiler, and the gas load. The heat energy output from the hydrogen electrolyzer, fuel cell, and gas turbine is connected to a waste heat recovery device. The heat energy output from the gas boiler, waste heat recovery device, and electric boiler is connected to the heat load or a heat storage tank through a heat bus. The heat storage tank is used to store heat energy or output the stored heat energy to the heat load through the heat bus.

[0007] Taking into account energy purchase costs, load shedding compensation costs, environmental costs, and wind and solar curtailment penalties, the total operating cost of the integrated power-heat-gas-hydrogen energy system is minimized as the objective function for scheduling the power generation, heating, gas supply, and hydrogen electrolysis processes involved in the system. The objective function expression is as follows:

[0008] min C = C buy +C com +C en +C p

[0009] In the formula, C represents the total operating cost of the system; C buy C com C en C p These are energy purchase costs, loss-of-load compensation costs, environmental costs, and wind and solar curtailment penalty costs.

[0010] The energy purchase cost includes the costs of purchasing electricity, heat, gas, and hydrogen, which are expressed as follows:

[0011] C buy =C buye +C buyt +C buyg +C buyh

[0012]

[0013]

[0014]

[0015]

[0016] In the formula, C buye C buyt C buyg C buyh These are the costs of purchasing electricity, heat, gas, and hydrogen, respectively; prt E pr G pr T pr H These are the unit prices for purchasing electricity, gas, heat, and hydrogen, respectively. These represent the electricity and heat purchase power at time t in scenario s, respectively. These represent the purchased gas volume and hydrogen volume at time t in scenario s, respectively; prob s,t Let be the probability of scenario s at time t.

[0017] The cost of load shedding compensation is calculated using the following formula:

[0018]

[0019] In the formula, pr Pnd pr Tnd pr Gnd Price per unit power for power loss compensation in electricity, heat, and gas, ¥ / kWh; The electrical, thermal, and gaseous power loss at time t in scenario s, respectively, in kW; prob s,t Let be the probability of scenario s at time t.

[0020] The environmental cost is calculated using the following formula:

[0021]

[0022] In the formula, T t mt The heating power of the gas turbine is expressed in kW or T. t gb The output thermal power of the gas-fired boiler is expressed in kW. The penalty prices for SO2, NO2, and CO2 emissions per unit of thermal power produced by gas turbines and gas boilers, respectively, are ¥ / kWh; The density of CO2 is kg / m³. 3 ; Environmental contribution incentive price, ¥ / kg.

[0023] The penalty cost for wind and solar power curtailment is calculated using the following formula:

[0024]

[0025] In the formula, p f Price for penalties for wind and solar power curtailment, expressed as ¥ / kWh; Let be the power of wind and solar curtailment at time t in scenario s, in kW; prob s,t Let be the probability of scenario s at time t.

[0026] In this invention, the hydrogen flow rate and heat generation power output from the hydrogen electrolyzer are calculated using the following formula:

[0027]

[0028]

[0029] η t el =a1+a2P t el +a3(P t el ) 2

[0030] In the formula, F t el The hydrogen flow rate is m. 3 / h;P t el The power consumption of the electrolytic cell is expressed in kW. The efficiency of hydrogen production in the electrolyzer; The low calorific value of hydrogen is kWh / m³. 3 ;T t el a1, a2, and a3 represent the heat generation power of the electrolytic hydrogen production process (kW); a1, a2, and a3 are the efficiency parameters of the electrolyzer.

[0031] The electrical and thermal power output of a fuel cell are calculated using the following formula:

[0032]

[0033]

[0034]

[0035] In the formula, P t fc The electrical power output of the fuel cell is expressed in kW; F t fc m is the hydrogen flow rate of the fuel cell. 3 / h;T t fc The output thermal power of the fuel cell is expressed in kW. For the efficiency of fuel cells; b i These are fuel cell efficiency parameters.

