Scheduling method for carbon capture of deep peak regulation coal-fired unit under consideration of new energy consumption

Abstract

The invention relates to a scheduling method for carbon capture of a deep peak regulation coal-fired unit under consideration of new energy consumption, and the method comprises the steps: constructing a comprehensive energy system which comprises a deep peak regulation coal-fired unit, a first device, a conventional coal-fired unit, a second device, a wind turbine generator, a gas-fired boiler, and a heat storage device; the first device and the second device respectively comprise a carbon capture device, a methane reactor, an electrolytic bath, a hydrogen storage device and a hydrogen fuel cell; establishing an operation model, a total operation cost model and a total load constraint condition of the integrated energy system; obtaining total load prediction data; obtaining wind power output prediction data; the scheduling strategy is obtained for the operation model, the total operation cost model and the total load constraint condition of the integrated energy system by taking the minimization of the total operation cost of the integrated energy system as the target, so that the coordination and unification of the safety, low carbon and low operation cost of the power system can be realized while the efficient consumption of new energy can be ensured.

Description

Technical Field

[0001] This application relates to the field of power system technology, and in particular to a dispatching method for carbon capture of deep peak-shaving coal-fired power units considering the consumption of new energy sources. Background Technology

[0002] Currently, the installed capacity and penetration rate of new energy sources, represented by wind power, in the power system continue to increase, and the clean energy transformation has yielded significant results. However, the inherent volatility, randomness, and anti-peak-shaving characteristics of new energy output pose unprecedented challenges to the real-time power balance and safe and stable operation of the power system.

[0003] To ensure the real-time power stability of the power system and maximize the absorption of randomly fluctuating renewable energy power, coal-fired power units, which traditionally bear the main responsibility for base load and peak shaving, are forced to frequently and for extended periods switch to deep peak shaving operation, or even to stable combustion operation at extremely low loads. However, this shift in operating mode has given rise to a series of serious problems.

[0004] First, from the perspective of power system safety, coal-fired power units are not designed for deep load variation conditions. When coal-fired power units are in a deep peak-shaving state far below their design operating conditions for extended periods, their core components face severe challenges, specifically a surge in the risk of boiler tube rupture and accelerated turbine wear. On the one hand, on the boiler side of a coal-fired power unit, combustion stability deteriorates sharply, and the uneven temperature field within the furnace easily leads to abnormal hydrodynamic circulation, causing localized overheating or alternating thermal stress on key heating surfaces such as water-cooled walls. This significantly increases the risk of tube rupture and leakage, becoming the primary cause of unplanned unit shutdowns. On the other hand, on the turbine side of a coal-fired power unit, the decrease in steam flow and parameters under low-load conditions leads to reduced efficiency of flow-through components and may trigger blade vibration, exacerbating wear and fatigue damage to components such as rotors and blades, and shortening equipment service life.

[0005] Secondly, from the perspective of the economic (low operating cost) and environmental (low carbon emission) aspects of the power system, in order to maintain stable combustion under deep peak shaving conditions, coal-fired units often need to inject oil to assist combustion, which directly increases the expensive fuel costs. At the same time, the coal consumption for power generation of coal-fired units increases significantly under low load, and the operating costs increase substantially. The high maintenance costs and equipment damage caused by frequent start-ups and shutdowns and deep peak shaving further increase the operating costs of the power system.

[0006] In summary, the existing power system faces a dilemma when dealing with a high proportion of renewable energy integration: if priority is given to ensuring renewable energy consumption, the safety and economy of the power system must be sacrificed; if the peak-shaving depth of coal-fired units is limited in order to ensure the safety and economy of the power system, a large amount of wind curtailment will result, sacrificing the environmental friendliness of the power system.

[0007] Therefore, there is an urgent need to provide a scheduling method to ensure the coordinated unity of the security, environmental protection and economy of the power system while ensuring the efficient consumption of new energy on the premise of ensuring the real-time power stability of the power system. Summary of the Invention

[0008] The present application provides a scheduling method for carbon capture of a deep peak shaving coal-fired unit considering the consumption of new energy, which can ensure the coordinated unity of the security, environmental protection and economy of the power system while ensuring the efficient consumption of new energy on the premise of ensuring the real-time power stability of the power system.

[0009] The present application provides a scheduling method for carbon capture of a deep peak shaving coal-fired unit considering the consumption of new energy, including: Construct a comprehensive energy system, including: a deep peak shaving coal-fired unit, a first device for capturing and utilizing carbon dioxide configured in cooperation with the deep peak shaving coal-fired unit, a conventional coal-fired unit, a second device for capturing and utilizing carbon dioxide configured in cooperation with the conventional coal-fired unit, a wind turbine, a gas boiler and a heat storage device; each of the first device and the second device includes a carbon capture device, a methane reactor, an electrolyzer, a hydrogen storage device and a hydrogen fuel cell; the carbon capture device has the performance of rich and lean liquid decoupling; Establish an operation model of the comprehensive energy system; establish a total operation cost model of the comprehensive energy system; establish a total load constraint condition of the comprehensive energy system, and the total load includes electric, heat and gas loads; Obtain total load prediction data, which includes electric load prediction data, heat load prediction data and gas load prediction data; obtain wind power output prediction data; With the goal of minimizing the total operation cost of the comprehensive energy system, for the operation model, the total operation cost model and the total load constraint condition of the comprehensive energy system, obtain a scheduling strategy.

[0010] The scheduling method provided by the present application: Through the carbon capture devices with the performance of rich and lean liquid decoupling in the first and second devices, the rich liquid generated during the period with low electric load and large wind power output can be stored for use during the period with high electric load and small wind power output, thus having the characteristic of "virtual energy storage"; through the electrolyzer, hydrogen storage device and hydrogen fuel cell in the first and second devices, the excess wind power during the period with low electric load and large wind power output can be incorporated into the power grid during the period with high electric load and small wind power output, thus having the characteristic of "energy time-space transfer".

[0011] By utilizing the carbon capture device, electrolytic cell, hydrogen storage device, and hydrogen fuel cell with lean and rich liquid decoupling capabilities in the first and second units, and coordinating them with a deep peak-shaving coal-fired power unit, the "virtual energy storage" characteristic of the carbon capture device, along with the "energy spatiotemporal transfer" characteristics of the electrolytic cell, hydrogen storage device, and hydrogen fuel cell, can the following be achieved: Firstly, during periods of low electricity load and high wind power output, wind power is consumed through carbon dioxide capture and hydrogen production, achieving efficient or even 100% wind power utilization. Conversely, during periods of high electricity load and low wind power output, wind power utilization is even stronger. Therefore, throughout the entire dispatch cycle, efficient or even 100% wind power utilization can be achieved, preventing deep peak-shaving coal-fired units from entering deep peak-shaving mode. This fundamentally reduces the risk of boiler tube rupture and turbine wear in coal-fired units. Thus, the safety of deep peak-shaving coal-fired units is ensured, thereby contributing to the safety of the power system, and consequently, the integrated energy system.

[0012] Secondly, during periods of low electricity load and high wind power output, the captured carbon dioxide is stored in rich liquid and the produced hydrogen is stored in hydrogen storage devices. During periods of high electricity load and low wind power output, carbon dioxide capture is stopped to reduce the energy consumption of carbon capture coal-fired power plants, and hydrogen production is stopped to generate electricity using the hydrogen stored in the hydrogen storage devices, thereby increasing the grid-connected power of carbon capture coal-fired power plants. Therefore, electricity load demand is met, and the real-time power stability of the integrated energy system is ensured.

[0013] Thirdly, since wind power can be efficiently absorbed or even 100% absorbed throughout the entire dispatch cycle, the amount of coal consumed and carbon emissions are reduced when the grid-connected power of carbon capture coal-fired power plants are the same. Therefore, the environmental friendliness (low carbon) of the integrated energy system can be achieved.

[0014] Fourthly, since wind power can be efficiently absorbed, even at 100%, throughout the entire dispatch cycle, deep peak-shaving coal-fired units will not enter deep peak-shaving mode, reducing oil-fired power input costs. During periods of high electricity load and low wind power output, the large amount of heat released during the conversion of hydrogen energy into electricity via hydrogen fuel cells is supplied to gas-fired boilers to replace natural gas combustion for heat generation, thereby reducing carbon trading costs. Therefore, the economic efficiency (low operating costs) of the integrated energy system can be achieved.

[0015] Fifthly, during periods of low electricity load and high wind power output, carbon dioxide is captured and methane is produced, which in turn produces natural gas. During periods of high electricity load and low wind power output, although carbon dioxide capture ceases, methane is produced using stored rich liquid, which is then used to produce natural gas. Therefore, throughout the entire dispatch cycle, the gas boiler's demand for natural gas is met, the gas load demand is met, and with the gas boiler's natural gas demand met, the heat load demand is also met. Thus, both the gas load demand and the heat load demand can be satisfied.

