A cogeneration unit and heat network coordinated unit peak capacity improvement system and method

Abstract

The application discloses a kind of thermoelectric unit and heat network collaborative unit peak capacity promotion system and method, it is related to thermoelectric cogeneration unit peak shaving technical field, the system includes central control system, thermoelectric cogeneration unit, heating first station, primary network, secondary network and heat exchange station, wherein heat exchange station is equipped with main, vice heat exchanger and connecting pipeline, sensor, valve.The mathematical model of thermoelectric cogeneration unit, heat network, heat exchange station and heat user is established, the scheduling strategy including the water temperature of heating first station and the switching regulation instruction of vice heat exchanger is generated, the valve on the connecting pipeline of vice heat exchanger is controlled by central control system, for responding switching regulation instruction to put in or cut off vice heat exchanger.The application can enhance the flexibility of heat station in heat network, so that it can guarantee indoor temperature of heat user stable when primary side water temperature fluctuates greatly due to thermoelectric cogeneration unit cooperates with heat network peak, make full use of heat storage resource of heating water network, improve unit peak capacity.

Description

Technical Field

[0001] This invention relates to the field of peak shaving technology for cogeneration units, and in particular to a system and method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network. Background Technology

[0002] The statements in this section are merely background information related to the present invention and do not necessarily constitute prior art.

[0003] With the rapid growth of installed capacity of new energy power generation such as wind power and photovoltaic power, the intermittent nature and anti-peak-shaving characteristics of new energy output have exacerbated the intraday fluctuations in power supply and widened the peak-valley difference in the power system, posing a severe challenge to power supply security. Meanwhile, in heating areas, large-scale combined heat and power (CHP) units bear the main heat load during the heating season. Their power generation output is strictly constrained by the amount of steam extracted for heating, resulting in a "heat-driven power generation" operating mode. This severely limits the peak power generation capacity of the units during peak electricity demand periods, making peak supply security of the power system particularly challenging during the heating season. Therefore, how to achieve heat and power decoupling and release the peak-shaving potential of heating units has become a key issue in ensuring the safe and stable operation of the new power system.

[0004] In existing technologies, two main methods are currently used to achieve heat and electricity decoupling: First, adding large-scale heat storage devices, such as hot water tanks, to the heat source side. While effective, this method suffers from drawbacks such as large land area requirements, high investment costs, and long construction periods, limiting its widespread application. Second, utilizing the large water volume of the heating network itself as a heat storage medium. During peak electricity demand periods, the extraction of steam from generating units is reduced to increase power generation, while the heat storage in the heating network temporarily maintains heating. However, this method faces fundamental constraints in practical applications. The heat capacity of the various buildings covered by the heating network (especially older buildings) is limited, and they are sensitive to changes in heating demand. When "heating is reduced and electricity is increased," the indoor temperature of these end-users with small heat capacities will drop rapidly, potentially exceeding comfort levels. This becomes a "bottleneck" restricting the duration and magnitude of peak demand, limiting the full utilization of the heating network's heat storage potential, and further limiting the synergistic effect of combined heat and power units with the heating network during peak demand periods. Summary of the Invention

[0005] To address the shortcomings of the existing technologies, this invention provides a system and method for enhancing the peak power capacity of cogeneration units in coordination with the heating network. By adding a controllable start-stop auxiliary heat exchanger to the heat exchange station and generating an optimal scheduling strategy for the heating network side based on thermal calculation and optimization algorithms, precise control of the heat supply to the user side is achieved when the primary network operating conditions fluctuate. This safely and efficiently enhances the peak power generation capacity of the cogeneration unit without affecting the heating quality of the user.

[0006] In a first aspect, the present invention provides a system for enhancing the peak capacity of a cogeneration unit in coordination with a heating network.