[0036] In this invention, the energy conversion relationship of the hydrogen-to-methane device is as follows:

[0037]

[0038]

[0039] In the formula, m is the flow rate of CO2 consumed in the hydrogen-to-methane process. 3 / h; m is the hydrogen flow rate used to produce methane. 3 / h; k is the molar volume conversion factor; For the generated methane flow rate, m 3 / h;η ch4 The efficiency of the hydrogen-to-methane unit.

[0040] In this invention, the battery, thermal storage tank, and hydrogen storage tank are the energy storage devices of the system, and the corresponding mathematical models of each energy storage device are established according to the following formula:

[0041]

[0042]

[0043] SOCx min ≤SOCx t ≤SOCx max

[0044]

[0045]

[0046]

[0047]

[0048] Among them, SOCx t The total energy storage (E), thermal storage (T), and hydrogen storage (H) during time period t; δ represents the energy released and stored during time period t, respectively; x,loss Storage dissipation rate; These represent the energy charge / discharge efficiency; SOCx0 represents the initial energy in the energy storage device; SOCx min SOCx max These are the upper and lower limits for energy storage, respectively; x c,min x c,max These represent the upper and lower limits of charging for different energy storage devices; These represent the upper and lower limits of energy release for different energy storage devices; μ c μ d This is a 0-1 variable indicating the charging / discharging status of the corresponding energy storage device.

[0049] The calorific value of mixed hydrogen natural gas (L) mix for,

[0050]

[0051] In the formula, L gas It is a low-calorific-value natural gas, kWh / m³ 3 ; The hydrogen-to-hydrogen ratio, representing the ratio of hydrogen volume to the total gas volume in the pipeline, is calculated using the following formula:

[0052]

[0053] In the formula, F t grid To purchase hydrogen, m 3 / h;F t mix The flow rate of hydrogen released from the hydrogen storage tank that participates in direct hydrogen mixing, m 3 / h; For gas purchase volume, m 3 / h; The methane flow rate produced by the hydrogen-to-methane unit is given in m. 3 / h.

[0054] Compared with the prior art, the present invention has the following beneficial effects:

[0055] This invention analyzes the operating characteristics of equipment such as electrolyzers and fuel cells, taking into account the dynamic changes in equipment efficiency, and establishes a refined model of the hydrogen system equipment. It considers multiple energy storage methods for electrothermal hydrogen to achieve energy coupling in the electrothermal gas-hydrogen system. Taking into account the fluctuations in electrothermal gas load and the uncertainty of renewable energy, it proposes a stochastic optimization scheduling method for the integrated electrothermal gas-hydrogen energy system. The optimization scheduling method proposed in this invention can effectively absorb wind power, reduce operating costs, and reduce environmental pollution, demonstrating good economic and environmental benefits. Attached Figure Description

[0056] Figure 1 -Schematic diagram of the IEHGHES model structure of the integrated electrothermal-hydrogen energy system of this invention.

[0057] Figure 2 -Flowchart of the model solution process of this invention.

[0058] Figure 3 - A schematic diagram of the system's electric heating and gas load and wind and solar energy data in a certain embodiment of the present invention. Detailed Implementation

[0059] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings.

[0060] This invention proposes an integrated electric-heating-gas-hydrogen energy system (IEHGHES), analyzes the dynamic efficiency models of the electrolyzer and fuel cell, and establishes corresponding mathematical models for energy conversion devices and energy storage devices among various energy sources in the system. Taking into account energy purchase costs, load shedding compensation costs, environmental costs, and wind / solar curtailment penalties, and aiming to minimize total operating costs, a stochastic optimization scheduling method for the integrated electric-heating-gas-hydrogen energy system is proposed, considering load fluctuations and the uncertainty of renewable energy sources.

[0061] The IEHGHES structure of the present invention is as follows Figure 1 As shown, the system mainly comprises four subsystems: electricity, heat, gas, and hydrogen. Specifically, the integrated energy system includes a power generation system, which comprises a wind power generation system, a photovoltaic power generation system, a fuel cell, and a gas turbine. The outputs of the wind power generation system, photovoltaic power generation system, fuel cell, and gas turbine are connected to the load via a power bus. A storage battery is connected to the power bus to store electrical energy or to output the stored electrical energy to the load via the power bus.

