A low-carbon scheduling method and system for an integrated energy system

Abstract

This invention discloses a low-carbon scheduling method and system for integrated energy systems, relating to the field of scheduling optimization technology. The specific steps are as follows: constructing an IES-RSOC architecture based on the integrated energy system, and constructing an integrated energy system scheduling model based on the IES-RSOC architecture; constructing a tiered carbon trading model and a demand response model based on the IES-RSOC architecture; introducing the tiered carbon trading model and the demand response model into the integrated energy system scheduling model, and constructing a low-carbon scheduling model for the integrated energy system with the goal of minimizing operating costs, combined with constraints. This invention maximizes the low-carbon nature and flexibility of hydrogen energy, achieving the effects of reducing carbon emission costs and improving energy conversion efficiency.

Description

Technical Field

[0001] This invention relates to the field of scheduling optimization technology, and more specifically to a low-carbon scheduling method and system for an integrated energy system. Background Technology

[0002] With increasing global focus on sustainable development, renewable energy sources such as wind and solar power have gained widespread attention due to their clean and inexhaustible nature. However, the intermittency and unpredictability of these renewable energy sources make grid management difficult, especially during peak electricity demand periods or when weather conditions are unfavorable, leading to curtailment of wind and solar power. To address this challenge, various solutions have been explored, among which hydrogen energy storage technology is considered an effective means due to its ability to store large amounts of energy over long periods.

[0003] Hydrogen storage not only addresses the intermittency of renewable energy sources but also serves as a clean energy carrier, reducing reliance on fossil fuels and thus lowering greenhouse gas emissions. The application prospects of hydrogen storage are even broader, especially with the development of reversible solid oxide battery (RSOC) technology. RSOC can produce hydrogen in electrolysis mode and consume hydrogen to generate electricity in fuel cell mode; this bidirectional conversion capability makes it a key bridge connecting renewable energy sources and end users.

[0004] However, despite the numerous advantages of hydrogen energy storage technology, it still faces some challenges in practical applications. How to effectively integrate RSOC with the existing power system to reduce carbon emissions while balancing supply and demand is a problem that urgently needs to be solved by those skilled in the art. Summary of the Invention

[0005] In view of this, the present invention provides a low-carbon scheduling method and system for integrated energy systems, overcoming the above-mentioned defects.

[0006] In order to achieve the above object, the present invention adopts the following technical solutions:

[0007] A low-carbon dispatching method for an integrated energy system, comprising the following steps:

[0008] An IES-RSOC architecture is constructed based on the integrated energy system, and an integrated energy system scheduling model is constructed based on the IES-RSOC architecture.

[0009] A tiered carbon trading model and a demand response model are constructed based on the IES-RSOC architecture;

[0010] The tiered carbon trading model and the demand response model are introduced into the integrated energy system scheduling model. With the goal of minimizing operating costs, and in combination with constraints, a low-carbon scheduling model for the integrated energy system is constructed.

[0011] Optionally, the integrated energy system dispatch model includes a clean power generation model, an RSOC model, a combined heat and power unit model, a gas boiler model, a methanation model, and an energy storage model.

[0012] Optionally, the expression for the tiered carbon trading model is:

[0013]

[0014] In the formula, σ represents the tiered carbon trading cost of the system; σ is the base carbon trading price; δ is the growth rate of carbon trading prices at different tiers; M c For purchasing allowances; p is the length of the carbon emission range.

[0015] Optionally, the demand response model includes an interruptible model and a transferable model.

[0016] Optionally, the expression for the interruptible model is:

[0017]

[0018] In the formula, These represent the load values ​​of the interruptible electrical load before and after participating in demand response at time t; These represent the load values ​​at time t before and after the interruptible hydrogen load participates in the demand response; These represent the load values ​​before and after the interruptible heat load participates in demand response at time t; Let t represent the interruptible loads of electricity, hydrogen, and heat at time t.

[0019] Optionally, the expression for the transferable model is:

[0020]

[0021] In the formula, These represent the load values ​​of transferable electrical load before and after participating in demand response at time t; These represent the load values ​​of transferable hydrogen load before and after participating in demand response at time t; These represent the load values ​​at time t before and after the transferable heat load participates in the demand response; These are the transferable loads for electricity, hydrogen, and heat, respectively. These represent the load amounts transferred in and out of the electrical load at time t, respectively. These represent the amount of hydrogen load transferred in and out at time t, respectively. These represent the load amounts transferred in and out at time t, respectively.