[0007] A system for enhancing the peak capacity of a cogeneration unit in conjunction with a heating network includes: A combined heat and power (CHP) unit is used to simultaneously generate electrical energy and heat energy in the form of steam. The primary heating station is used to heat the primary network return water using steam generated by the combined heat and power unit. The primary network connects the heating station and each heat exchange station, and is used to transmit heat energy; At least one heat exchange station is connected between the primary network and the secondary network for heat exchange; the heat exchange station includes main and auxiliary heat exchangers arranged in parallel, as well as connecting pipes, sensors, and valves, and the valves on the connecting pipes of the auxiliary heat exchangers are controlled by a central control system to respond to adjustment commands to activate or deactivate the auxiliary heat exchangers. The secondary network connects the heat exchanger to the heat exchange equipment of the heat user and is used to transfer heat energy; The central control system receives data collected by sensors, optimizes and calculates to obtain control strategies, and generates adjustment commands for valve opening and closing.

[0008] A further technical solution involves a heat exchanger group consisting of a main heat exchanger and an auxiliary heat exchanger, both of which are plate heat exchangers of the same specifications. Both heat exchangers are arranged in countercurrent, with the primary side connected in series in the primary network and the secondary side connected in parallel in the secondary network. The heat exchanger assembly is equipped with valves on both the primary and secondary sides. The valves between the heat exchanger assembly and the primary side supply and return water pipes, as well as the valve at the secondary side outlet of the main heat exchanger, are normally open during the heating season. The primary side outlet of the main heat exchanger is connected to two branches. One branch is connected to the primary side return water pipe and is equipped with valve 1C. The other branch is connected to the primary side inlet of the auxiliary heat exchanger and is equipped with valve 1D. The secondary side of the auxiliary heat exchanger is directly connected to the secondary network, and valve 2B is provided between the two. Valves 1C, 1D, and 2B are controlled by the central control system and are used to respond to adjustment commands to activate or deactivate the auxiliary heat exchanger.

[0009] A further technical solution involves sensors in the heat exchange station, including temperature sensors and flow sensors, both of which are connected to the central control system. Both types of sensors are installed at the inlet and outlet of the primary and secondary networks of the heat exchange station to collect the temperature and flow rate of the primary network water supply, primary network return water, secondary network water supply, and secondary network return water, and transmit them to the central control system.

[0010] Secondly, the present invention provides a method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network.

[0011] A method for enhancing the peak capacity of a cogeneration unit in conjunction with a heating network includes: Establish the cogeneration operation domain of the cogeneration unit and the dynamic mathematical model of the heating network; the dynamic mathematical model of the heating network takes the water supply temperature sequence of the primary heating station and the start-up and shutdown time points of the auxiliary heat exchangers of each heat exchange station as inputs, and outputs the predicted indoor temperature of the heat users. Based on the dynamic mathematical model of the heating network, with the goal of minimizing the deviation between the actual power generation and demand of the units, and with user indoor temperature and the thermal power operation domain of the units as constraints, an optimized scheduling model is constructed. The optimal scheduling strategy is obtained by solving the optimal scheduling model with the unit power load demand sequence and outdoor temperature forecast value in the future target period as input; the optimal scheduling strategy is the water supply temperature sequence of the heating station in the future target period and the start-stop status sequence of the auxiliary heat exchangers of each heat exchange station. During the actual operation of the target time period in the future, the optimal scheduling strategy will be executed.

[0012] A further technical solution, based on the heat balance diagram of the cogeneration unit, establishes the unit's thermoelectric operating domain as follows: By identifying thermal calculations or historical operating data, the upper and lower boundaries of the power generation capacity of the cogeneration unit under different heat loads are determined. These boundaries are represented as a planar polygon with the extraction steam flow / heat supply as the horizontal axis and the actual power generation capacity as the vertical axis. The area within the polygon is the cogeneration operating domain of the unit for stable operation.