[0062] The electrical load includes a hydrogen electrolyzer and an electric boiler. The output of the power bus is connected to the hydrogen electrolyzer and the electric boiler respectively to supply power to them. The hydrogen output from the hydrogen electrolyzer is connected to a hydrogen storage tank. The output of the hydrogen storage tank is connected to a hydrogen-to-methane unit, a fuel cell, and a mixed hydrogen-natural gas pipeline. The output of the hydrogen-to-methane unit is connected to a natural gas pipeline, which is connected to a mixed hydrogen-natural gas pipeline. The output of the mixed hydrogen-natural gas pipeline is connected to a gas turbine, a gas boiler, and a gas load. The heat energy output from the hydrogen electrolyzer, fuel cell, and gas turbine is connected to a waste heat recovery device. The heat energy output from the gas boiler, waste heat recovery device, and electric boiler is connected to a heat load or a heat storage tank through a heat bus. The heat storage tank is used to store heat energy or to output the stored heat energy to the heat load through the heat bus.

[0063] Due to variations in meteorological factors and physical conditions related to IEHGHES operation, the output of wind and solar power, as well as the loads on power, heat, and natural gas systems, exhibit uncertainty. This invention establishes an uncertain model of wind, solar, and load based on stochastic scenarios. It generates a large number of scenarios using probability density functions and a roulette wheel algorithm, and employs a synchronous back-substitution scenario reduction method to eliminate low-probability scenarios. This transforms the stochastic optimization problem into a deterministic one.

[0064] The mathematical modeling process for the main equipment involved in this invention is as follows. Considering the refined models of the electrolyzer and fuel cell, the hydrogen production efficiency of the electrolyzer is affected by factors such as operating current and equipment parameters. The efficiency of the electrolyzer has a non-linear relationship with the operating current, and therefore also a non-linear relationship with the actual power, making it difficult to use for establishing a mathematical model of electrolyzer operation. To facilitate calculation, a polynomial fitting function is used for simplification, and the fuel cell is treated similarly:

[0065]

[0066]

[0067]

[0068]

[0069]

[0070]

[0071] In the formula, F t el The hydrogen flow rate is m. 3 / h;P t el The power consumption of the electrolytic cell is expressed in kW. The efficiency of hydrogen production in the electrolyzer; The low calorific value of hydrogen is kWh / m³. 3 ;T t el The heat output power (kW) of the electrolytic hydrogen production process; F t fc m is the hydrogen flow rate of the fuel cell. 3 / h;P t fc The output electrical power of the fuel cell is expressed in kW; T. t fc The output thermal power of the fuel cell is expressed in kW. The efficiency of the fuel cell is given by a1, a2, and a3, which are the efficiency parameters of the electrolyzer. i These are fuel cell efficiency parameters.

[0072] The energy conversion relationship of a hydrogen-to-methane plant is as follows:

[0073]

[0074]

[0075] In the formula, m is the flow rate of CO2 consumed in the hydrogen-to-methane process. 3 / h; m is the hydrogen flow rate used to produce methane. 3 / h; k is the molar volume conversion factor; For the generated methane flow rate, m 3 / h;η ch4 The efficiency of the hydrogen-to-methane equipment.

[0076] Batteries, thermal storage tanks, and hydrogen storage tanks are the energy storage devices in the system. The mathematical model for these energy storage devices is as follows:

[0077]

[0078]

[0079] SOCx min ≤SOCx t ≤SOCx max

[0080]

[0081]

[0082]

[0083]

[0084] Among them, SOCx t The total energy storage (E), thermal storage (T), and hydrogen storage (H) during time period t; δ represents the energy released and stored during time period t, respectively; x,loss Storage dissipation rate; These represent the energy charge / discharge efficiency; SOCx0 represents the initial energy in the energy storage device; SOCx min SOCx max These are the upper and lower limits for energy storage, respectively; x c,min x c,max These represent the upper and lower limits of charging for different energy storage devices; These represent the upper and lower limits of energy release for different energy storage devices; μ c μ d This is a 0-1 variable indicating the charging / discharging status of the corresponding energy storage device.