[0022] Optionally, the operating cost is the total daily operating cost, obtained based on energy purchase cost, tiered carbon trading cost, wind and solar curtailment cost, and demand response cost, and its expression is:

[0023]

[0024] In the formula, This represents the total daily operating cost of the system. The cost of purchasing energy for the system; The carbon trading cost of the system; The cost of curtailing wind and solar power in the system; This refers to the system's demand response cost.

[0025] Optionally, the constraints include power balance constraints, equipment operation constraints, energy purchase constraints, and demand response constraints.

[0026] Optionally, the equipment operation constraints include wind and solar generator operation constraints, RSOC operation constraints, cogeneration unit operation constraints, gas turbine unit operation constraints, methanation unit constraints, and energy storage constraints.

[0027] A low-carbon dispatching system for an integrated energy system, comprising:

[0028] The initial model building module is used to build the IES-RSOC architecture based on the integrated energy system, and to build the integrated energy system scheduling model according to the IES-RSOC architecture;

[0029] The first model building module is used to build a tiered carbon trading model and a demand response model based on the IES-RSOC architecture.

[0030] The model optimization module is used to introduce the tiered carbon trading model and the demand response model into the integrated energy system scheduling model, with the goal of minimizing operating costs, and in combination with constraints, to construct a low-carbon scheduling model for the integrated energy system.

[0031] As can be seen from the above technical solutions, compared with the prior art, this invention discloses a low-carbon dispatching method and system for a comprehensive energy system. Through a low-carbon dispatching method that considers a tiered carbon trading mechanism and demand response, it maximizes the low-carbon nature and flexibility of hydrogen energy, achieving the effects of reducing carbon emission costs and improving energy conversion efficiency. This invention applies hydrogen to all aspects of the power system, including the "source, grid, and load" links. By leveraging the large-scale and long-term storage characteristics of hydrogen energy storage, it can achieve large-scale absorption of wind and solar power curtailment on the power supply side. Hydrogen energy can be converted into gas and heat energy through technologies such as RSOC, methanation, and combined heat and power, which can optimize the overall energy configuration of the system on the grid side. Combined with its inherent cleanliness, it can achieve large-scale carbon reduction. The flexible conversion of hydrogen into electricity, gas, and heat energy also greatly promotes multi-energy complementary operation on the load side. Attached Figure Description

[0032] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on the provided drawings without creative effort.

[0033] Figure 1 This is a schematic diagram of the method flow provided by the present invention;

[0034] Figure 2 This is a schematic diagram of the IES-RSOC structure provided by the present invention;

[0035] Figure 3 This is a schematic diagram of carbon trading provided by the IES-RSOC according to the present invention;

[0036] Figure 4 A schematic diagram of the piecewise function of the reward and punishment tiered carbon trading mechanism provided by the present invention;

[0037] Figure 5 A schematic diagram of energy prices provided for this invention;

[0038] Figure 6 The above diagram illustrates the predicted output and load curves of typical renewable energy sources for each season, as provided by this invention. Detailed Implementation

[0039] The following will clearly and completely describe the technical solutions in the embodiments of the present invention in conjunction with the accompanying drawings. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of the present invention.

[0040] This embodiment discloses a low-carbon dispatching method for an integrated energy system, such as... Figure 1 As shown, the specific steps are as follows:

[0041] Step 1: Construct the IES-RSOC architecture based on the integrated energy system, and construct the integrated energy system scheduling model based on the IES-RSOC architecture;

[0042] Step 2: Construct a tiered carbon trading model and a demand response model based on the IES-RSOC architecture;

[0043] Step 3: Introduce the tiered carbon trading model and demand response model into the integrated energy system scheduling model. With the goal of minimizing operating costs, and in combination with constraints, construct a low-carbon scheduling model for the integrated energy system.

[0044] In one embodiment, the integrated energy system's energy sources are wind and solar power generation, hydrogen, natural gas, and purchased electricity. The loads are categorized into three types: electricity loads, heat loads, and hydrogen loads. The system's equipment mainly includes RSOC, wind power generation (WG), photovoltaic power generation (PV), combined heat and power (CHP), gas-fired boiler (GB), methanation unit (MET), hydrogen energy storage unit (HES), and thermal energy storage unit (TES).