[0013] A further technical solution employs a discrete equation method based on time-delay heat loss identification to construct a dynamic mathematical model of the heating network, as follows: Identify the time delay and heat loss parameters of the heat medium transmission in the supply and return water pipelines of each heat exchange station; Based on the heat transfer effectiveness-number of heat transfer units method, a heat transfer calculation model for a heat exchange station is established, including the start-up and shutdown conditions of the main heat exchanger and the auxiliary heat exchanger. Based on the building's heat balance equation, a dynamic response model of indoor temperature to heating supply and outdoor temperature for heat users is established. Based on the law of conservation of energy, the relationship between the supply and return water temperatures of the heating first station is obtained by combining the time delay and heat loss parameters of the integrated pipeline, the heat exchange calculation model of the heat exchange station, and the dynamic response model of the heat user. The steam extraction sequence of the unit is determined, and a dynamic mathematical model of the heating network is formed.

[0014] Further technical solutions, including the identification of time delay and heat loss parameters in the supply and return water pipelines, are as follows: Historical time-series data of supply and return water temperatures at the primary heating station and each heat exchange station were collected and preprocessed by cleaning and interpolation. A temperature correlation model was established between the supply and return water temperature sequences of the primary heating station and the primary side supply and return water temperature sequences of each heat exchange station. Using preprocessed data as input, a grid search method was employed to traverse parameter combinations to determine the coefficients. With the goal of maximizing, the optimal parameters of time delay and heat loss of the supply and return water pipelines of each heat exchange station are obtained by solving.

[0015] A further technical solution involves determining the power load demand sequence based on power market information or grid dispatch instructions, and expecting the combined heat and power (CHP) units to track the power generation curve.

[0016] Thirdly, the present invention also provides an electronic device, comprising: a memory for storing executable instructions; and a processor for executing the executable instructions stored in the memory to realize the above-mentioned method for enhancing the peak capacity of a thermal power unit in coordination with a heating network.

[0017] Fourthly, the present invention also provides a computer-readable storage medium storing executable instructions for causing a processor to execute the executable instructions to realize the above-mentioned method for improving the peak capacity of a co-generation unit and a heating network.

[0018] The above one or more technical solutions have the following beneficial effects: 1. This invention proposes a system and method for enhancing the peak capacity of cogeneration units in coordination with the heating network. An auxiliary heat exchanger is added to the heat exchange station, and an optimized scheduling system is introduced. By controlling the start and stop of the auxiliary heat exchanger, active control is achieved for the secondary network to extract heat from the primary network, thus decoupling the thermal conditions of the secondary network from the primary network to a certain extent. The decoupling boundary is set at the heat exchange station, between the primary and secondary networks. Through this method, when peak shaving is not required, the cogeneration unit supplies heat according to the heat load demand. When peak power generation is needed, the heat storage capacity of the primary network can be effectively utilized to reduce the primary network water supply temperature and decrease steam extraction. Simultaneously, by activating the auxiliary heat exchanger, the total heat exchange capacity is increased, keeping the heat supply to the user side stable. This completely isolates the impact of "heat reduction and power increase" within the primary network, fundamentally ensuring the heating safety and comfort of end users while releasing the unit's power generation potential.

[0019] 2. The peak capacity enhancement system and method of the co-generation unit and the heating network of the present invention has a rapid response and is energy-efficient. The start-up and shutdown operation response time of the auxiliary heat exchanger is in the minute range, which can quickly compensate for the heat transfer temperature difference loss caused by the temperature change of the primary network, overcome the problem of lag in traditional heating network regulation, and this method directly regulates the heat exchange process without starting an additional fossil fuel heat source. It is a highly efficient "passive" regulation method with significant energy-saving effect.

[0020] 3. The peak capacity enhancement system and method of the co-generation unit and the heating network of the present invention is low in cost and flexible in modification. It makes full use of the heat storage capacity of the existing heating network itself. There is no need to build expensive infrastructure such as large heat storage tanks. Only the parallel auxiliary heat exchangers need to be modified at the heat exchange stations at key nodes. The investment is small, the construction period is short, and it is easy to implement. It is particularly suitable for the efficiency improvement and transformation of existing heating systems.