[0016] Therefore, the dispatching method provided in this application can ensure the efficient absorption of new energy sources while guaranteeing the real-time power stability of the power system, and achieve a coordinated unity of power system security, environmental protection and economy, that is, a coordinated unity of power system security, low carbon and low operating costs. Attached Figure Description

[0017] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0018] The technical solution and other beneficial effects of this application will become apparent from the following detailed description of specific embodiments in conjunction with the accompanying drawings.

[0019] Figure 1 A flowchart illustrating the scheduling method for carbon capture of deep peak-shaving coal-fired power units under the consideration of renewable energy consumption, provided in the embodiments of this application.

[0020] Figure 2 This is a structural block diagram of an integrated energy system provided in an embodiment of this application.

[0021] Figure 3 for Figure 2 The diagram shows the structural block diagram of the carbon capture device.

[0022] Figure 4 The electricity, heat, and gas load demand curves and wind power output prediction curves provided for embodiments of this application are shown.

[0023] Figure 5 The scheduling result diagram of Scheme 1 provided for comparison in this application; wherein, Figure 5 a is the electrical load balance diagram. Figure 5 b is the hydrogen balance diagram. Figure 5 c is the gas load balance diagram. Figure 5 d is the heat load balance diagram.

[0024] Figure 6Schematic diagram of the scheduling result of Scheme 2 provided for the comparative example of this application; where Figure 6 a is the electrical load balance diagram, Figure 6 b is the hydrogen balance diagram, Figure 6 c is the gas load balance diagram, Figure 6 d is the heat load balance diagram.

[0025] Figure 7 Schematic diagram of the scheduling result of Scheme 3 provided for the comparative example of this application; where Figure 7 a is the electrical load balance diagram, Figure 7 b is the hydrogen balance diagram, Figure 7 c is the gas load balance diagram, Figure 7 d is the heat load balance diagram.

[0026] Figure 8 Schematic diagram of the scheduling result of Scheme 4 provided for the embodiment of this application; where Figure 8 a is the electrical load balance diagram, Figure 8 b is the hydrogen balance diagram, Figure 8 c is the gas load balance diagram, Figure 8 d is the heat load balance diagram.

[0027] Figure 9 Power curve diagram of the deep peak shaving coal-fired unit in Schemes 1, 2, 3, and 4 provided for this application. Detailed implementation manners

[0028] Next, the technical solutions in the embodiments of this application will be clearly and completely described in conjunction with the accompanying drawings in the embodiments of this application. Obviously, the described embodiments are only a part of the embodiments of this application, rather than all the embodiments. Based on the embodiments in this application, all other embodiments obtained by those skilled in the art without creative efforts belong to the protection scope of this application.

[0029] Please refer to Figure 1 and Figure 2 , the embodiment of this application provides a scheduling method for a deep peak shaving coal-fired unit with carbon capture considering new energy consumption, including Step 110, Step 120, Step 130, and Step 140.

[0030] Step 110, construct an integrated energy system, the integrated energy system includes: a deep peak shaving coal-fired unit, a first device for capturing and utilizing carbon dioxide configured in a supporting manner with the deep peak shaving coal-fired unit, a conventional coal-fired unit, a second device for capturing and utilizing carbon dioxide configured in a supporting manner with the conventional coal-fired unit, a wind turbine, a gas boiler, and a heat storage device; each of the first device and the second device includes a carbon capture device, a methane reactor, an electrolyzer, a hydrogen storage device, and a hydrogen fuel cell; the carbon capture device has a rich and lean liquid decoupling performance.

[0031] Step 120: Establish the operation model of the integrated energy system; establish the total operating cost model of the integrated energy system; establish the total load constraints of the integrated energy system, wherein the total load includes electricity, heat and gas loads.

[0032] Step 130: Obtain total load forecast data, which includes electricity load forecast data, heat load forecast data and gas load forecast data; obtain wind power output forecast data.

[0033] Step 140: With the goal of minimizing the total operating cost of the integrated energy system, a scheduling strategy is obtained from the operating model of the integrated energy system, the total operating cost model, and the total load constraints.

[0034] It is understood that deep peak-shaving coal-fired power units refer to those capable of operating at less than 50% of their rated power. The dispatch strategy obtained through solving is the optimal dispatch strategy. This dispatch strategy, obtained through solving, includes the operating condition data of the integrated energy system. Using this integrated energy system operating condition data, the various devices within the integrated energy system, including deep peak-shaving coal-fired power units, the first device, conventional coal-fired power units, the second device, wind turbines, gas-fired boilers, and thermal storage devices, are regulated. This achieves a coordinated balance between power system safety, environmental protection, and economy, ensuring efficient absorption of new energy sources while maintaining real-time power stability. In other words, it achieves a coordinated balance between power system safety, low carbon emissions, and low operating costs.

[0035] Understandably, when the new energy source is wind power, the "high efficiency" in the efficient consumption of new energy refers to minimizing wind curtailment.

[0036] For example, in the embodiments of this application, the operation model, total operating cost model and total load constraints of the integrated energy system can be established on the MATLAB (Matrix Laboratory) platform using the optimization tool YALMIP, and the scheduling strategy can be obtained by solving the problems using the CPLEX solver.

[0037] Understandably, deep peak-shaving coal-fired power units convert the chemical energy in coal into electrical energy through combustion, while producing carbon dioxide as a byproduct. Conventional coal-fired power units, on the other hand, also convert the chemical energy in coal into electrical energy through combustion, producing carbon dioxide as a byproduct. The lower limit of the electrical load for deep peak-shaving coal-fired power units can be lower than 50%, for example, as low as 30%, but the lower limit for the electrical load of conventional coal-fired power units cannot be lower than 50%. This is determined by the structural differences between deep peak-shaving and conventional coal-fired power units.

[0038] An electrolyzer for electrolyzing water to produce hydrogen. A hydrogen storage device for storing the hydrogen produced by the electrolyzer. A hydrogen fuel cell for converting the chemical energy of hydrogen into electrical energy by chemically reacting the hydrogen produced by the electrolyzer and / or stored in the hydrogen storage device with oxygen.

[0039] A carbon capture device for capturing, storing and releasing carbon dioxide, which is the carbon dioxide generated by burning coal in a deep peak-shaving coal-fired power unit or a conventional coal-fired power unit. The carbon capture device has the property of lean-rich liquid decoupling, which means that the lean liquid and the rich liquid are stored separately. A methane reactor for producing methane by chemically reacting the carbon dioxide released by the carbon capture device with the hydrogen produced by the electrolyzer. A gas-fired boiler for burning natural gas to generate heat. It can be understood that methane can be used to produce natural gas. A heat storage device for storing the heat generated by the gas-fired boiler. A wind turbine for converting wind energy into electrical energy.

[0040] Please refer to Figure 3 , in some embodiments, the carbon capture device in step 110 includes an absorption tower, a rich liquid tank, a regeneration tower and a lean liquid tank connected in sequence; the absorption tower is used to capture carbon dioxide with lean liquid to form rich liquid, the rich liquid tank is used to store rich liquid, the regeneration tower is used to regenerate the rich liquid to release carbon dioxide to form lean liquid, and the lean liquid tank is used to store lean liquid and transport the lean liquid to the absorption tower; The integrated energy system includes a carbon capture coal-fired power plant; the carbon capture coal-fired power plant includes a first carbon capture coal-fired power plant and a second carbon capture coal-fired power plant; wherein, the first carbon capture coal-fired power plant includes the deep peak-shaving coal-fired power unit, the carbon capture device and the methane reactor configured in support of the deep peak-shaving coal-fired power unit, and the second carbon capture coal-fired power plant includes the conventional coal-fired power unit, the carbon capture device and the methane reactor configured in support of the conventional coal-fired power unit.

[0041] In some embodiments, the operation model of the integrated energy system in step 120 includes: the operation model of the deep peak-shaving coal-fired power unit, the operation model of the conventional coal-fired power unit, the operation model of the first device, the operation model of the second device, the operation model of the wind turbine, the operation model of the gas-fired boiler and the operation model of the heat storage device; The operation model of the deep peak-shaving coal-fired power unit includes the operation cost of the deep peak-shaving coal-fired power unit and the operation constraint conditions of the deep peak-shaving coal-fired power unit; The operation model of the conventional coal-fired power unit includes the operation cost of the conventional coal-fired power unit and the operation constraint conditions of the conventional coal-fired power unit; The operating models of the first device and the second device each include an operating model of a carbon capture device, an operating model of a methane reactor, an operating model of an electrolyzer, an operating model of a hydrogen storage device, and an operating model of a hydrogen fuel cell.