[0045] In one embodiment, the integrated energy system dispatch model includes a clean power generation model, an RSOC model, a combined heat and power unit model, a gas boiler model, a methanation model, and an energy storage model.

[0046] In one embodiment, the clean power generation model includes a photovoltaic power generation model and a wind power generation model, wherein the expression for the photovoltaic power generation model is:

[0047]

[0048] In the formula, P represents the output power of the photovoltaic cell at time t. ST Light intensity 1kW / m 2 Photovoltaic power output at 25℃; r is the actual solar radiation intensity at time t; ST denoted as , where is the solar radiation intensity under standard conditions; z is the temperature coefficient of photovoltaic power. T represents the actual operating temperature of the photovoltaic cell at time t; STThis refers to the operating temperature of a photovoltaic cell under standard conditions.

[0049] The expression for the wind power generation model is:

[0050]

[0051] In the formula, v is the output power of the wind power at time t; v is the actual wind speed at time t; v in Let v be the cutoff wind speed at time t; out The cutoff wind speed at time t; P WG v0 represents the rated power of the fan; v0 represents the rated wind speed.

[0052] In one embodiment, the RSOC model includes SOFC mode and SOEC mode;

[0053] The simplified expressions for the output electrical and thermal power of RSOC in SOFC mode are:

[0054]

[0055] In the formula, L represents the heat dissipation power of the SOFC at time t. hv Hydrogen has a high calorific value; Let t be the hydrogen production rate of SOFC; The heat dissipation coefficient of SOFC at time t; Let t be the power consumption of the SOFC. Let t be the SOFC electrolysis efficiency at time t.

[0056] The simplified expressions for the electrical and thermal power consumption of RSOC in SOEC mode are:

[0057]

[0058] In the formula, Let t be the heat dissipation power of SOEC; Let t be the power consumption of SOEC; Let t be the SOEC heat dissipation coefficient; Let t be the SOEC hydrogen production rate; Let t be the SOEC electrolysis efficiency at time t.

[0059] In one embodiment, the expression for the combined heat and power unit model is:

[0060]

[0061] In the formula, Let t be the electrical power output of the CHP unit; η is the input power of the CHP unit at time t; gteThe gas-to-electricity efficiency coefficient of the CHP unit; η is the thermal power output of the CHP unit at time t; gth This is the gas-to-heat efficiency coefficient of the CHP unit.

[0062] In one embodiment, the expression for the gas-fired boiler model is:

[0063]

[0064] In the formula, Let t be the thermal power output of unit GB. η is the input power of the GB unit at time t; GB This is the gas-to-heat efficiency coefficient of the GB unit.

[0065] In one embodiment, the expression for the methanation model is:

[0066]

[0067] In the formula, Let t be the output power of the MET unit; η is the input power of the MET unit at time t; MET The efficiency of hydrogen methanation conversion in the MET unit.

[0068] In one embodiment, the energy storage model includes a hydrogen storage device model and a thermal storage device model, wherein the expression for the hydrogen storage device model is:

[0069]

[0070] In the formula, η represents the amount of hydrogen stored in the HES at time t; HES,ch Hydrogen charging efficiency for HES; Let t be the hydrogen charging power of HES; η is the hydrogen release power of HES at time t; HES,dis The hydrogen release efficiency of HES.

[0071] The expression for the thermal storage device model is:

[0072]

[0073] In the formula, Let η be the heat storage of the TES at time t; TES,ch The heating efficiency of TES; Let t be the heating power of the TES; Let η be the heat release power of TES at time t; TES,dis This refers to the heat dissipation efficiency of TES.

[0074] In one embodiment, the expression for the tiered carbon trading model is:

[0075]

[0076] In the formula, δ represents the tiered carbon trading cost of the system; p is the length of the carbon emission range; and δ is the growth rate of carbon trading prices at different tiers.

[0077] Furthermore, the steps to obtain the tiered carbon trading model are as follows:

[0078] like Figure 3 As shown, the carbon emissions from the RSOC-based integrated energy system come from three sources: purchased electricity, gas turbines, and gas-fired boilers. This embodiment assumes that all purchased electricity originates from coal-fired power plants. The system's free total carbon emissions model is as follows:

[0079]

[0080] In the formula, E IES E is the total amount of free carbon emissions for the system. e,buy Free carbon emission allowance for electricity purchased from higher authorities; E CHP E GB Free carbon credits for CHP and GB, respectively; λ e Carbon emissions per unit of electricity generated by a coal-fired power unit; λ g Carbon emissions per unit of natural gas used by a natural gas-fired power plant.