[0021] 4. The system and method for enhancing the peak power capacity of a cogeneration unit and a heating network, as described in this invention, can not only be used to enhance the peak power generation capacity of the unit, but is also suitable for assisting the unit in deep peak shaving. Furthermore, through optimized control, it can smooth heating fluctuations, improve the stability and anti-interference capability of the heating system, and has multiple application values.

[0022] Advantages of additional aspects of the invention will be set forth in part in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. Attached Figure Description

[0023] The accompanying drawings, which form part of this invention, are used to provide a further understanding of the invention. The illustrative embodiments of the invention and their descriptions are used to explain the invention and do not constitute an improper limitation of the invention.

[0024] Figure 1 This is a schematic diagram of the peak capacity enhancement system for coordinating thermal power units and heating networks in Embodiment 1 of the present invention; Figure 2 A structural comparison diagram of a conventional heat exchanger and a heat exchange station containing an auxiliary heat exchanger in Embodiment 1 of the present invention; Figure 3 This is a flowchart of the method for improving the peak capacity of a cogeneration unit in coordination with a heating network in Embodiment 1 of the present invention; Figure 4 This is a flowchart of the optimization process for time delay and heat loss parameters in Embodiment 1 of the present invention; Figure 5 This is a schematic diagram of the thermal system of the extraction condensing unit in Embodiment 1 of the present invention; Figure 6 This is a schematic diagram of the operating domain of the extraction condensing unit in Embodiment 1 of the present invention; Figure 7 This is a schematic diagram of the optimized scheduling of the thermal power unit and the primary heating station in Embodiment 1 of the present invention; Figure 8 This is a schematic diagram of the optimized scheduling of the heat exchange station and heat users in Embodiment 1 of the present invention. Detailed Implementation

[0025] It should be noted that the following detailed descriptions are exemplary and are intended only to describe specific embodiments and to provide further explanation of the invention, and are not intended to limit the scope of exemplary embodiments of the invention. Unless otherwise specified, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention pertains. Furthermore, it should be understood that when the terms "comprising" and / or "including" are used in this specification, they indicate the presence of features, steps, operations, devices, components, and / or combinations thereof.

[0026] Example 1 Cogeneration units and heat users are connected through heat exchange stations, and the heating network is usually structured as "heat source - primary network - heat exchange station - secondary network - heat user". Based on this, this embodiment proposes a peak capacity enhancement system for co-generation units and the heating network. By adding auxiliary heat exchangers at the heat exchange stations that can be put into operation and cut off on demand, and introducing an optimized scheduling system, the heat exchange stations can achieve active control and quantitative heat extraction. This decouples the thermal conditions of the secondary network from the primary network to a certain extent, that is, it decouples the actual heat supply from the heat exchange station to the end users from the hydraulic and thermal conditions of the primary network. This isolates the heat supply fluctuations caused by co-generation to the primary network side to the greatest extent, which can effectively utilize the heat storage capacity of the primary network and reduce the impact of primary network water supply temperature fluctuations on the heating stability of the secondary network. Thus, it can effectively improve the peak output of cogeneration units while ensuring the quality of heating.

[0027] like Figure 1 As shown, the unit peak capacity enhancement system for the coordinated operation of thermal power units and heating networks proposed in this embodiment specifically includes: (1) A combined heat and power (CHP) unit is used to simultaneously generate electrical energy and heat energy in the form of steam. In this embodiment, an extraction condensing unit or an extraction back-pressure CHP unit is used, and its peak capacity is negatively correlated with the heat load.

[0028] (2) The first heating station is used to heat the primary network return water using the steam (extraction or exhaust steam) generated by the cogeneration unit.

[0029] (3) Primary network, which connects the first heating station and each heat exchange station in the area, including a series of pipelines, valves, relay pump stations and necessary auxiliary facilities, for the transmission of heat energy.