[0085] hydrogen mixing ratio This is an important parameter for hydrogen-mixed natural gas, representing the ratio of hydrogen volume to the total gas volume in the pipeline:

[0086]

[0087] In the formula, F t grid To purchase hydrogen, m 3 / h;F t mix The flow rate of hydrogen released from the hydrogen storage tank that participates in direct hydrogen mixing, m 3 / h; For gas purchase volume, m 3 / h.

[0088] Based on pipeline safety requirements and gas-using equipment, the hydrogen mixing ratio... Generally not exceeding 20%. Calorific value (L) of the mixed gas. mix for:

[0089]

[0090] In the formula, L gas It is a low-calorific-value natural gas, kWh / m³ 3 .

[0091] The IEHGHES optimized scheduling model comprehensively considers system energy purchase cost, load shedding compensation cost, environmental cost, and wind / solar curtailment penalty cost to construct an optimized operation objective function, the expression of which is as follows:

[0092] min C = C buy +C com +C en +C p

[0093] In the formula, C represents the total operating cost of the system, expressed in RMB. buy C com C en C p These are energy purchase cost, loss-of-load compensation cost, environmental cost, and wind / solar curtailment penalty cost, respectively, in ¥.

[0094] (1) Energy purchase cost

[0095] IEHGHES energy purchase costs mainly include the costs of purchasing electricity, heat, gas, and hydrogen, which can be specifically expressed as follows:

[0096] C buy =C buye +C buyt +C buyg +C buyh

[0097]

[0098]

[0099]

[0100]

[0101] In the formula, Cbuye C buyt C buyg C buyh These are the costs of purchasing electricity, heat, gas, and hydrogen, respectively; pr t E pr G pr T pr H These are the unit prices for purchasing electricity, gas, heat, and hydrogen, respectively. These represent the electricity and heat purchase power at time t in scenario s, respectively. These represent the gas and hydrogen purchase quantities at time t in scenario s, respectively; prob s,t Let be the probability of scenario s at time t.

[0102] (2) Loss of load compensation cost

[0103] To fully meet load demand, the objective function includes load loss compensation costs, which are the costs incurred in compensating users when load demand cannot be met.

[0104]

[0105] In the formula, pr Pnd pr Tnd pr Gnd Price per unit power for power loss compensation in electricity, heat, and gas, ¥ / kWh; Let be the electrical, thermal, and gaseous power loss at time t under scenario s, respectively, in kW.

[0106] (3) Environmental costs

[0107] To achieve low-carbon goals, polluting emissions will be penalized. Considering the environmental contribution of hydrogen-to-methane production, the corresponding environmental costs are as follows:

[0108]

[0109] In the formula, T t mt The heating power of the gas turbine is expressed in kW or T. t gb The output thermal power of the gas-fired boiler is expressed in kW. The penalty prices for SO2, NO2, and CO2 emissions per unit of thermal power produced by gas turbines and gas boilers, respectively, are ¥ / kWh; The density of CO2 is kg / m³. 3 ; Environmental contribution incentive price, ¥ / kg.

[0110] (4) Penalty costs for wind and solar power curtailment

[0111] To promote the utilization of wind and solar resources, the penalty cost for wind and solar curtailment is considered as follows:

[0112]

[0113] In the formula, p f Price for penalties for wind and solar power curtailment, expressed as ¥ / kWh; Let be the power of wind and solar curtailment at time t under scenario s, in kW.

