Low-carbon scheduling method and system of integrated energy system

Abstract

The invention discloses a low-carbon scheduling method and system for an integrated energy system, and relates to the technical field of scheduling optimization, and the method comprises the specific steps: constructing an IES-RSOC architecture based on the integrated energy system, and constructing an integrated energy system scheduling model according to the IES-RSOC architecture; constructing a stepped carbon transaction model and a demand response model based on an IES-RSOC architecture; and introducing the stepped carbon transaction model and the demand response model into the integrated energy system scheduling model, and constructing an integrated energy system low-carbon scheduling model by taking the minimum operation cost as a target and combining constraint conditions. According to the invention, the low-carbon property and flexibility of hydrogen energy are exerted to the greatest extent, and the effects of reducing the carbon emission cost and improving the energy conversion efficiency are achieved.

Description

Technical Field

[0001] The present invention relates to the technical field of scheduling optimization, and more specifically to a low-carbon scheduling method and system for an integrated energy system. Background Art

[0002] As the world pays more attention to sustainable development, renewable energy sources such as wind and solar energy have attracted widespread attention due to their clean and endless characteristics. However, the intermittent and unpredictable nature of these renewable energy sources makes it difficult to effectively manage the power grid, especially during peak electricity consumption or bad weather conditions, which can easily lead to wind and solar power abandonment. In order to meet this challenge, a variety of solutions have been explored, among which hydrogen energy storage technology is seen as an effective means due to its ability to store large amounts of energy for a long time.

[0003] Hydrogen energy storage can not only solve the intermittent problem of renewable energy, but also serve as a clean energy carrier to reduce dependence on fossil fuels, thereby reducing greenhouse gas emissions. Especially with the development of reversible solid oxide cell (RSOC) technology, the application prospects of hydrogen energy storage are even broader. RSOC can produce hydrogen in electrolysis mode and consume hydrogen to generate electricity in fuel cell mode. This two-way conversion capability makes it a key bridge connecting renewable energy and end users.

[0004] However, despite the many advantages of hydrogen energy storage technology, it still faces some challenges in practical application. How to effectively integrate RSOC with the existing power system and reduce carbon emissions on the basis of balancing supply and demand is an urgent problem that technicians in this field need to solve. Summary of the invention

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

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

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

[0008] Building an IES-RSOC architecture based on an integrated energy system, and building an integrated energy system scheduling model based on the IES-RSOC architecture;

[0009] Construct a ladder-type carbon trading model and demand response model based on the IES-RSOC architecture;

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

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

[0012] Optionally, the ladder-type carbon trading model is expressed as:

[0013]

[0014] In the formula, is the system's tiered carbon trading cost; σ is the carbon trading base price; δ is the growth rate of carbon trading prices at different tiers; M c is the purchase quota; p is the length of the carbon emission interval.

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

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

[0017]

[0018] In the formula, They are the load values ​​before and after the interruptible load participates in demand response at time t; They are the load values ​​before and after the interruptible hydrogen load participates in demand response at time t; They are the load values ​​before and after the interruptible heat load participates in demand response at time t; They are the interruptible loads of electricity, hydrogen and heat at time t respectively.

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

[0020]

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

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

[0023]

[0024] In the formula, is the total daily operating cost of the system; is the system's energy purchase cost; is the carbon trading cost of the system; The system’s wind and solar curtailment costs; is the demand response cost of the system.

[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 power generator set operation constraints, RSOC operation constraints, cogeneration unit operation constraints, gas unit operation constraints, methanation unit constraints and energy storage constraints.

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

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

[0029] The first model building module is used to build a ladder-type carbon trading model and a demand response model according to the IES-RSOC framework;

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

[0031] It can be seen from the above technical solutions that, compared with the prior art, the present invention discloses a low-carbon scheduling method and system for an integrated energy system. Through a low-carbon scheduling method that takes into account a ladder-type carbon trading mechanism and demand response, the low-carbon and flexibility of hydrogen energy are maximized, thereby achieving the effect of reducing carbon emission costs and improving energy conversion efficiency. The present invention applies hydrogen to each link of the "source, grid, and load" of the power system. With the large-scale and long-term storage characteristics of hydrogen energy storage, a large amount of abandoned wind and solar power can be absorbed on the power supply side. Hydrogen energy is converted into gas energy and thermal energy through RSOC, methanation, cogeneration and other technologies, which can optimize the overall energy configuration of the system on the grid side. Combined with its own cleanliness, it can achieve the effect of large-scale carbon reduction. The flexible conversion of hydrogen into electricity, gas, and heat energy has also greatly promoted the complementary operation of multiple energy sources on the load side. BRIEF DESCRIPTION OF THE DRAWINGS

[0032] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on the provided drawings without paying creative work.