[0030] (4) At least one heat exchange station is connected between the primary network and the secondary network for heat exchange. In this embodiment, the heat exchange station includes a main heat exchanger and a secondary heat exchanger arranged in parallel, namely, a plate heat exchanger as the main heat exchanger and a plate heat exchanger connected in parallel with the main heat exchanger as the secondary heat exchanger, as well as related connecting pipes, sensors, valves, pump sets and other auxiliary accessories. The sensors are electrically connected to the central control system and are used to upload operating condition data to the central control system. The pump sets and valves are also electrically connected to the central control system. The valves on the connecting pipes of the secondary heat exchanger are controlled by the central control system and are used to respond to adjustment commands to put the secondary heat exchanger into or out of the system and to adjust the secondary side flow.

[0031] (5) Secondary network: a hot water pipe network or heat exchange equipment that connects the heat exchanger to the end of the heat user's terminal, used to transmit heat energy.

[0032] (6) User terminal refers to heat exchange equipment placed inside the user's building for releasing heat to the user's building, including but not limited to wall heating, floor heating, fan coil units, central air conditioning, etc.

[0033] (7) Central control system, which is used to receive and integrate data collected by sensors in the system, as well as the prediction results of thermal and electrical loads, and calculate the optimal control strategy by running optimization algorithms to generate valve on / off adjustment commands.

[0034] The core concept of this embodiment lies in the central control system and the auxiliary heat exchanger added to the heat exchange station. The structure and operation mode of the heat exchange station with the auxiliary heat exchanger are described in detail below.

[0035] like Figure 2 As shown, in traditional heat exchange stations, only one heat exchanger is typically installed between the primary and secondary networks. The flow parameters and heat exchange area of ​​a traditional heat exchanger are fixed, meaning the heat exchange capacity depends on the temperature difference and flow rate between the two sides. When the temperature of the primary network supply water fluctuates due to "electricity-based heat adjustment," the actual heat supply to users will also fluctuate, making it difficult to ensure heating quality while adjusting for electricity. Unlike existing designs, this embodiment adds an auxiliary heat exchanger to the heat exchange station. Specifically, the heat exchange station includes a main plate heat exchanger (which operates continuously throughout the heating season) and an auxiliary plate heat exchanger (which is activated on demand). Both the main and auxiliary plate heat exchangers are of the same specifications and are arranged in counter-current flow. The primary side is connected in series to the primary network, and the secondary side is connected in parallel to the secondary network. The reason for adopting the above arrangement is that the primary side long-distance pipeline has large friction loss, and the pump head redundancy and pipeline pressure-bearing capacity limit can support the series arrangement, which is conducive to increasing the heat transfer efficiency when the auxiliary heat exchanger is activated. However, the secondary network has weak pressure-bearing capacity, so the parallel arrangement is used to avoid excessive pressure drop.

[0036] The operation mode of the aforementioned heat exchange station with added auxiliary plate heat exchangers is as follows: During the heating season, the heat exchange station has two operating modes: normal operating mode and peak-shaving operating mode, which are switched by opening and closing valves. For example... Figure 2 As shown, a series of valves are installed before and after the main and auxiliary heat exchangers in the heat exchange station, including: Valve 1A is the primary side inlet valve of the heat exchange station, and it is normally open during operation. Valve 1B is the primary side outlet valve of the heat exchange station, which is normally open during operation. Valve 1C is an electric gate valve located between the primary side outlet of the main heat exchanger and the primary network return water pipe, which is involved in the switching of operating conditions. Valve 1D is an electric gate valve between the primary side outlet of the main heat exchanger and the primary side inlet of the auxiliary heat exchanger, which participates in the switching of operating conditions. Valve 2A is the secondary side outlet valve of the main heat exchanger, and it is normally open during operation. Valve 2B is the secondary side outlet valve of the auxiliary heat exchanger, which is involved in the switching of operating conditions.