[0114] The stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electrothermal-hydrogen system proposed in this invention is a mixed-integer nonlinear programming problem. The SOS-2 piecewise linearization method is used for linearization, transforming the model into a mixed-integer linear programming problem, which can be quickly solved using the commercial software Cplex. The model solution process is as follows: Figure 2 As shown.

[0115] The present invention will be further described below with reference to specific embodiments.

[0116] Assume the daily load of electric heating gas and the power output curves of wind and solar power in the system are as follows: Figure 3 As shown.

[0117] The optimized scheduling cycle is 24 hours, divided into 1-hour time periods. Electricity purchase prices are based on time-of-use pricing: off-peak hours are 0:00-8:00, normal hours are 8:00-12:00 and 17:00-20:00, and peak hours are 12:00-17:00 and 20:00-24:00. The off-peak, normal, and peak hour prices are ¥0.17 / kWh, ¥0.49 / kWh, and ¥0.83 / kWh, respectively. The heat purchase price is ¥0.35 / kWh, and the natural gas price is ¥2.5 / m³. 3 The price of hydrogen is ¥2 / m³ 3 .

[0118] To demonstrate the role of IEHGHES in promoting the consumption of renewable energy, three comparative cases are set up, as shown in Table 1. Case 1 is the model method proposed in this invention, which includes multiple forms of energy storage such as electrolyzers, fuel cells, hydrogen-to-methane, and electrothermal hydrogen, and takes into account the dynamic efficiency of electrolyzers and fuel cells. In Case 2, the efficiency of electrolyzers and fuel cells is fixed at 0.7. Case 3 does not consider hydrogen systems and only considers traditional integrated electric-thermal-gas energy systems.

[0119] Table 1 Costs of Different Cases

[0120]

[0121]

[0122] Table 2 shows the total renewable energy utilization rate for different cases. Due to the participation of the hydrogen system, the wind and solar energy utilization capacity in Case 1 was significantly improved, with an energy utilization rate reaching 98.4%. During the early morning hours, wind resources were abundant, and the system used an electrolyzer to produce hydrogen for energy storage; however, due to the capacity limitations of the hydrogen production equipment, some wind power was wasted. At midday, because photovoltaic resources were plentiful and the output of each device basically met the electricity and heat load requirements, solar power wasted. In Case 2, because the refined process of the hydrogen equipment was not considered, the wind and solar energy utilization rate was slightly lower than in Case 1, at 94.2%. Case 3 had the lowest wind and solar energy utilization rate at 90.1%, with severe wind and solar power wasted. In summary, the addition of the hydrogen system effectively improved the wind and solar energy utilization rate and significantly reduced wind and solar power wasted.

[0123] Table 2 Total Renewable Energy Consumption Rate in Different Cases

[0124]

[0125] Table 3 shows the cost comparison results for different cases. It can be seen that the total operating cost of Case 1 is 3072.67, which is more economical than the other cases. This is because the addition of the hydrogen system provides a new energy storage method, absorbing more renewable energy, and its wind and solar curtailment penalty is the lowest. Since the efficiency of the electrolyzer and fuel cell in Case 2 is fixed at 0.7, and actual operating conditions are not considered, its energy purchase cost increases by 3.25% compared to Case 1, and its wind and solar curtailment penalty cost is approximately twice that of Case 1. Case 3 is a traditional integrated electric-thermal-gas energy system. Due to the absence of a hydrogen system, its wind and solar curtailment penalty is the highest, and this case also lacks hydrogen-to-methane equipment for CO2 recycling, resulting in a higher environmental cost, approximately twice that of Case 1. The load shedding compensation cost is 0 in all cases. This is because the unit load shedding penalty in the cases is relatively high, and Cases 1-3 did not choose a strategy of reducing costs by shedding load. In conclusion, using hydrogen energy as a medium to achieve the coupling of electric and thermal systems can reduce the total operating cost of the system and promote the utilization of renewable energy.