[0042] It should be noted that the operating costs of deep peak-shaving coal-fired power units and conventional coal-fired power units in the operating model are the same as the operating costs of deep peak-shaving coal-fired power units and conventional coal-fired power units in the operating cost of deep peak-shaving coal-fired power units, which will be explained together in the following sections.

[0043] The specific details of the operating constraints for deep peak-shaving coal-fired power units are explained below.

[0044] In some embodiments, the operating constraints of the deep peak-shaving coal-fired power unit in step 120 include: output constraints of the deep peak-shaving coal-fired power unit, ramp rate constraints of the deep peak-shaving coal-fired power unit, and minimum start-up and shutdown time constraints of the deep peak-shaving coal-fired power unit.

[0045] In some embodiments, the output constraint condition of the deep peak-shaving coal-fired unit is expressed as: , In the formula: This represents the maximum power generation of deep peak-shaving coal-fired units; This is the lower limit for oil injection peak shaving in deep peak-shaving coal-fired power units; is the working status parameter of the deep peak-shaving coal-fired unit in time period t, with a value of 0 or 1, where 0 represents the stopped state and 1 represents the running state. This represents the power generation of the deep peak-shaving coal-fired unit in the t-th time period; T refers to dividing a scheduling cycle into T time periods of equal length, and t refers to the t-th time period within a scheduling cycle, t=1,2,3…T.

[0046] It should be noted that in the following content of the embodiments of this application, T and t are interpreted in the same way as follows: T refers to dividing a scheduling period into T time periods of equal length, and t refers to the t-th time period within a scheduling period, t=1,2,3…T.

[0047] For example, when a scheduling period of 24 hours is divided into 24 time periods of equal length, T=24, t=1,2,3…24. When a scheduling period of 24 hours is divided into 48 time periods of equal length, T=48, t=1,2,3…48.

[0048] In some embodiments, the ramp rate constraint condition for the deep peak-shaving coal-fired unit is expressed as follows:

[0049] In the formula: This is the upper limit of the ramp rate for deep peak-shaving coal-fired power units. This is the lower limit of the ramp rate for deep peak-shaving coal-fired power units. This represents the power generation of the deep peak-shaving coal-fired unit during period t. This represents the power generation of the deep peak-shaving coal-fired unit during the t-1 period.

[0050] In some embodiments, the minimum start-up and shutdown time constraint condition for the deep peak-shaving coal-fired power unit is expressed as follows: , In the formula: T refers to dividing a scheduling cycle into T time periods of equal length, t refers to the t-th time period within a scheduling cycle, t=1,2,3…T; The total number of time periods corresponding to the maximum continuous operating time of deep peak-shaving coal-fired power units; This represents the total number of time periods corresponding to the maximum continuous shutdown time of deep peak-shaving coal-fired power units; based on the value of t, the value of k is k = t, t+1, ..., t+ -1; These are the operating status parameters of the deep peak-shaving coal-fired power units in the k-th time period. The value can be 0 or 1, where 0 represents a stopped state and 1 represents a running state. These are the operating status parameters of the deep peak-shaving coal-fired power units in time period t. The value can be 0 or 1, where 0 represents a stopped state and 1 represents a running state. This is the operating status parameter for the deep peak-shaving coal-fired power unit in the (t-1)th time period. The value is 0 or 1, where 0 represents the stopped state and 1 represents the running state.

[0051] The specific details of the operating constraints for conventional coal-fired power units are explained below.

[0052] In some embodiments, the operating constraints of the conventional coal-fired power unit in step 120 include: the output constraint of the conventional coal-fired power unit and the ramp-up rate constraint of the conventional coal-fired power unit.

[0053] The output constraint condition of the conventional coal-fired power unit is expressed as follows: , In the formula: This is the maximum power generation capacity of a conventional coal-fired unit; This is the lower limit for oil injection peak shaving in conventional coal-fired power units; These are the operating status parameters of a conventional coal-fired power unit during time period t. A value that is always 1 indicates that the device is always in a running state. This represents the power generation of a conventional coal-fired unit in time period t; T refers to dividing a scheduling cycle into T time periods of equal length, and t refers to the t-th time period within a scheduling cycle, where t = 1, 2, 3…T.

[0054] In some embodiments, the ramp rate constraint condition for conventional coal-fired power units is expressed as follows:

[0055] In the formula: This represents the upper limit of the ramp rate for conventional coal-fired power units. This is the lower limit of the downhill ramp rate for conventional coal-fired power units. This represents the power generation of a conventional coal-fired unit during time period t. This represents the power generation of a conventional coal-fired unit during the t-1 time period.

[0056] The specific details of the operation models of the first and second devices are explained below.

[0057] In some embodiments, the operating model of the carbon capture device of the first device and the second device includes the energy consumption model of the carbon capture device and the operating model of the lean liquid tank and the rich liquid tank.

[0058] In some embodiments, the energy consumption model of the carbon capture device of the first device is expressed as follows:

[0059] In the formula: The power generation of the deep peak-shaving coal-fired unit in time period t; The net output electricity of the first carbon capture coal-fired power plant in time period t; Let t be the carbon capture energy consumption of the first carbon capture coal-fired power plant during the t-th time period; This represents the basic energy consumption of the first carbon capture coal-fired power plant. Let t be the operating energy consumption of the first carbon capture coal-fired power plant during time period t; The operating energy consumption coefficient of the carbon capture device; Let t represent the total CO2 generation of the deep peak-shaving coal-fired power unit in time period t. Carbon emission intensity of deep peak-shaving coal-fired power units; The parameters for the oil-fired stable combustion state of the deep peak-shaving coal-fired unit in time period t are given. The value can be 0 or 1, where 0 means not entering the fuel injection and stable combustion state, and 1 means entering the fuel injection and stable combustion state. This refers to the oil consumption of the coal-fired power unit in the deep peak shaving stage during the oil injection phase, specifically the oil consumption in time period t. Let be the amount of CO2 absorbed by the absorption tower in time period t; is the flue gas diversion ratio of the first carbon capture coal-fired power plant in the t-th period, and the flue gas diversion ratio is the ratio of carbon dioxide collection and carbon dioxide evacuation; μ1 is the absorption efficiency of the absorption tower; is the amount of CO2 regeneration required to be processed by the regeneration tower in the t-th period; μ2 is the regeneration efficiency of the regeneration tower; is the CO2 outflow from the rich liquid tank in the t-th period, being positive indicates that CO2 flows from the rich liquid tank to the regeneration tower, being negative indicates that CO2 flows from the absorption tower to the rich liquid tank; is the actual CO2 capture amount of the carbon capture device in the t-th period. It can be understood that the carbon capture energy consumption of the first carbon capture coal-fired power plant is also the energy consumption of the carbon capture device配套 with the deep peak shaving coal-fired unit.

[0060] The energy consumption model of the carbon capture device of the second device is established according to the energy consumption model of the carbon capture device of the first device. The specific method is: replace the deep peak shaving coal-fired unit in the energy consumption model of the carbon capture device of the first device with a conventional coal-fired unit, the first carbon capture coal-fired power plant with a second carbon capture coal-fired power plant, and the first device with the second device, taking a value of constantly 0, representing that the conventional coal-fired unit does not enter the oil stabilizing combustion state, and the energy consumption model of the carbon capture device of the second device can be obtained.

[0061] In some embodiments, the operation models of the lean liquid tanks and rich liquid tanks of the first device and the second device are expressed as:

[0062] In the formula: is the density of the CO2 solution in the rich liquid tank; is the CO2 outflow from the rich liquid tank in the t-th period, being positive indicates that CO2 flows from the rich liquid tank to the regeneration tower, being negative indicates that CO2 flows from the absorption tower to the rich liquid tank; is the solution outflow or inflow of the lean liquid tank in the t-th period, being positive indicates the outflow, being negative indicates the inflow, and the inflow of the lean liquid tank is the same as the outflow of the rich liquid tank at the same moment; is the solution outflow or inflow of the rich liquid tank in the t-th period, being positive indicates the outflow, being negative indicates the inflow, and the inflow of the lean liquid tank is the same as the outflow of the rich liquid tank at the same moment; is the solution storage of the lean liquid tank in the t-th period; is the solution storage of the lean liquid tank in the (t - 1)-th period; This refers to the solution storage capacity of the lean solution tank at the beginning of the 0th time period, which is the start of a scheduling cycle. The solution storage capacity of the lean solution tank during time period T; Let t be the solution storage capacity of the rich liquid tank during time period t. The solution storage capacity of the rich liquid tank during the (t-1)th time period; This refers to the solution storage capacity of the rich liquid tank at the beginning of time period 0, which is the start of a scheduling cycle. The solution storage capacity of the rich liquid tank during time period T; This is the maximum storage volume of the lean liquid tank; This is the maximum liquid storage volume of the rich liquid tank.