[0033] Figure 1 A schematic diagram of the method provided by the present invention;

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

[0035] Figure 3 A schematic diagram of carbon trading of IES-RSOC provided by the present invention;

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

[0037] Figure 5 A schematic diagram of energy prices provided by the present invention;

[0038] Figure 6 This is a schematic diagram of the predicted output curve and load curve of typical renewable energy in each season provided by the present invention. DETAILED DESCRIPTION

[0039] The following will be combined with the drawings in the embodiments of the present invention to clearly and completely describe the technical solutions in the embodiments of the present invention. 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 creative work are within the scope of protection of the present invention.

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

[0041] Step 1: Build the IES-RSOC architecture based on the integrated energy system, and build the integrated energy system scheduling model according to the IES-RSOC architecture;

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

[0043] Step 3: Introduce the ladder-type carbon trading model and demand response model into the integrated energy system scheduling model, take the minimum operating cost as the goal, and combine the constraints to build a low-carbon scheduling model for the integrated energy system.

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

[0045] In one embodiment, the integrated energy system scheduling model includes a clean power generation model, an RSOC model, a cogeneration 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 of the photovoltaic power generation model is:

[0047]

[0048] In the formula, is the output power of the photovoltaic cell at time t; P ST The light intensity is 1kW / m 2 , photovoltaic power generation output at 25℃; is the actual solar radiation intensity at time t; r ST is the solar radiation intensity under standard conditions; z is the photovoltaic power temperature coefficient; is the actual working temperature of the photovoltaic cell at time t; T STis the operating temperature of photovoltaic cells under standard conditions.

[0049] The expression of wind power generation model is:

[0050]

[0051] In the formula, is the output power of wind power at time t; v is the actual wind speed at time t; v in is the cut-in wind speed at time t; v out is the cut-out wind speed at time t; P WG is the rated power of the fan; v0 is the rated wind speed.

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

[0053] The simplified expression of electrical and thermal power output of RSOC in SOFC mode is:

[0054]

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

[0056] The simplified expression of electrical and thermal power consumed by RSOC in SOEC mode is:

[0057]

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

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

[0060]

[0061] In the formula, is the electric power output of the CHP unit at time t; is the input power of the CHP unit at time t; η gteis the gas-to-electricity efficiency coefficient of the CHP unit; is the thermal power output of the CHP unit at time t; η gth is the gas-to-gas thermal efficiency coefficient of the CHP unit.

[0062] In one embodiment, the expression of the gas boiler model is:

[0063]

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

[0065] In one embodiment, the expression of the methanogenation model is:

[0066]

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

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

[0069]

[0070] In the formula, is the hydrogen storage capacity of HES at time t; η HES,ch is the hydrogen charging efficiency of HES; is the hydrogen charging power of HES at time t; is the hydrogen desorption power of HES at time t; η HES,dis is the hydrogen desorption efficiency of HES.

[0071] The expression of the heat storage device model is:

[0072]

[0073] In the formula, is the heat storage capacity of TES at time t; η TES,ch is the heating efficiency of TES; is the heating power of TES at time t; is the heat release power of TES at time t; η TES,dis is the heat release efficiency of TES.

[0074] In one embodiment, the ladder-type carbon trading model is expressed as:

[0075]

[0076] In the formula, is the system's stepped carbon trading cost; p is the length of the carbon emission interval; δ is the growth rate of different stepped carbon trading prices.

[0077] Furthermore, the steps for obtaining the ladder-type carbon trading model are as follows:

[0078] like Figure 3 As shown, the carbon emissions generated by the integrated energy system based on RSOC are divided into three categories: purchased electricity, gas turbines, and gas boilers. In this embodiment, it is assumed that the upper-level purchased electricity comes from coal-fired units. The total free carbon emission model of the system is:

[0079]

[0080] In the formula, E IES is the total free carbon emissions of the system; E e,buy Free carbon emission allowance for purchasing electricity from the upper level; E CHP 、E GB are the free carbon emission quotas of CHP and GB respectively; e is the carbon emission per unit of electricity used by coal-fired units; g It refers to the carbon emission per unit of natural gas used by natural gas-fired units.