[0037] Furthermore, the arrangement and connection of each valve are clarified: the outlet of the main heat exchanger is connected to two branches. One branch connects to the primary side return water pipe, and the valve on this branch is valve 1C. The other branch connects to the primary side inlet of the auxiliary heat exchanger, and the valve on this branch is valve 1D. The primary side outlet of the auxiliary heat exchanger is connected to the outlet of valve 1C, and then both are connected to the primary side return water pipe. This connection method realizes the series connection of the primary sides of the auxiliary heat exchanger and the main heat exchanger. The aforementioned valve 1B is installed on this primary side return water pipe. In addition, the secondary side of the auxiliary heat exchanger is directly connected to the secondary network, and a valve 2B is installed between the two. Among the above valves, valves 1C, 1D, and 2B are controlled by the central control system and are used to respond to adjustment commands to activate or deactivate the auxiliary heat exchanger.

[0038] Based on the above settings, the valve allows the system to switch between the following two operating conditions: (1) Normal operating condition: When the heat network does not coordinate with the cogeneration unit for peak shaving, the temperature of the primary network water supply changes slowly, and the actual heat supply always matches the heat load. The main heat exchanger can be put into operation alone, that is, valve 1C is opened while valves 1D and 2B are closed. The auxiliary heat exchanger is not put into operation. At this time, the heat transfer efficiency of the heat exchange station is low and the temperature of the primary network return water is high.

[0039] (2) Peak Shaving Condition: During peak shaving in conjunction with the cogeneration unit, the primary network water supply temperature fluctuates significantly and decreases. At this time, valve 1C is closed, while valves 1D and 2B are fully open. The circulating pump increases its circulation flow, and the main and auxiliary heat exchangers are simultaneously put into operation. The primary side of both is connected in series, and the secondary side is connected in parallel. The overall heat transfer efficiency of the system increases, ensuring that the heat supply to users is not affected by the primary network temperature fluctuation. Due to the more efficient heat exchange, the primary network return water temperature will be lower than that under normal operating conditions.

[0040] With the support of the aforementioned hardware and software, the heat exchange station can switch between normal operating conditions and peak-shaving operating conditions, and rely on the input and output of auxiliary heat exchangers to achieve the peak capacity enhancement of the cogeneration unit and the heating network.

[0041] In addition, such as Figure 2 As shown, the sensors in the heat exchange station include temperature sensors and flow sensors, both of which are connected to the central control system. Both types of sensors are installed at the inlet and outlet of the primary network and the secondary network of the heat exchange station to collect the temperature and flow rate of the primary network water supply, primary network return water, secondary network water supply, and secondary network return water, and transmit them to the central control system to provide data support for the optimization calculation of the control strategy.

[0042] Example 2 like Figure 3As shown, this embodiment proposes a method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network. It is implemented based on the cogeneration unit and heating network peak capacity enhancement system proposed in Embodiment 1. The method specifically includes the following steps: Step S1: Establish the cogeneration operation domain of the cogeneration unit and the dynamic mathematical model of the heating network; the dynamic mathematical model of the heating network takes the water supply temperature sequence of the primary heating station and the start-up and shutdown time of the auxiliary heat exchangers of each heat exchange station as input, and outputs the predicted indoor temperature of the heat users. Step S2: Based on the dynamic mathematical model of the heating network, with the goal of minimizing the deviation between the actual power generation of the units and the demand power, and with user indoor temperature and the thermal power operation domain of the units as constraints, an optimized scheduling model is constructed. Step S3: Using the unit power load demand sequence and outdoor temperature forecast value within the future target time period as input, solve the optimization scheduling model to obtain the optimal scheduling strategy; the optimal scheduling strategy is the water supply temperature sequence of the primary heating station and the start-stop status sequence of the auxiliary heat exchangers of each heat exchange station within the future target time period. Step S4: During the actual operation of the target time period in the future, execute the optimal scheduling strategy.

[0043] The following content will provide a more detailed introduction to the method for improving the peak capacity of a cogeneration unit in coordination with a heating network proposed in this embodiment.