[0063] It is understandable that the energy consumption model of the carbon capture device will include the power generation of the first carbon capture coal-fired power plant in time period t. Decomposed into the net output power of the first carbon capture coal-fired power plant Carbon capture energy consumption compared to the first carbon capture coal-fired power plant The energy consumption of carbon capture Further including basic energy consumption and CO2 regeneration Proportional operating energy consumption .

[0064] By storing and releasing solutions in lean and rich solution tanks, dynamic decoupling of the processing capacity of the absorption tower and regeneration tower is achieved.

[0065] In some embodiments, the operating model of the methane reactors in the first and second devices is expressed as follows: , In the formula: Let t be the hydrogen input power of the methane reactor during time period t; Let t be the methane output power of the methane reactor during time period t; The energy conversion efficiency of a methane reactor; This represents the maximum methane output power of the methane reactor. This represents the upper limit of the ramp rate for the methane reactor; The lower limit of the ramp-up rate for the methane reactor; T refers to dividing a scheduling cycle into T time periods of equal length, and t refers to the t-th time period within a scheduling cycle, t=1,2,3…T.

[0066] In some embodiments, the operating model of the electrolytic cells of the first device and the second device is expressed as follows: , In the formula: Let t be the hydrogen output power of the electrolyzer during time period t; The energy conversion efficiency of the electrolytic cell; Let be the electrical input power of the electrolytic cell in time period t; This refers to the maximum electrical input power of the electrolytic cell; The upper limit of the ramp rate for the power input of the electrolytic cell; This is the lower limit of the ramp rate of the power input to the electrolytic cell.

[0067] In some embodiments, the operating model of the hydrogen fuel cells of the first device and the second device is expressed as follows: , In the formula: Let be the power output of the hydrogen fuel cell in time period t; For the power generation efficiency of hydrogen fuel cells; Let t be the hydrogen input power of the hydrogen fuel cell in time period t; Let t be the thermal output power of the hydrogen fuel cell in time period t; For the heating efficiency of hydrogen fuel cells; This represents the maximum hydrogen input power of the hydrogen fuel cell; This represents the upper limit of the ramp rate for the hydrogen input power of a hydrogen fuel cell. This represents the lower limit of the ramp-up rate for the hydrogen input power of a hydrogen fuel cell.

[0068] In some embodiments, the operating model of the hydrogen storage device of the first device and the second device is expressed as follows:

[0069] In the formula: Let t be the storage capacity of the hydrogen storage device during time period t; This represents the storage capacity of the hydrogen storage device during the (t-1)th time period. Let t be the hydrogen storage power of the hydrogen storage device in time period t; Let t be the hydrogen release power of the hydrogen storage device during time period t; The hydrogen storage efficiency of the hydrogen storage device; This represents the upper limit of the hydrogen storage capacity of the hydrogen storage device; This represents the lower limit of the hydrogen storage capacity of the hydrogen storage device. This represents the maximum single-use hydrogen storage power of the hydrogen storage device. This represents the maximum single hydrogen release power of the hydrogen storage device; These are the hydrogen storage and release status parameters of the hydrogen storage device during time period t. The value can be 0 or 1. A value of 0 indicates the hydrogen release state, and a value of 1 indicates the hydrogen storage state.

[0070] In some embodiments, the operating model of the thermal storage device is expressed as: , In the formula: Let t be the storage capacity of the thermal energy storage device during time period t. This represents the storage capacity of the thermal energy storage device during the (t-1)th time period. Let t be the thermal storage power of the thermal storage device during time period t; Let t be the heat release power of the thermal storage device during time period t; The thermal storage efficiency of the thermal storage device; This is the upper limit of the thermal storage capacity of the thermal storage device; This represents the lower limit of the thermal storage capacity of the thermal storage device. This represents the maximum single-use thermal storage power of the thermal storage device. This represents the maximum heat release power of the thermal storage device in a single operation. These are the heat storage and heat release state parameters of the thermal storage device during time period t. The value can be 0 or 1. A value of 0 indicates a heat release state, and a value of 1 indicates a heat storage state. T refers to dividing a scheduling cycle into T time periods of equal length.

[0071] In some embodiments, the operating model of the gas-fired boiler is expressed as: , In the formula: This refers to the heat output power of the gas-fired boiler. The overall efficiency of the gas-fired boiler; The natural gas input power for the gas-fired boiler; This is the maximum heat output power of the gas-fired boiler. The upper limit of the ramp-up rate of the heat output power of a gas-fired boiler; This represents the lower limit of the ramp-up rate for the heat output power of a gas-fired boiler.

[0072] In some embodiments, the operating model of the wind turbine is expressed as:

[0073] In the formula: The operating cost of the wind turbine unit; T refers to dividing a scheduling cycle into T time periods of equal length, and t refers to the t-th time period within a scheduling cycle, t=1,2,3…T; Let t be the grid-connected power of the wind turbines in time period t; The maximum grid-connected power of the wind turbine in time period t; This is the operating cost coefficient for wind turbine units; This represents the minimum grid connection coefficient for wind turbine units.

[0074] In some embodiments, the total operating cost model of the integrated energy system in step 120 includes: The total operating cost of the integrated energy system includes the operating cost of deep peak-shaving coal-fired units, the operating cost of conventional coal-fired units, the carbon trading cost of the integrated energy system, the carbon sequestration cost of the integrated energy system, the operating cost of wind turbine units, and the gas purchase cost of the integrated energy system.

[0075] The total operating cost model of the integrated energy system is expressed as follows: , In the formula, The total operating cost of the integrated energy system; To reduce the operating costs of deep peak-shaving coal-fired power units; The operating cost of a conventional coal-fired power unit; The carbon trading cost of the integrated energy system; The cost of carbon sequestration for integrated energy systems; For wind turbine operating costs; This refers to the cost of purchasing gas for the integrated energy system. It's understandable that purchasing gas refers to buying methane.

[0076] The following section details the operating costs of deep peak-shaving coal-fired power units.

[0077] In some embodiments, the operating costs of the deep peak-shaving coal-fired power unit include: The operating costs of deep peak-shaving coal-fired power units, the fuel costs of deep peak-shaving coal-fired power units, the start-up and shutdown costs of deep peak-shaving coal-fired power units, the life loss costs of deep peak-shaving coal-fired power units, the oil injection costs of deep peak-shaving coal-fired power units, and the environmental costs of deep peak-shaving coal-fired power units.

[0078] The operating cost of the deep peak-shaving coal-fired power unit The expression is as follows: , in, To reduce the operating costs of deep peak-shaving coal-fired power units; To reduce fuel costs for deep peak-shaving coal-fired power units; Costs of starting and stopping deep peak-shaving coal-fired power units; The lifespan loss cost incurred by deep peak shaving coal-fired power units; To reduce the cost of oil injection for deep peak-shaving coal-fired power units; Environmental costs of deep peak-shaving coal-fired power units; The operating cost of conventional coal-fired power units The expression is as follows: , in, The operating cost of a conventional coal-fired power unit; Fuel costs for conventional coal-fired power units; Environmental costs of conventional coal-fired power units.

[0079] In some embodiments, the fuel cost of the deep peak-shaving coal-fired unit The expression is as follows:

[0080] In the formula: The fuel cost of a deep peak-shaving coal-fired power unit is given by a1, b1, and c1, which are the coal consumption coefficients of the deep peak-shaving coal-fired power unit, respectively. This represents the power generation of the deep peak-shaving coal-fired unit in the t-th time period; T refers to dividing a scheduling cycle into T time periods of equal length, and t refers to the t-th time period within a scheduling cycle, t=1,2,3…T.

[0081] In some embodiments, the start-up and shutdown costs of the deep peak-shaving coal-fired power unit The expression is:

[0082] In the formula: Costs of starting and stopping deep peak-shaving coal-fired power units; The binary variable represents the operating state of the coal-fired power unit in time period t. The value can be 0 or 1. A value of 0 indicates a stopped state. A value of 1 indicates the start state; S The cost of starting up a deep peak-shaving coal-fired power unit once.