[0126] Table 3 Costs of Different Cases

[0127]

[0128] Finally, it should be noted that the above examples of the present invention are merely illustrative and not intended to limit the implementation of the invention. Although the applicant has described the present invention in detail with reference to preferred embodiments, those skilled in the art can make other variations and modifications based on the above description. It is impossible to exhaustively list all possible implementations here. All obvious variations or modifications derived from the technical solutions of the present invention are still within the scope of protection of the present invention.

Claims

1. A stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electrothermal gas-hydrogen system, characterized in that: The integrated electrothermal-hydrogen energy system includes a power generation system, which comprises a wind power generation system, a photovoltaic power generation system, a fuel cell, and a gas turbine. The outputs of the wind power generation system, the photovoltaic power generation system, the fuel cell, and the gas turbine are connected to the power load via a power bus. A storage battery is connected to the power bus to store electrical energy or to output the stored electrical energy to the power load via the power bus. The electrical load includes a hydrogen electrolyzer and an electric boiler. The output of the power bus is connected to the hydrogen electrolyzer and the electric boiler respectively to supply power to them. The hydrogen output from the hydrogen electrolyzer is connected to a hydrogen storage tank. The output of the hydrogen storage tank is connected to a hydrogen-to-methane unit, a fuel cell, and a mixed hydrogen-natural gas pipeline. The output of the hydrogen-to-methane unit is connected to a natural gas pipeline, which is connected to a mixed hydrogen-natural gas pipeline. The output of the mixed hydrogen-natural gas pipeline is connected to a gas turbine, a gas boiler, and the gas load. The heat energy output from the hydrogen electrolyzer, fuel cell, and gas turbine is connected to a waste heat recovery device. The heat energy output from the gas boiler, waste heat recovery device, and electric boiler is connected to the heat load or a heat storage tank through a heat bus. The heat storage tank is used to store heat energy or output the stored heat energy to the heat load through the heat bus. Taking into account energy purchase costs, load shedding compensation costs, environmental costs, and wind and solar curtailment penalties, the total operating cost of the integrated power-heat-gas-hydrogen energy system is minimized as the objective function for scheduling the power generation, heating, gas supply, and hydrogen electrolysis processes involved in the system. The objective function expression is as follows: my C=C buy +C com +C en +C p In the formula, C represents the total operating cost of the system; C buy C com C en C p These are energy purchase costs, loss-of-load compensation costs, environmental costs, and costs of penalties for wind and solar power curtailment. The battery, thermal storage tank, and hydrogen storage tank are the energy storage devices of the system. The mathematical model of each energy storage device is established according to the following formula: SOCx min ≤SOCx t ≤SOCx max m c +m d ≤1 Among them, SOCx t The total energy storage (E), thermal storage (T), and hydrogen storage (H) during time period t; δ represents the energy released and stored during time period t, respectively; x,loss Storage dissipation rate; These represent the energy charge / discharge efficiency; SOCx0 represents the initial energy in the energy storage device; SOCx min SOCx max These are the upper and lower limits for energy storage, respectively; x c,min x c,max These represent the upper and lower limits of charging for different energy storage devices; These represent the upper and lower limits of energy release for different energy storage devices; μ c μ d This is a 0-1 variable indicating the charging / discharging status of the corresponding energy storage device.

2. The stochastic optimization scheduling method for a hydrogen-containing energy storage electrothermal gas-hydrogen integrated energy system according to claim 1, characterized in that: The energy purchase cost includes the cost of purchasing electricity, heat, gas, and hydrogen, which are expressed as follows: C buy =C buye +C buyt +C buyg +C buyh In the formula, C buye C buyt C buyg C buyh These are the costs of purchasing electricity, heat, gas, and hydrogen, respectively. pr t E pr G pr T pr H These are the unit prices for purchasing electricity, gas, heat, and hydrogen, respectively. These represent the electricity and heat purchase power at time t in scenario s, respectively. These represent the purchased gas volume and hydrogen volume at time t in scenario s, respectively; prob s,t Let be the probability of scenario s at time t.