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

[0082]

[0083] In the formula, E IES,a is the actual total carbon emissions of the system; E e,buy,a The actual carbon emissions of electricity purchased from the superior; E total,a is the total actual carbon emissions of CHP, GB and MR; E MRT is the actual amount of CO2 absorbed by MET; a1, b1, c1 are all carbon emission calculation parameters for coal-fired units; a2, b2, c2 are all carbon emission calculation parameters for natural gas-fired units; is the equivalent output power of CHP and GB at time t; ω is the parameter of CO2 absorption in the methanation process of the MR device.

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

[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 quotas for the system; σ is the carbon trading base price.

[0089] Since the traditional carbon trading calculation model has a certain inhibitory effect on carbon emissions, but the single transaction and insufficient execution result in the inability to maximize the restriction of carbon emissions, in order to further restrict carbon emissions, this embodiment adopts a ladder-type carbon trading mechanism with multiple trading intervals, and its model expression is shown in formula (10).

[0090] The carbon trading base price is generally affected by policies and the market. The price difference between adjacent levels is σδ. The relationship between the carbon trading price and the trading volume is as follows: Figure 4 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 usage can be reduced or shifted, the available capacity during peak hours can be increased, and RIES can be promoted to achieve supply and demand balance.

[0093] Interruptible load is a type of incentive-based demand response, which is characterized by low energy supply reliability requirements, such as indoor lighting and heating needs. The government department signs a call agreement with the user, and the user selectively interrupts the energy-consuming equipment in certain periods according to the market incentive mechanism, so that the total consumption decreases to achieve supply and demand matching. For users who interrupt the load, they will receive some compensation according to the agreement. The expression of the interruptible model is:

[0094]

[0095] In the formula, They are the load values ​​before and after the interruptible load participates in demand response at time t; They are the load values ​​before and after the interruptible hydrogen load participates in demand response at time t; They are the load values ​​before and after the interruptible heat load participates in demand response at time t; They are the interruptible loads of electricity, hydrogen and heat at time t respectively.

[0096] In one embodiment, the transferable load is a type of price-based demand response, which is characterized by the energy demand being transferred from one period to another, while the total amount of the entire process remains unchanged. Through such measures, some energy-consuming equipment can be transferred from peak hours to off-peak hours, and at the same time, some compensation can be obtained. The expression of the transferable model is:

[0097]

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

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

[0100]

[0101] In the formula, is the total daily operating cost of the system; is the system's energy purchase cost; is the carbon trading cost of the system; The system’s wind and solar curtailment costs; is the demand response cost of the system.

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

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

[0104]

[0105] In the formula, T is the scheduling period of the system; The price of electricity purchased from the grid for the system; is the amount of electricity purchased in time t; is the water purchase price of the system; water is the water consumption coefficient of electrolysis water in SOEC mode; is the amount of hydrogen produced in time t; is the hydrogen purchase price of the system; is the amount of hydrogen purchased within time t; is the system's natural gas purchase price; is the amount of natural gas purchased during time t.

[0106] In one embodiment, the expression of the wind and solar power abandonment cost of the system is:

[0107]

[0108] In the formula, The unit abandonment penalty cost for the system; The penalty cost for unit wind curtailment in the system; is the abandoned optical power of the system at time t; is the wind power abandoned by the system at time t.

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

[0110]

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

[0117] Thermal power balance constraints:

[0118]

[0119] Hydrogen power balance constraints:

[0120]

[0121] Natural gas power balance constraints:

[0122]

[0123] In one embodiment, the equipment operation constraints include wind and solar power generator set operation constraints, RSOC operation constraints, cogeneration unit operation constraints, gas unit operation constraints, methanogenization unit constraints and energy storage constraints, specifically:

[0124] Wind and solar power generation constraints:

[0125]

[0126] Where P PV,min , P PV,max are the upper and lower output limits of PV respectively; P WG,min , P WG,max They are the upper and lower output limits of WG respectively.

[0127] RSOC operation constraints: RSOC has extremely low efficiency and poor climbing ability when running under low load conditions. In order to ensure the flexible and efficient operation of RSOC, the RSOC operation base power is limited. The RSOC output and climbing constraints and operating state constraints are expressed as:

[0128]

[0129] Where ΔP SOEC,down is the lower limit of SOFC ramp power; ΔP SOFC,up is the upper limit of SOFC ramp power; ΔP SOEC,down is the lower limit of SOEC climbing power; ΔP SOEC,up are the upper limit of SOEC climbing power; w t =0 or 1 is the RSOC operating state constraint parameter.