[0083] In some embodiments, the lifespan loss cost generated by deep peak shaving of the coal-fired power unit The expression is: , In the formula: c represents the lifespan loss cost of deep peak shaving coal-fired power units; c represents the purchase cost of deep peak shaving coal-fired power units. This represents the power generation of the deep peak-shaving coal-fired unit during period t. For the number of rotor-induced cracking cycles, Rotor cracking cycles With deep peak-shaving coal-fired power units The functional relationship is as follows: τ1 is the wear coefficient of the coal-fired power unit with no oil injection depth for peak shaving; τ2 is the wear coefficient of the coal-fired power unit with oil injection depth for peak shaving. This refers to the upper limit of oil injection for peak shaving in deep peak-shaving coal-fired power units; This is the lower limit for oil injection peak shaving in deep peak-shaving coal-fired power units; This represents the maximum power generation of deep peak-shaving coal-fired units; This is the minimum power generation capacity for deep peak-shaving coal-fired power units.

[0084] In some embodiments, the oil injection cost of the deep peak-shaving coal-fired unit is expressed as: , In the formula: To reduce the cost of oil injection for deep peak-shaving coal-fired power units; This refers to the upper limit of oil injection for peak shaving in deep peak-shaving coal-fired power units; This is the lower limit for oil injection peak shaving in deep peak-shaving coal-fired power units; This represents the maximum power generation of deep peak-shaving coal-fired units; P oil The price of oil in the current season; This refers to the oil consumption of the coal-fired power unit in the deep peak shaving stage during the oil injection phase, specifically the oil consumption in time period t. This represents the power generation of the deep peak-shaving coal-fired unit during period t.

[0085] In some embodiments, the environmental cost of the deep peak-shaving coal-fired unit The expression is: , In the formula: Environmental costs of deep peak-shaving coal-fired power units; j For the first j Various pollutants; J The types of taxable pollutants; K The amount of tax payable per pollution equivalent; The first generation produced per unit of coal combustion j Quality of various pollutants; This refers to the environmental protection devices configured for deep peak-shaving coal-fired power units to remove the first... j The efficiency of pollutant selection; For the first j Pollution equivalent of each pollutant; Let t be the coal consumption of the deep peak-shaving coal-fired power unit in the t-th time period.

[0086] In some embodiments, fuel costs of conventional coal-fired units The expression is: , In the formula: For conventional coal-fired power units, , and These are the coal consumption coefficients for conventional coal-fired power units. This represents the power generation of a conventional coal-fired unit during time period t.

[0087] In some embodiments, the environmental costs of conventional coal-fired power units The expression is: , In the formula: Environmental costs for conventional coal-fired power units; j For the first j Various pollutants; J The types of taxable pollutants; K The amount of tax payable per pollution equivalent; The first generation produced per unit of coal combustion j Quality of various pollutants; This refers to the removal of the first environmental protection device for conventional coal-fired power units. j The efficiency of pollutant selection; For the first j Pollution equivalent of each pollutant; Let be the coal consumption of a conventional coal-fired unit during time period t.

[0088] In some embodiments, the carbon trading cost of the integrated energy system The calculation formula is: , In the formula: denoted as α, representing the carbon trading cost of the integrated energy system; c represents the carbon trading benchmark price; α represents the carbon trading price growth rate; and d represents the carbon emission range step size. , For carbon trading volume of the integrated energy system, The actual carbon emissions of the integrated energy system. This is the initial carbon emission allowance for the integrated energy system.

[0089] The actual carbon emissions of the integrated energy system The calculation formula is: , In the formula: This is the sum of carbon emissions from the integrated energy system; This is the sum of the net carbon emissions from coal-fired power plants; This represents the actual carbon emissions from a gas-fired boiler. Carbon content per unit calorific value of natural gas; The carbon oxidation rate of natural gas; Thermoelectric conversion coefficient; t represents the natural gas input power of the gas-fired boiler during time period t; 44 / 12 represents the ratio of the relative molecular masses of CO2 to carbon.

[0090] It is understood that in the embodiments of this application, carbon emissions refer to carbon dioxide emissions, and carbon emission amount refers to carbon dioxide emission amount.

[0091] The initial carbon emission allowance for the integrated energy system , the calculation formula is: , In the formula: is the initial carbon emission quota of the integrated energy system; is the total initial carbon emission quota of the first carbon capture coal-fired power plant and the second carbon capture coal-fired power plant; is the initial carbon emission quota of the gas boiler; is the power supply reference value of the coal-fired unit; is the heat supply reference value of the gas boiler.

[0092] In some embodiments, the carbon sequestration cost of the integrated energy system , and the expression is: , , In the formula: is the carbon sequestration cost of the integrated energy system; is the cost required to sequester a unit of CO2; is the actual CO2 capture amount of the carbon capture device and the overall carbon capture device in the t-th period; is the amount of CO2 required for the operation of the power-to-gas device in the t-th period; the power-to-gas device includes an electrolyzer and a methane reactor配套 with the electrolyzer, as well as the electrolyzer and the methane reactor配套 with the electrolyzer; is the output power of the methane reactor in the t-th period; is the lower calorific value of natural gas; is the thermoelectric conversion coefficient; is the density of the CO2 provided to the power-to-gas device.

[0093] In some embodiments, the operating cost of the wind turbine , and the expression is: , In the formula: is the operating cost of the wind turbine; is the grid-connected power of the wind turbine in the t-th period; is the operating cost coefficient of the wind turbine.

[0094] In some embodiments, the gas purchase cost of the integrated energy system , and the expression is: , In the formula: is the gas purchase cost of the integrated energy system; is the unit price of natural gas purchased; is the thermoelectric conversion coefficient; Let t be the gas purchase capacity of the integrated energy system during time period t; This is the lower heating value of natural gas.

[0095] In some embodiments, the total load constraint of the integrated energy system in step 120 includes: , In the formula: Let t be the electrical load of the integrated energy system during time period t. Let t be the grid-connected power of the wind turbines in time period t; This represents the total net power output of the first and second carbon capture coal-fired power plants during time period t. The total input power of the electrolytic cells of the first and second devices in time period t; The total electrical output power of the hydrogen fuel cells in the first and second devices during time period t is denoted as t. This refers to the heat output power of the gas-fired boiler. The total thermal output power of the hydrogen fuel cells of the first and second devices in time period t; Let t be the heat load of the integrated energy system during time period t. Let t be the thermal storage power of the thermal storage device during time period t; Let t be the heat release power of the thermal storage device during time period t; This represents the total output power of the electrolytic cells in the first and second units during time period t. The total input power of the methane reactors in units one and two during time period t; The total hydrogen storage power of the first and second devices in time period t; The total hydrogen release power of the first and second devices in time period t; The total hydrogen input power of the hydrogen fuel cells in the first and second devices during time period t; Let t be the gas purchase capacity of the integrated energy system during time period t; The total output power of the methane reactors in units one and two during time period t; Let be the natural gas input power of the gas-fired boiler in time period t; Let t be the gas load of the integrated energy system during the t-th time period.

[0096] It is understood that, for example, the total electrical output power of the hydrogen fuel cells in the first and second devices refers to the sum of the electrical output power of the hydrogen fuel cells in the first device and the hydrogen fuel cells in the second device. Other similar expressions are explained in the same manner.

[0097] In this embodiment, the scheduling cycle is set to 24 hours, and a case simulation is performed on the system. The load demand curve and wind power output forecast curve can be referenced. Figure 1 The relevant parameters for each piece of equipment are listed in Table 1, while the low-carbon cost parameters are detailed in Table 2. The lower heating value of natural gas is 39 MJ / m³, and that of hydrogen is 11 MJ / m³, with a thermoelectric conversion efficiency of 3600 MJ / (MW·h). Furthermore, the market price of natural gas per unit volume is 3.79 yuan / m³, and the maximum wind curtailment rate is 10%. The entire system includes one 300MW conventional coal-fired unit, one 600MW deep peak-shaving coal-fired unit, one 150MW gas-fired boiler, one wind power station, two thermal storage units, two hydrogen storage units, two electrolyzers, two methane reactors, and two hydrogen fuel cells. It is understood that the power-to-gas conversion unit includes an electrolyzer and a methane reactor.

[0098] Table 1 Parameters of each device

[0099] Table 2 Low-carbon cost coefficient

[0100] To analyze the economics (low operating cost) of the scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption provided in the embodiments of this application, this application provides four schemes for comparative analysis. Schemes 1, 2, and 3 are comparative examples of this application, and Scheme 4 is an embodiment of this application.