[0081] The hydrogen-to-natural-gas conversion process in MET can absorb some CO2, so this needs to be taken into account. The actual carbon emission model is as follows:

[0082]

[0083] In the formula, E IES,a E represents the system's actual total carbon emissions. e,buy,a E represents the actual carbon emissions from electricity purchased from higher levels. total,a This represents the total actual carbon emissions from CHP, GB, and MR; E MRT This represents the actual amount of CO2 absorbed by the MET; a1, b1, and c1 are carbon emission calculation parameters for coal-fired units; a2, b2, and c2 are carbon emission calculation parameters for natural gas-fired units. ω represents the equivalent output power of CHP and GB at time t; ω is the parameter for CO2 absorption during the methanation process of the MR device.

[0084] In one embodiment, the formula for calculating the additional quota that the system needs to purchase is as follows:

[0085] M c =E IES,a -EIES (13);

[0086] The traditional carbon trading cost calculation is as follows:

[0087] C E =σM c (14);

[0088] In the formula, C E The cost of purchasing additional allowances for the system; σ is the base price for carbon trading.

[0089] Since traditional carbon trading calculation models have a certain inhibitory effect on carbon emissions, the single trading and insufficient execution result in the inability to maximize the limitation of carbon emissions. Therefore, in order to further limit carbon emissions, this embodiment adopts a tiered carbon trading mechanism with multiple trading ranges, and its model expression is shown in formula (10).

[0090] The base price of carbon trading is generally influenced by policies and the market, and the price difference between adjacent tiers can be σδ. The relationship between carbon trading price and trading volume is as follows: Figure 4 As shown.

[0091] In one embodiment, the demand response model includes an interruptible model and a transferable model.

[0092] In one embodiment, energy sources such as heat and gas can also participate in demand response. Through demand response, the amount of usage can be reduced or shifted, peak-time available capacity can be increased, and RIES can be promoted to achieve supply and demand balance.

[0093] Interruptible loads are a type of incentive-based demand response, characterized by low requirements for energy reliability, such as indoor lighting and heating. Government departments sign dispatch agreements with users, who, based on market incentives, selectively interrupt energy consumption during certain periods, reducing total usage to achieve supply-demand matching. Users of interrupted loads receive compensation according to the agreement. The expression for the interruptible load model is:

[0094]

[0095] In the formula, These represent the load values ​​of the interruptible electrical load before and after participating in demand response at time t; These represent the load values ​​at time t before and after the interruptible hydrogen load participates in the demand response; These represent the load values ​​before and after the interruptible heat load participates in demand response at time t; Let t represent the interruptible loads of electricity, hydrogen, and heat at time t.

[0096] In one embodiment, transferable load is a type of price-based demand response, characterized by the shift of energy demand from one period to another while the total energy consumption remains constant. This allows some energy-consuming equipment to be shifted from peak to off-peak periods, while also providing some compensation. The expression for the transferable load model is:

[0097]

[0098] In the formula, These represent the load values ​​of transferable electrical load before and after participating in demand response at time t; These represent the load values ​​of transferable hydrogen load before and after participating in demand response at time t; These represent the load values ​​at time t before and after the transferable heat load participates in the demand response; These are the transferable loads for electricity, hydrogen, and heat, respectively. These represent the load amounts transferred in and out of the electrical load at time t, respectively. These represent the amount of hydrogen load transferred in and out at time t, respectively. These represent the load amounts transferred in and out at time t, respectively.

[0099] In one embodiment, the operating cost is the total daily operating cost, obtained based on energy purchase cost, tiered carbon trading cost, wind and solar curtailment cost, and demand response cost, and its expression is:

[0100]

[0101] In the formula, This represents the total daily operating cost of the system. The cost of purchasing energy for the system; The carbon trading cost of the system; The cost of curtailing wind and solar power in the system; This refers to the system's demand response cost.

[0102] Furthermore, this embodiment introduces tiered carbon trading in the low-carbon dispatch of the RSOC integrated energy system, thus requiring the tiered carbon trading cost to be used as an economic indicator for system dispatch. This embodiment takes the minimum daily operating cost as the objective function, comprehensively considers energy purchase cost, tiered carbon trading cost, wind and solar curtailment cost, and demand response cost, and constructs an operating cost model as shown in formula (17).