[0130] Combined heat and power unit operation constraints, namely CHP operation constraints:

[0131]

[0132] Where P CHP,min , P CHP,max are the upper and lower limits of CHP output respectively; ΔP CHP,ge,max , ΔP CHP,ge,minThey are the climbing and downhill power limits of CHP respectively.

[0133] Gas unit operation constraints, namely GB operation constraints:

[0134]

[0135] Where P GB,min , P GB,max are the upper and lower output limits of GB respectively; ΔP GB,ge,max , ΔP GB,ge,min These are GB's climbing and downhill power limits respectively.

[0136] Methanation unit constraints, namely MET unit constraints:

[0137]

[0138] Where P MET,min , P MET,max are the upper and lower limits of MET output respectively; ΔP MET,ge,max , ΔP MET,ge,min These are the climbing and descending power limits for MET respectively.

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

[0140] HES Constraints:

[0141]

[0142] In the formula, They are the maximum and minimum reserves of the HES unit; They are the starting reserves and ending reserves of the HES unit respectively; are the maximum values ​​of hydrogen charging and discharging power of the HES device respectively; A variable that is 0 or 1. The hydrogen charging and dehydrogenating conditions cannot be 0 or 1 at the same time.

[0143] TES constraints:

[0144]

[0145] In the formula, They are the maximum and minimum reserves of the TES unit, respectively; They are the starting reserves and ending reserves of the TES unit respectively; are the maximum values ​​of the charging and discharging power of the TES device, respectively; A variable that is 0 or 1. The charging and releasing conditions cannot be 0 or 1 at the same time.

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

[0147]

[0148] Where P el,buy,max , P el,buy,min are the upper and lower limits of purchased power respectively; P hy,buy,max , P hy,buy,min are the upper and lower limits of hydrogen purchase power respectively; P gas,buy,max , P gas,buy,min They are the upper and lower limits of natural gas purchase power respectively.

[0149] In one embodiment, the demand response constraints include:

[0150] Interruptible load constraints:

[0151]

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

[0153] Transferable load constraints:

[0154]

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

[0156] In one embodiment, taking a comprehensive energy system of a park in the west as an example, its structure is as follows: Figure 2 As shown in Table 1, it is necessary to optimize the low-carbon scheduling of some equipment in the system according to the output of wind and solar clean energy and the conditions of electric load, heat load and hydrogen load. The photovoltaic benchmark power is 3500kW, the wind power benchmark power is 2500kW, the electric load benchmark power is 4000kW, the heat load benchmark power is 2000kW, and the hydrogen load benchmark power is 1500kW. The efficiency of each device in the system is shown in Table 1, the system equipment output range and climbing range parameters are shown in Table 2, other parameters are shown in Table 3, and parameters such as energy prices are shown in Table 4. Figure 5As shown in the figure, (a) is the purchase price, and (b) is the sales price. The K-means clustering algorithm is used to divide it into four typical days: spring, summer, autumn, and winter. The typical renewable energy output curve and load curve for each season are shown in Figure 6 As shown, (a) is the predicted output curve and load curve of typical renewable energy in spring; (b) is the predicted output curve and load curve of typical renewable energy in summer; (c) is the predicted output curve and load curve of typical renewable energy in autumn; (d) is the predicted output curve and load curve of typical renewable energy in winter. Its operation strategy: when the system has surplus electricity, SOEC converts electricity into hydrogen energy by electrolysis of water; when the system has insufficient electricity, SOFC converts hydrogen energy into electricity by combustion reaction. The specific strategy generation steps are as follows:

[0157] 1) Input clean energy data such as wind and solar resources and generate scenarios for them;

[0158] 2) Input carbon trading range, base price and other tiered carbon trading information;

[0159] 3) Construct the objective function with the minimum daily operating cost;

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

[0161] 5) Using 1 hour as the scheduling accuracy and typical day as the cycle, the Yalmip toolbox is used to call the CPLEX solver to perform low-carbon optimization scheduling on the solution model;

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

[0163] Table 1

[0164]

[0165] Table 2

[0166]

[0167]

[0168] Table 3

[0169]

[0170] On the other hand, the present invention also discloses a low-carbon dispatching system for an integrated energy system, comprising:

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

[0172] The first model building module is used to build a ladder-type carbon trading model and a demand response model according to the IES-RSOC framework;

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

[0174] In this specification, each embodiment is described in a progressive manner, and each embodiment focuses on the differences from other embodiments. The same or similar parts between the embodiments can be referred to each other. For the device disclosed in the embodiment, since it corresponds to the method disclosed in the embodiment, the description is relatively simple, and the relevant parts can be referred to the method part.