[0101] Option 1: A scheduling method is provided, comprising: constructing a first comparison system, which includes coal-fired power plants (including conventional coal-fired units and deep peak-shaving coal-fired units), gas-fired boilers, hydrogen storage devices, thermal storage devices, wind turbines, electrolyzers, and hydrogen fuel cells (one electrolyzer and one hydrogen fuel cell are configured for each of the conventional coal-fired units and the deep peak-shaving coal-fired units, respectively). The objective function is to minimize the total cost of the first comparison system, including the operating costs of the coal-fired units, the operating costs of the gas-fired boilers, the operating costs of the wind power, the gas purchase cost of the first comparison system, and the carbon trading cost. It is understood that the scheduling method provided in Option 1 does not involve carbon capture retrofitting of the conventional coal-fired units or the deep peak-shaving coal-fired units; instead, the coal-fired power plants participate in the operation of the first comparison system.

[0102] Solution 2: Provide a scheduling method, including: constructing a second comparison system, the second comparison system includes a conventional coal-fired unit carbon capture coal-fired power plant (including a conventional coal-fired unit, a carbon capture device and a methane reactor configured with the conventional coal-fired unit; also including a deep peak shaving coal-fired unit), a gas boiler, a hydrogen storage device, a heat storage device, a wind turbine, an electrolyzer and a hydrogen fuel cell (one electrolyzer and one hydrogen fuel cell are respectively configured for each of the conventional coal-fired unit and the deep peak shaving coal-fired unit), and output a scheduling strategy with the minimum total cost of the second comparison system including the operating cost of the coal-fired unit, the operating cost of the gas boiler, the operating cost of the wind power, the gas purchase cost of the second comparison system, the carbon trading and carbon sequestration costs as the objective function. It can be understood that the scheduling method provided in Solution 2 only conducts carbon capture transformation on the conventional units, constructs a carbon capture coal-fired power plant, and participates in the operation of the second comparison system with the flexibly operating carbon capture coal-fired power plant.

[0103] Solution 3: Provide a scheduling method, including: constructing a third comparison system, the third comparison system includes a deep peak shaving coal-fired unit carbon capture coal-fired power plant (including a deep peak shaving coal-fired unit, a carbon capture device and a methane reactor configured with the deep peak shaving coal-fired unit; also including a conventional coal-fired unit), a gas boiler, a hydrogen storage device, a heat storage device, a wind turbine, an electrolyzer and a hydrogen fuel cell (one electrolyzer and one hydrogen fuel cell are respectively configured for each of the conventional coal-fired unit and the deep peak shaving coal-fired unit), and output a scheduling strategy with the minimum total cost of the third comparison system including the operating cost of the coal-fired unit, the operating cost of the gas boiler, the operating cost of the wind power, the gas purchase cost of the third comparison system, the carbon trading and carbon sequestration costs as the objective function. It can be understood that the scheduling method provided in Solution 3 only conducts carbon capture transformation on the deep peak shaving coal-fired unit to construct a carbon capture coal-fired power plant, and participates in the operation of the third comparison system with the flexibly operating carbon capture coal-fired power plant.

[0104] Solution 4: Provide a scheduling method, including: constructing an integrated energy system, the integrated energy system includes a conventional coal-fired unit and a deep peak shaving coal-fired unit carbon capture coal-fired power plant (including a conventional coal-fired unit and a carbon capture device and a methane reactor configured with the conventional coal-fired unit; also including a deep peak shaving coal-fired unit and a carbon capture device and a methane reactor configured with the deep peak shaving coal-fired unit), a gas boiler, a hydrogen storage device, a heat storage device, a wind turbine, an electrolyzer and a hydrogen fuel cell (one electrolyzer and one hydrogen fuel cell are respectively configured for each of the conventional coal-fired unit and the deep peak shaving coal-fired unit), and output a scheduling strategy with the minimum total cost of the integrated energy system including the operating cost of the coal-fired unit, the operating cost of the gas boiler, the operating cost of the wind power, the gas purchase cost of the integrated energy system, the carbon trading cost and the carbon sequestration cost as the objective function. It can be understood that the scheduling method provided in Solution 4 conducts carbon capture transformation on both the conventional coal-fired unit and the deep peak shaving coal-fired unit to construct a carbon capture coal-fired power plant, and participates in the system operation with the flexibly operating carbon capture coal-fired power plant.

[0105] It is understandable that in schemes 1, 2, 3, and 4, two steps are omitted for the sake of simplicity. One of these omitted steps is: establishing the system's operational model; establishing the system's total operating cost model; and establishing the system's total load constraints, where the total load includes electricity, heat, and gas loads. The other step is: obtaining total load forecast data, which includes electricity load forecast data, heat load forecast data, and gas load forecast data; and obtaining wind power output forecast data. It is understood that the systems mentioned in the above two steps refer to the first comparative system, the second comparative system, the third comparative system, and the integrated energy system in schemes 1, 2, 3, and 4.

[0106] Regarding the output of coal-fired units, since the lower limit of the electrical load for conventional coal-fired units cannot be lower than 50%, while the lower limit for the electrical load of deep peak-shaving coal-fired units can be lower than 50%, for example, as low as 30%, the dispatch strategies obtained from Schemes 1 to 4 prioritize changing the output of deep peak-shaving coal-fired units. This analysis mainly focuses on the output of deep peak-shaving coal-fired units. Table 3 below shows the cost distribution of the integrated energy system for Schemes 1 to 4: Table 3 Optimization results of Schemes 1 to 4

[0107] Please refer to Table 3. In terms of economics, Option 4 has the lowest total cost (3.6278 million yuan). Option 4 has the lowest total cost (3.6278 million yuan), which is 56,100 yuan lower than Option 1. The total costs of Options 2 and 3 are similar, but slightly higher than Option 4. This indicates that fully configuring carbon capture devices can bring more significant economic benefits. In addition, in Option 4, although the cost of coal increases due to the energy consumption of carbon capture, the cost of purchasing gas decreases significantly, and the cost of carbon trading is effectively controlled, ultimately achieving the optimal total cost.

[0108] In terms of environmental protection, Scheme 1 has the highest net carbon emissions (4407t). Schemes 2, 3, and 4, which are equipped with carbon capture devices, all stably control net carbon emissions at 3000t, a reduction of 26.72% compared to Scheme 1, demonstrating significant emission reduction effects. This proves that carbon capture devices are an effective means of deep decarbonization of the power system.

[0109] Regarding renewable energy consumption, Scheme 1 has a wind power utilization rate of 98%, but wind curtailment still exists. This is even with the configuration of electrolyzers, hydrogen storage tanks, and hydrogen fuel cells. Without these configurations, the wind curtailment would be even greater. In contrast, Schemes 2, 3, and 4 all have a wind power utilization rate of 100%, meaning they all achieve 100% wind power consumption. This is because Schemes 2, 3, and 4 are equipped with carbon capture devices. The flexible operation characteristics of carbon capture coal-fired power plants (by adjusting the rich and lean liquid tanks) allow them to be regarded as a kind of "virtual energy storage." By adjusting the carbon capture energy consumption, the net output can be flexibly changed, thereby providing the system with additional regulation capabilities, effectively smoothing wind power fluctuations, and promoting renewable energy consumption.

[0110] Please refer to Table 3. Schemes 2 and 3 are very similar in various indicators, indicating that the overall system-level benefits of configuring carbon capture devices only for conventional units or only for deep peak-shaving coal-fired units are comparable. However, compared with Scheme 4, the total cost of Schemes 2 and 3 is slightly higher. This is mainly because some coal-fired units are not equipped with carbon capture devices. The gas load gap caused by the failure to capture carbon dioxide emissions from Schemes 2 and 3 to produce methane needs to be balanced by purchasing gas, and the excess carbon emission quotas caused by these schemes need to be balanced by participating in carbon market trading, thus failing to fully realize the overall synergistic emission reduction potential of carbon capture devices.

[0111] Please see Figure 4 and Figures 5 to 9 , Figure 4 This is a forecast curve for a scheduling cycle with a future time length of 24 hours. Figures 5 to 8 This is a diagram showing the scheduling results of schemes 1 to 4 within a future scheduling cycle of 24 hours. Figure 9 The power generation curves of deep peak-shaving coal-fired units in Schemes 1 to 4 are shown within a future scheduling cycle of 24 hours.

[0112] It should be noted that, Figure 5 Figures a, 6a, 7a, and 8a are electrical load balance diagrams. In these diagrams, peak-shaving coal-fired units refer to: the grid-connected power of deep peak-shaving coal-fired units, which is the power generation of deep peak-shaving coal-fired units minus the energy consumption of their associated carbon capture devices; conventional coal-fired units refer to: the grid-connected power of conventional coal-fired units, which is the power generation of conventional coal-fired units minus the energy consumption of their associated carbon capture devices; wind power refers to: the grid-connected power of wind turbine units; hydrogen fuel cell 1 refers to: the power output of hydrogen fuel cells installed in conjunction with conventional coal-fired units; hydrogen fuel cell 2 refers to: the power output of hydrogen fuel cells installed in conjunction with deep peak-shaving coal-fired units; electro-hydrogen production refers to: the sum of the power input of electrolyzers installed in conjunction with conventional coal-fired units and electrolyzers installed in conjunction with deep peak-shaving coal-fired units.