[0103] In one embodiment, the system's energy purchase cost includes the cost of purchasing hydrogen, natural gas, electricity from the grid, and the cost of purchasing RSOC and water required for electrolysis in SOEC mode, expressed as:

[0104]

[0105] In the formula, T is the system scheduling period; The system's grid connection electricity price; The amount of electricity purchased within time t; The system's water purchase price; σ water This refers to the water consumption coefficient for water electrolysis under the SOEC mode. The amount of hydrogen produced within time t; The system's hydrogen purchase price; The amount of hydrogen purchased within time t; The system's natural gas purchase price; Let be the amount of natural gas purchased within time t.

[0106] In one embodiment, the expression for the system's wind and solar curtailment cost is:

[0107]

[0108] In the formula, The unit waste-of-light penalty cost of the system; The unit cost of wind curtailment penalty for the system; Let be the system's abandoned light power at time t; Let t be the system's wind curtailment power at time t.

[0109] In one embodiment, the system's demand response cost is:

[0110]

[0111] In the formula, These are the compensation costs for interrupted loads and transferable loads, respectively; ξ el,cut ξ hy,cut ξ hot,cut These are the compensation coefficients for interruptible loads of electricity, hydrogen, and heat, respectively; ξ el,sht ξ hy,sht ξ hot,sht These are the compensation coefficients for transferable loads of electricity, hydrogen, and heat, respectively.

[0112] In one embodiment, the constraints include power balance constraints, equipment operation constraints, energy purchase constraints, and demand response constraints.

[0113] In one embodiment, the power balance constraint includes:

[0114] Electric power balance constraints:

[0115]

[0116] In the formula, This refers to the amount of electricity sold.

[0117] Thermal power balance constraint:

[0118]

[0119] Hydrogen power balance constraint:

[0120]

[0121] Natural gas power balance constraints:

[0122]

[0123] In one embodiment, the equipment operation constraints include wind and solar generator operation constraints, RSOC operation constraints, combined heat and power (CHP) unit operation constraints, gas turbine unit operation constraints, methanation unit constraints, and energy storage constraints, specifically:

[0124] Constraints of wind and solar power generation:

[0125]

[0126] In the formula, P PV,min 、P PV,max These are the upper and lower limits of output for PV, respectively; P WG,min 、P WG,max These are the upper and lower limits of WG's output, respectively.

[0127] RSOC operating constraints: RSOC efficiency is extremely low and ramping capability is poor when operating under low load conditions. To ensure flexible and efficient RSOC operation, the base power for RSOC operation is limited. The expressions for RSOC output, ramping constraints, and operating state constraints are as follows:

[0128]

[0129] In the formula, ΔP SOEC,down This represents the lower limit of SOFC ramping power; ΔP SOFC,up This represents the upper limit of SOFC ramp power; ΔP SOEC,down This represents the lower limit of SOEC ramp power; ΔP SOEC,up These represent the SOEC ramp power limit; w t =0 or 1 is the RSOC operating status constraint parameter.

[0130] Cogeneration unit operating constraints, i.e., CHP operating constraints:

[0131]

[0132] In the formula, P CHP,min 、P CHP,max These are the upper and lower limits of CHP's output, respectively; ΔP CHP,ge,max ΔP CHP,ge,minThese are the power limits for CHP's ramp and downhill sections, respectively.

[0133] Gas turbine unit operating constraints, i.e., GB operating constraints:

[0134]

[0135] In the formula, P GB,min 、P GB,max These are the upper and lower limits of GB's output, respectively; ΔP GB,ge,max ΔP GB,ge,min These are the ramp and downhill power limits for GB, respectively.

[0136] Methanation unit constraints, i.e., MET unit constraints:

[0137]

[0138] In the formula, P MET,min 、P MET,max These are the upper and lower limits of MET's output, respectively; ΔP MET,ge,max ΔP MET,ge,min These are the climbing and downhill power limits for MET, respectively.