[0175] The above description of the disclosed embodiments enables one skilled in the art to implement or use the present invention. Various modifications to these embodiments will be apparent to one 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 present invention. Therefore, the present invention will not be limited to the embodiments shown herein, but rather to the widest scope consistent with the principles and novel features disclosed herein.

Claims

1. A low-carbon scheduling method for an integrated energy system, characterized in that: The specific steps are: Building an IES-RSOC architecture based on an integrated energy system, and building an integrated energy system scheduling model based on the IES-RSOC architecture; Construct a ladder-type carbon trading model and demand response model based on the IES-RSOC architecture; The ladder-type carbon trading model and the demand response model are introduced into the integrated energy system scheduling model, and a low-carbon scheduling model for the integrated energy system is constructed with the goal of minimizing operating costs and combined with constraints.

2. A low-carbon scheduling method for an integrated energy system according to claim 1, characterized in that: The comprehensive energy system scheduling model includes a clean power generation model, an RSOC model, a cogeneration unit model, a gas boiler model, a methanation model and an energy storage model.

3. A low-carbon scheduling method for an integrated energy system according to claim 1, characterized in that: The expression of the ladder carbon trading model is: In the formula, is the system's tiered carbon trading cost; σ is the carbon trading base price; δ is the growth rate of carbon trading prices at different tiers; M c is the purchase quota; p is the length of the carbon emission interval.

4. A low-carbon scheduling method for an integrated energy system according to claim 1, characterized in that: The demand response model includes an interruptible model and a transferable model.

5. A low-carbon scheduling method for an integrated energy system according to claim 4, characterized in that: The expression of the interruptible model is: In the formula, They are the load values ​​before and after the interruptible load participates in demand response at time t; They are the load values ​​before and after the interruptible hydrogen load participates in demand response at time t; They are the load values ​​before and after the interruptible heat load participates in demand response at time t; They are the interruptible loads of electricity, hydrogen and heat at time t respectively.

6. A low-carbon scheduling method for an integrated energy system according to claim 4, characterized in that: The expression of the transferable model is: In the formula, are the load values ​​of the transferable electric load before and after participating in demand response at time t; are the load values ​​of the transferable hydrogen load before and after it participates in demand response at time t; are the load values ​​before and after the transferable heat load participates in demand response at time t; are the transferable loads of electricity, hydrogen and heat respectively; are the loads transferred in and out at time t respectively; are the loads transferred in and out of hydrogen load at time t respectively; are the heat load transferred in and out at time t respectively.

7. A low-carbon scheduling method for an integrated energy system according to claim 1, characterized in that: The operating cost is the total daily operating cost, which is obtained based on the energy purchase cost, the ladder-type carbon trading cost, the wind and solar power abandonment cost and the demand response cost, and its expression is: In the formula, is the total daily operating cost of the system; is the system's energy purchase cost; is the carbon trading cost of the system; The system’s wind and solar curtailment costs; is the demand response cost of the system.

8. A low-carbon scheduling method for an integrated energy system according to claim 1, characterized in that: The constraints include power balance constraints, equipment operation constraints, energy purchase constraints and demand response constraints.

9. A low-carbon scheduling method for an integrated energy system according to claim 8, characterized in that: The equipment operation constraints include wind and solar power generator unit operation constraints, RSOC operation constraints, cogeneration unit operation constraints, gas unit operation constraints, methanation unit constraints and energy storage constraints.

10. A low-carbon dispatching system for an integrated energy system, characterized in that: include: An initial model building module, used to build an IES-RSOC architecture based on an integrated energy system, and to build an integrated energy system scheduling model according to the IES-RSOC architecture; The first model building module is used to build a ladder-type carbon trading model and a demand response model according to the IES-RSOC framework; The model optimization module is used to introduce the ladder-type carbon trading model and the demand response model into the integrated energy system scheduling model, and to construct a low-carbon scheduling model for the integrated energy system in combination with constraint conditions with the goal of minimizing operating costs.

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