[0113] Figure 5 b, 6b, 7b, and 8b are hydrogen balance diagrams. In these hydrogen balance diagrams, electrolytic hydrogen production 1 refers to the hydrogen output power of an electrolyzer configured with a conventional coal-fired unit; electrolytic hydrogen production 2 refers to the hydrogen output power of an electrolyzer configured with a deep load-following coal-fired unit; hydrogen storage 1 and hydrogen release 1 refer to the hydrogen storage power and hydrogen release power of a hydrogen storage device configured with a conventional coal-fired unit; hydrogen storage 2 and hydrogen release 2 refer to the hydrogen storage power and hydrogen release power of a hydrogen storage device configured with a deep load-following coal-fired unit; EL represents the hydrogen load.

[0114] Figure 5 c, 6c, 7c, and 8c are gas load balance diagrams. In these gas load balance diagrams, gas purchase refers to the gas purchase power of the integrated energy system, and gas purchase means purchasing methane; power-to-gas 1 refers to the methane output power of a methane reactor configured with a conventional coal-fired unit; power-to-gas 2 refers to the methane output power of a methane reactor configured with a deep load-following coal-fired unit; gas-fired boiler refers to the natural gas input power of the gas-fired boiler. Figure 5 d, 6d, 7d, and 8d are heat load balance diagrams. In these heat load balance diagrams, heat storage and heat release refer to the heat storage power and heat release power of the heat storage device; hydrogen fuel cell 1 refers to the heat output power of a hydrogen fuel cell configured with a conventional coal-fired unit; hydrogen fuel cell 2 refers to the heat output power of a hydrogen fuel cell configured with a deep load-following coal-fired unit; gas-fired boiler refers to the heat output power of the gas-fired boiler.

[0115] The following combines Figure 4 and Figures 5 to 9 to compare the scheduling results of Scheme 1, Scheme 2, and Scheme 3 provided in the comparative examples of this application with the scheduling result of Scheme 4 provided in the embodiments of this application.

[0116] Please refer to Figure 4 During a scheduling period with a future time length of 24 hours, the electrical load and wind power output have an anti-peaking characteristic. There are periods with a relatively high electrical load and a relatively low wind power output for a relatively long time length, and there are also periods with a relatively low electrical load and a relatively high wind power output for a relatively long time length.

[0117] In Scheme 1, during periods with a relatively low electrical load and a relatively large wind power output, in order to absorb wind power and ensure the system power balance at the same time, the coal-fired unit needs to be deeply depressed to operate at the technical output lower limit of the coal-fired unit. Please refer to Figure 9During periods 0-7 of the output curve for the coal-fired power unit corresponding to Scheme 1, the peak-shaving pressure is enormous, and some wind curtailment still occurs. To reduce wind curtailment, it is necessary to consume electricity by producing hydrogen through electrolyzers to alleviate the peak-shaving pressure. Deep peak-shaving coal-fired power units still need to remain in a deep peak-shaving state for extended periods. For Schemes 2 to 4, during periods of low electrical load and high wind power output, please refer to [the relevant documentation / reference needed]. Figure 9 During the 0-7 period of the output curves of the deep peak-shaving coal-fired power units corresponding to schemes 2 to 4, the deep peak-shaving coal-fired power units were not in a deep peak-shaving state.

[0118] In Scheme 4, on the one hand, during periods of low electricity load and high wind power output, the electrolyzer operates at high power. The integrated energy system utilizes wind power to electrolyze water to produce hydrogen, which is then stored in a hydrogen storage device. This process converts electrical energy into hydrogen energy, i.e., the chemical energy contained in hydrogen. On the other hand, during periods of high electricity load and low wind power output, the hydrogen energy stored in the hydrogen storage device can be converted into electrical energy and fed into the grid via a hydrogen fuel cell. This allows excess wind power from periods of low electricity load to be integrated into the grid during periods of high electricity load, giving the electrolyzer and hydrogen fuel cell the characteristic of "energy spatiotemporal transfer."

[0119] On the other hand, during periods of low electricity load and high wind power output, the integrated energy system instructs carbon capture coal-fired power plants to increase their operating energy consumption, proactively reducing the net output of the integrated energy system, thereby freeing up more space for wind power consumption. During periods of low electricity load and high wind power output, carbon capture devices are used to capture carbon dioxide, store the first portion of rich liquid, and regenerate the second portion of rich liquid. Simultaneously, a methane reactor is used to produce methane from the carbon dioxide released by the regenerated second portion of rich liquid, thereby consuming electricity to increase the power generation capacity of deep peak-shaving coal-fired units. During periods of high electricity load and low wind power output, carbon capture using carbon capture devices is stopped, and the carbon dioxide released from the regeneration of the first portion of rich liquid stored in the carbon capture devices is used to produce methane. This reduces the energy consumption burden of the first carbon capture coal-fired power plant while meeting gas load demands. Understandably, carbon capture (CC) devices consume a significant amount of electricity during carbon dioxide capture, creating an energy burden. By utilizing the rich liquid generated from excess wind power during periods of low electricity load and high wind power output, and supplying it to the integrated energy system during periods of high electricity load and low wind power output (when carbon dioxide capture ceases), the CC device can fulfill the integrated energy system's demand for rich liquid during periods of high electricity load. This gives the CC device a "virtual energy storage" characteristic. It's also understandable that the integrated energy system's demand for rich liquid during periods of high electricity load and low wind power output primarily stems from the need to convert the captured carbon dioxide into methane, which is then converted into natural gas for supply to the gas-fired boilers, thereby reducing the amount of gas purchased for the boilers.

[0120] Therefore, in Scheme 4, the "virtual energy storage" characteristic of the carbon capture device is utilized, that is, storing the rich liquid generated during periods of low electricity load and high wind power output for use during periods of high electricity load and low wind power output. This achieves the goal of maximizing wind power consumption during periods of low electricity load and high wind power output, and maximizing electricity savings during periods of high electricity load and low wind power output. Furthermore, the "energy spatiotemporal transfer" characteristics of the electrolyzer, hydrogen storage device, and hydrogen fuel cell are utilized, that is, integrating the excess wind power generated during periods of low electricity load and high wind power output into the power grid during periods of high electricity load and low wind power output. This greatly enhances the flexibility of the integrated energy system and enables the full utilization of wind power.

[0121] It should be understood that the terminology used in this application is for the purpose of describing particular embodiments only and is not intended to limit the application. The singular forms “a,” “the,” and “the” used in this application and the appended claims are also intended to include the plural forms, unless the context clearly indicates otherwise. The expressions “having,” “may have,” “comprising,” and “including,” or “may include” and “may contain” used herein may indicate the presence of corresponding features, but do not exclude the presence of additional features. Although the terms first, second, third, etc., may be used in this application to describe various information, this information should not be limited to these terms; these terms are only used to distinguish information of the same type from each other and are not necessarily used to describe a specific order or sequence. The technical solutions described in the embodiments of this application can be arbitrarily combined without conflict.

[0122] The above description is merely a specific embodiment of this application, but the scope of protection of this application is not limited thereto. Any changes or substitutions that can be easily conceived by those skilled in the art within the scope of the technology disclosed in this application should be included within the scope of protection of this application.

Claims

1. A scheduling method for carbon capture in deep peak-shaving coal-fired power units considering renewable energy consumption, characterized in that, Including: Construct a comprehensive energy system, including: a deep peak shaving coal-fired unit, a first device for capturing and utilizing carbon dioxide configured in cooperation with the deep peak shaving coal-fired unit, a conventional coal-fired unit, a second device for capturing and utilizing carbon dioxide configured in cooperation with the conventional coal-fired unit, a wind turbine unit, a gas boiler and a heat storage device; each of the first device and the second device includes a carbon capture device, a methane reactor, an electrolyzer, a hydrogen storage device and a hydrogen fuel cell; the carbon capture device has a rich and lean liquid decoupling performance. Establish an operation model of the comprehensive energy system; establish a total operation cost model of the comprehensive energy system; establish total load constraint conditions of the comprehensive energy system, where the total load includes electric, heat and gas loads. Obtain total load prediction data, where the total load prediction data includes electric load prediction data, heat load prediction data and gas load prediction data; obtain wind power output prediction data. With the goal of minimizing the total operation cost of the comprehensive energy system, for the operation model of the comprehensive energy system, the total operation cost model and the total load constraint conditions, obtain a scheduling strategy.