[0139] Energy storage constraints include HES constraints and TES constraints, specifically:

[0140] HES constraints:

[0141]

[0142] In the formula, These are the maximum and minimum storage capacities of the HES device, respectively. These are the initial and final storage quantities for the HES device, respectively. These are the maximum values ​​of the hydrogen charging and discharging power of the HES unit, respectively; The variable can be either 0 or 1, representing both hydrogen filling and hydrogen release; it cannot be both 0 or 1 simultaneously.

[0143] TES constraints:

[0144]

[0145] In the formula, These represent the maximum and minimum storage capacity of the TES device, respectively. These are the initial and final storage capacities of the TES unit, respectively. These are the maximum values ​​of the charging and discharging power of the TES device, respectively; A variable that is either 0 or 1 represents both the heat charging and heat releasing states; it cannot be both 0 or 1 simultaneously.

[0146] In one embodiment, the energy purchase constraint is:

[0147]

[0148] In the formula, P el,buy,max 、P el,buy,min These are the upper and lower limits of the power purchase capacity, respectively; P hy,buy,max 、P hy,buy,min These represent the upper and lower limits of hydrogen purchase capacity, respectively; P gas,buy,max 、P gas,buy,min These are the upper and lower limits for the power consumption required to purchase natural gas.

[0149] In one embodiment, the demand response constraint includes:

[0150] Interruptible load constraints:

[0151]

[0152] In the formula, △P el,cut,min , △P el,cut,max These represent the minimum and maximum interruptible electrical loads, respectively; △P hy,cut,min , △P hy,cut,max These represent the minimum and maximum interruptible hydrogen load, respectively; △P hot,cut,min , △P hot,cut,max These represent the minimum and maximum interruptible heat loads, respectively.

[0153] Transferable load constraints:

[0154]

[0155] In the formula, △P el,sht,min , △P el,sht,max These represent the minimum and maximum transferable electrical loads, respectively; △P hy,sht,min , △P hy,sht,max These represent the minimum and maximum transferable hydrogen loads, respectively; ΔP hot,sht,min , △P hot,sht,max These represent the minimum and maximum transferable heat loads, respectively.

[0156] In one embodiment, taking a comprehensive energy system in a western industrial park as an example, its structure is as follows: Figure 2 As shown, low-carbon optimization scheduling of some equipment in the system needs to be implemented based on the output of wind and solar clean energy, as well as the electricity load, heat load, and hydrogen load. The base power for photovoltaic power is 3500kW, the base power for wind power is 2500kW, the base power for electricity load is 4000kW, the base power for heat load is 2000kW, and the base power for hydrogen load is 1500kW. The efficiency of each device in the system is shown in Table 1, the output range and ramp-up range parameters of the system equipment are shown in Table 2, other parameters are shown in Table 3, and energy price and other parameters are shown in Table 4. Figure 5As shown in the figure, (a) represents the energy purchase price, and (b) represents the energy sales price. Using the K-means clustering algorithm, the energy is divided into four typical days: spring, summer, autumn, and winter. The predicted renewable energy output curves and load curves for each season are shown below. Figure 6 As shown in the figure, (a) represents the predicted output and load curves of typical renewable energy sources in spring; (b) represents the predicted output and load curves of typical renewable energy sources in summer; (c) represents the predicted output and load curves of typical renewable energy sources in autumn; and (d) represents the predicted output and load curves of typical renewable energy sources in winter. Its operating strategy is as follows: When the system has surplus electricity, SOEC converts electricity into hydrogen energy through water electrolysis; when the system has insufficient electricity, SOFC converts hydrogen energy into electricity through combustion. The specific strategy generation steps are as follows:

[0157] 1) Input clean energy data such as wind and solar resources, and generate scenarios based on it;

[0158] 2) Input tiered carbon trading information such as carbon trading range and base price;

[0159] 3) Construct a function with the objective of minimizing daily operating costs;

[0160] 4) Input constraints such as energy balance, equipment operation, and demand response;

[0161] 5) Using 1 hour as the scheduling accuracy and a typical day as the period, the CPLEX solver was called using the Yalmip toolbox to perform low-carbon optimization scheduling on the scheme model.

[0162] 6) Output low-carbon optimization solutions.

[0163] Table 1

[0164]

[0165] Table 2

[0166]

[0167]

[0168] Table 3

[0169]

[0170] Another aspect of the present invention discloses a low-carbon dispatching system for an integrated energy system, comprising:

[0171] The initial model building module is used to build the IES-RSOC architecture based on the integrated energy system, and to build the integrated energy system scheduling model based on the IES-RSOC architecture;

[0172] The first model building module is used to build a tiered carbon trading model and a demand response model based on the IES-RSOC architecture.