3. The stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electric-thermal-hydrogen system according to claim 1, characterized in that: The cost of load shedding compensation is calculated using the following formula: In the formula, pr Pnd pr Tnd pr Gnd Price per unit power for power loss compensation in electricity, heat, and gas, ¥ / kWh; The electrical, thermal, and gaseous power loss at time t in scenario s, respectively, in kW; prob s,t Let be the probability of scenario s at time t.

4. The stochastic optimization scheduling method for a hydrogen-containing energy storage electrothermal gas-hydrogen integrated energy system according to claim 1, characterized in that: The environmental cost is calculated using the following formula: In the formula, T t mt The heating power of the gas turbine is expressed in kW or T. t gb The output thermal power of the gas-fired boiler is expressed in kW. The penalty prices for SO2, NO2, and CO2 emissions per unit of thermal power produced by gas turbines and gas boilers, respectively, are ¥ / kWh; The density of CO2 is kg / m³. 3 ; Environmental contribution incentive price, ¥ / kg.

5. The stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electrothermal gas-hydrogen energy system according to claim 1, characterized in that: The penalty cost for wind and solar power curtailment is calculated using the following formula: In the formula, p f Price for penalties for wind and solar power curtailment, expressed as ¥ / kWh; Let be the power of wind and solar curtailment at time t in scenario s, in kW; prob s,t Let be the probability of scenario s at time t.

6. The stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electrothermal gas-hydrogen energy system according to claim 1, characterized in that: This scheduling method establishes uncertain models of wind power generation systems, photovoltaic power generation systems, electrical load, heat load, and gas load based on random scenarios. It generates a large number of scenarios by applying probability density functions and roulette wheel algorithm, and uses a synchronous back-substitution scenario reduction method to eliminate low-probability scenarios, thereby transforming the stochastic optimization problem into a deterministic problem.

7. The stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electrothermal gas-hydrogen system according to claim 1, characterized in that: The hydrogen flow rate and heat production power output from the hydrogen electrolyzer are calculated using the following formula: In the formula, F t el The hydrogen flow rate is m. 3 / h;P t el The power consumption of the electrolytic cell is expressed in kW. The efficiency of hydrogen production in the electrolyzer; The low calorific value of hydrogen is kWh / m³. 3 ; T t el a1, a2, and a3 represent the heat generation power of the electrolytic hydrogen production process (kW); a1, a2, and a3 are the efficiency parameters of the electrolyzer. The electrical and thermal power output of a fuel cell are calculated using the following formula: In the formula, P t fc The electrical power output of the fuel cell is expressed in kW; F t fc m is the hydrogen flow rate of the fuel cell. 3 / h;T t fc The output thermal power of the fuel cell is expressed in kW. For the efficiency of fuel cells; b i These are fuel cell efficiency parameters.

8. The stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electric-thermal-hydrogen system according to claim 1, characterized in that: The energy conversion relationship of a hydrogen-to-methane plant is as follows: In the formula, m is the flow rate of CO2 consumed in the hydrogen-to-methane process. 3 / h; m is the hydrogen flow rate used to produce methane. 3 / h; k is the molar volume conversion factor; For the generated methane flow rate, m 3 / h;η ch4 The efficiency of the hydrogen-to-methane unit.

9. The stochastic optimization scheduling method for a hydrogen-containing energy storage integrated electrothermal gas-hydrogen system according to claim 1, characterized in that: The calorific value of mixed hydrogen natural gas (L) mix for, In the formula, L gas It is a low-calorific-value natural gas, kWh / m³ 3 ; The hydrogen-to-hydrogen ratio, representing the ratio of hydrogen volume to the total gas volume in the pipeline, is calculated using the following formula: In the formula, F t grid To purchase hydrogen, m 3 / h;F t mix The flow rate of hydrogen released from the hydrogen storage tank that participates in direct hydrogen mixing, m 3 / h; For gas purchase volume, m 3 / h; The methane flow rate produced by the hydrogen-to-methane unit is given in m. 3 / h.

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