2. The scheduling method for carbon capture of a deep peak shaving coal-fired unit considering new energy consumption according to claim 1, wherein The carbon capture device includes an absorption tower, a rich liquid tank, a regeneration tower and a lean liquid tank connected in sequence; the absorption tower is used to capture carbon dioxide through lean liquid to form rich liquid, the rich liquid tank is used to store rich liquid, the regeneration tower is used to regenerate the rich liquid to release carbon dioxide to form lean liquid, and the lean liquid tank is used to store lean liquid and transport the lean liquid to the absorption tower. The comprehensive energy system includes a carbon capture coal-fired power plant; the carbon capture coal-fired power plant includes a first carbon capture coal-fired power plant and a second carbon capture coal-fired power plant; wherein, the first carbon capture coal-fired power plant includes the deep peak shaving coal-fired unit, the carbon capture device and the methane reactor configured in cooperation with the deep peak shaving coal-fired unit, and the second carbon capture coal-fired power plant includes the conventional coal-fired unit, the carbon capture device and the methane reactor configured in cooperation with the conventional coal-fired unit.

3. The scheduling method for carbon capture of a deep peak shaving coal-fired unit considering new energy consumption according to claim 1, wherein The operation model of the comprehensive energy system includes: an operation model of the deep peak shaving coal-fired unit, an operation model of the conventional coal-fired unit, an operation model of the first device, an operation model of the second device, an operation model of the wind turbine unit, an operation model of the gas boiler and an operation model of the heat storage device. The operation model of the deep peak shaving coal-fired unit includes the operation cost of the deep peak shaving coal-fired unit and the operation constraint conditions of the deep peak shaving coal-fired unit. The operation model of the conventional coal-fired unit includes the operation cost of the conventional coal-fired unit and the operation constraint conditions of the conventional coal-fired unit. The operation models of the first device and the second device each include an operation model of the carbon capture device, an operation model of the methane reactor, an operation model of the electrolyzer, an operation model of the hydrogen storage device and an operation model of the hydrogen fuel cell.

4. The scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption as described in claim 1, characterized in that, The total operating cost model of the integrated energy system includes: The total operating cost of the integrated energy system includes the operating cost of deep peak-shaving coal-fired units, the operating cost of conventional coal-fired units, the carbon trading cost of the integrated energy system, the carbon sequestration cost of the integrated energy system, the operating cost of wind turbine units, and the gas purchase cost of the integrated energy system.

5. The scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption as described in claim 2, characterized in that, The total load constraints of the integrated energy system include: The sum of the grid-connected power of the wind turbines in time period t, the total net output power of the first and second carbon capture coal-fired power plants in time period t, the total input power of the electrolyzers of the first and second units in time period t, and the total electrical output power of the hydrogen fuel cells of the first and second units in time period t, equals the electrical load of the integrated energy system in time period t. The heat output power of the gas boiler, the total heat output power of the hydrogen fuel cells of the first and second devices in time period t, is the sum of the heat release power of the heat storage device in time period t, which is equal to the sum of the heat load of the integrated energy system in time period t and the heat storage power of the heat storage device in time period t. The sum of the total output power of the electrolyzers of the first and second devices in time period t and the total hydrogen release power of the first and second devices in time period t is equal to the sum of the total input power of the methane reactors of the first and second devices in time period t, and the sum of the total hydrogen storage power of the first and second devices in time period t and the total hydrogen input power of the hydrogen fuel cells of the first and second devices in time period t. The sum of the gas purchase power of the integrated energy system in time period t and the total output power of the methane reactors of the first and second units in time period t is equal to the sum of the total natural gas input power of the gas boiler in time period t and the gas load of the integrated energy system in time period t.

6. The scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption as described in claim 3 or 4, characterized in that, The operating costs of the deep peak-shaving coal-fired power units include: Fuel cost of deep peak shaving coal-fired power units, start-up and shutdown cost of deep peak shaving coal-fired power units, life loss cost of deep peak shaving coal-fired power units, oil injection cost of deep peak shaving coal-fired power units, and environmental cost of deep peak shaving coal-fired power units; The operating constraints of the deep peak-shaving coal-fired power units include: Output constraints of deep peak-shaving coal-fired power units, ramp-up rate constraints of deep peak-shaving coal-fired power units, and minimum start-up and shutdown time constraints of deep peak-shaving coal-fired power units.

7. The scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption as described in claim 6, characterized in that, The output constraint condition of the deep peak-shaving coal-fired power unit is expressed as follows: ， In the formula: This represents the maximum power generation of deep peak-shaving coal-fired units; This is the lower limit for oil injection peak shaving in deep peak-shaving coal-fired power units; is the working status parameter of the deep peak-shaving coal-fired unit in time period t, with a value of 0 or 1, where 0 represents the stopped state and 1 represents the running state. This represents the power generation of the deep peak-shaving coal-fired unit in the t-th time period; T refers to dividing a scheduling cycle into T time periods of equal length, and t refers to the t-th time period within a scheduling cycle, t=1,2,3…T.

8. The scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption as described in claim 4, characterized in that, The expression for the ramp rate constraint of the deep peak-shaving coal-fired power unit is: ， In the formula: This is the upper limit of the ramp rate for deep peak-shaving coal-fired power units. This is the lower limit of the ramp rate for deep peak-shaving coal-fired power units. This represents the power generation of the deep peak-shaving coal-fired unit during period t. This represents the power generation of the deep peak-shaving coal-fired unit during the t-1 period.

9. The scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption as described in claim 6, characterized in that, The minimum start-up and shutdown time constraint condition for the deep peak-shaving coal-fired power unit is expressed as follows: , In the formula: T refers to dividing a scheduling cycle into T time periods of equal length, t refers to the t-th time period within a scheduling cycle, t=1,2,3…T; This refers to the total number of time periods corresponding to the maximum continuous operating time of deep peak-shaving coal-fired power units. This represents the total number of time periods corresponding to the maximum continuous shutdown time of deep peak-shaving coal-fired power units; based on the value of t, the value of k is k = t, t+1, ..., t+ -1; These are the operating status parameters of the deep peak-shaving coal-fired power units in the k-th time period. The value can be 0 or 1, where 0 represents a stopped state and 1 represents a running state. These are the operating status parameters of the deep peak-shaving coal-fired power units in time period t. The value can be 0 or 1, where 0 represents a stopped state and 1 represents a running state. This is the operating status parameter of the deep peak-shaving coal-fired power unit in the (t-1)th time period. The value is 0 or 1, where 0 represents the stopped state and 1 represents the running state.

10. The scheduling method for carbon capture of deep peak-shaving coal-fired power units considering renewable energy consumption according to claim 3, characterized in that, The operating model of the carbon capture device of the first device includes the energy consumption model of the carbon capture device and the operating models of the lean liquid tank and the rich liquid tank; The energy consumption model of the carbon capture device of the first device is expressed as follows: ， In the formula: The power generation of the deep peak-shaving coal-fired unit in time period t; The net output electricity of the first carbon capture coal-fired power plant in time period t; Let t be the carbon capture energy consumption of the first carbon capture coal-fired power plant during the t-th time period; This represents the basic energy consumption of the first carbon capture coal-fired power plant. Let t be the operating energy consumption of the first carbon capture coal-fired power plant during time period t; The operating energy consumption coefficient of the carbon capture device; Let t represent the total CO2 generation of the deep peak-shaving coal-fired power unit in time period t. Carbon emission intensity of deep peak-shaving coal-fired power units; The parameters for the oil-fired stable combustion state of the deep peak-shaving coal-fired unit in time period t are given. The value can be 0 or 1, where 0 means not entering the fuel injection and stable combustion state, and 1 means entering the fuel injection and stable combustion state. This refers to the oil consumption of the coal-fired power unit in the deep peak shaving stage during the oil injection phase, specifically the oil consumption in time period t. Let be the amount of CO2 absorbed by the absorption tower in time period t; denoted as the flue gas split ratio of the first carbon capture coal-fired power plant in time period t, where the flue gas split ratio is the proportion of carbon dioxide collection to carbon dioxide venting; μ1 is the absorption efficiency of the absorption tower. denoted as t, where μ is the amount of CO2 to be regenerated by the regeneration tower during time period t; μ2 is the regeneration efficiency of the regeneration tower. Let be the CO2 outflow from the rich liquid tank during time period t. A positive value indicates that CO2 flows from the rich liquid tank to the regeneration tower. A negative value indicates that CO2 flows from the absorber to the rich liquid tank; This represents the actual CO2 capture amount of the carbon capture device during time period t.

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