[0173] The model optimization module is used to introduce the tiered carbon trading model and demand response model into the integrated energy system scheduling model. With the goal of minimizing operating costs, and in combination with constraints, a low-carbon scheduling model for the integrated energy system is constructed.

[0174] The various embodiments in this specification are described in a progressive manner, with each embodiment focusing on its differences from other embodiments. Similar or identical parts between embodiments can be referred to interchangeably. For the apparatus disclosed in the embodiments, since they correspond to the methods disclosed in the embodiments, the description is relatively simple; relevant parts can be referred to the method section.

[0175] The above description of the disclosed embodiments enables those skilled in the art to make or use the invention. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of the invention. Therefore, the invention is not to be limited to the embodiments shown herein, but is to be accorded the widest scope consistent with the principles and novel features disclosed herein.

Claims

1. A low-carbon dispatching method for an integrated energy system, characterized in that, The specific steps are as follows: An IES-RSOC architecture is constructed based on an integrated energy system, and an integrated energy system scheduling model is constructed based on the IES-RSOC architecture; the integrated energy system scheduling model includes a clean power generation model, an RSOC model, a combined heat and power unit model, a gas boiler model, a methanation model, and an energy storage model; A tiered carbon trading model and a demand response model are constructed based on the IES-RSOC architecture; the demand response model includes an interruptible model and a transferable model. The expression for the interruptible model is as follows: In the formula, These represent the load values ​​of the interruptible electrical load before and after participating in demand response at time t; These represent the load values ​​at time t before and after the interruptible hydrogen load participates in the demand response; These represent the load values ​​before and after the interruptible heat load participates in demand response at time t; These represent the interruptible loads of electricity, hydrogen, and heat at time t, respectively. The expression for the transferable model is: In the formula, These represent the load values ​​of transferable electrical load before and after participating in demand response at time t; These represent the load values ​​of transferable hydrogen load before and after participating in demand response at time t; These represent the load values ​​at time t before and after the transferable heat load participates in the demand response; These are the transferable loads for electricity, hydrogen, and heat, respectively. These represent the load amounts transferred in and out of the electrical load at time t, respectively. These represent the amount of hydrogen load transferred in and out at time t, respectively. These represent the load amounts that are transferred into and out of the heat load at time t, respectively. The tiered carbon trading model and the demand response model are introduced into the integrated energy system scheduling model. With the goal of minimizing operating costs, and in combination with constraints, a low-carbon scheduling model for the integrated energy system is constructed. The constraints include power balance constraints, equipment operation constraints, energy purchase constraints, and demand response constraints. The equipment operation constraints include wind and solar generator set operation constraints, RSOC operation constraints, cogeneration unit operation constraints, gas turbine unit operation constraints, methanation unit constraints, and energy storage constraints.

2. The low-carbon dispatching method for an integrated energy system according to claim 1, characterized in that, The expression for the tiered carbon trading model is: In the formula, σ represents the tiered carbon trading cost of the system; σ is the base carbon trading price; δ is the growth rate of carbon trading prices at different tiers; M c For purchasing allowances; p is the length of the carbon emission range.

3. The low-carbon dispatching method for an integrated energy system according to claim 1, characterized in that, The operating cost mentioned is the total daily operating cost, obtained based on energy purchase cost, tiered carbon trading cost, wind and solar curtailment cost, and demand response cost. Its expression is: In the formula, This represents the total daily operating cost of the system. The cost of purchasing energy for the system; The carbon trading cost of the system; The cost of curtailing wind and solar power in the system; This refers to the system's demand response cost.

4. A low-carbon dispatching system for an integrated energy system, characterized in that, Implementing a low-carbon dispatching method for an integrated energy system as described in claim 1 includes: The initial model building module is used to build the IES-RSOC architecture based on the integrated energy system, and to build the integrated energy system scheduling model according to the IES-RSOC architecture; The first model building module is used to build a tiered carbon trading model and a demand response model based on the IES-RSOC architecture. The model optimization module is used to introduce the tiered carbon trading model and the demand response model into the integrated energy system scheduling model, with the goal of minimizing operating costs, and in combination with constraints, to construct a low-carbon scheduling model for the integrated energy system.

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