[0044] In step S1, the cogeneration operation domain of the cogeneration unit and the dynamic mathematical model of the heating network were established, specifically including: Step S1.1: First, based on the heat balance diagram of the cogeneration unit, establish the unit's cogeneration operating domain. Specifically, the established cogeneration operating domain refers to the upper and lower boundaries of the power generation capacity of the cogeneration unit under different heat loads, determined through thermal calculations or historical operating data identification. This domain is represented as a planar polygon with the extraction steam flow rate or heat supply as the horizontal axis and the actual power generation capacity of the unit as the vertical axis. The area within this polygon represents the operating conditions the unit can achieve and the cogeneration operating domain capable of stable operation. It should be noted that this embodiment does not limit the method used to determine the operating domain.

[0045] Step S1.2: Next, construct the dynamic mathematical model of the heating network (which can be simply referred to as the heating network mathematical model). The heating network mathematical model is a subsystem of the optimization scheduling algorithm used in this embodiment. This model takes the water supply temperature sequence of the first heating station in the future target time period (the steam extraction sequence of the unit can be calculated and determined based on the water supply temperature sequence of the first heating station) and the start-up and shutdown times of the auxiliary heat exchangers of each heat exchange station as inputs, and outputs the predicted indoor temperature of heat users through thermal calculations, that is, the predicted value of the indoor temperature of heat users.

[0046] In this embodiment, the discrete equation method based on time-delay heat loss identification is used for heating network modeling. The specific operation is as follows: Step S1.2.1: Identify the time delay and heat loss parameters of heat medium transmission in the long-distance pipeline network (i.e., supply and return water pipeline) of each heat exchange station.

[0047] Specifically, taking the identification of time delay and heat loss parameters of water supply pipelines as an example, let the water supply temperature sequence of the primary heating station be... Number heat exchange station The primary water supply temperature sequence is as follows A temperature correlation model is established between the supply and return water temperature sequences of the primary heating station and the primary side supply and return water temperature sequences of each heat exchange station. The system model can be expressed as follows: (1) in, The time step of the dataset, This represents the pure delay of pipeline transmission, which is Integer multiples of HES Representative number is In the heat exchange station, 1 represents the primary side, g represents feed water, and h represents return water. For the heat exchange station number, This represents the total number of heat exchange stations; This represents the average heat loss during pipeline transmission, expressed in °C. This indexes the data points in the dataset. The meanings of the symbols and subscripts mentioned above remain unchanged throughout the text.

[0048] In parameters and When selected appropriately, this model can reflect the DHS water supply temperature at the primary heating station. When changes occur, the heat exchange station Primary inlet temperature The response situation. At this point, the problem is transformed into a parameter optimization problem for the model shown in equation (1). The parameters to be optimized are the time delay and heat loss of the supply and return water pipes of each heat exchange station in the thermal system involved. Considering that the parameter dimension is small in this problem, this embodiment adopts the grid search method for solution. The solution process is as follows. Figure 4 As shown, while establishing the above model, historical time-series data of the supply and return water temperatures of the primary heating station and each heat exchange station were collected and preprocessed by cleaning and interpolation. Then, using the preprocessed data as input, a grid search method was used to traverse the parameter combinations to determine the coefficients. With the goal of maximizing, the optimal parameters of time delay and heat loss of the supply and return water pipelines of each heat exchange station are obtained by solving.

[0049] Solving the aforementioned optimization problem is technically equivalent to finding the global maximum point of a bivariate function in a two-dimensional parameter space. During data preprocessing, the introduction of cubic spline interpolation ensures that the time delay parameter can be estimated with a precision lower than the original data sampling rate, improving the accuracy of parameter identification; while during parameter optimization, a coefficient of determination is defined. As a performance indicator, it aims to minimize the deviation between the predicted and actual values. The calculation methods for the coefficient of determination are shown in equations (2) and (3) below: (2) (3) in, This represents the model's predicted value. This represents the average value observed. For the number of valid data points, The coefficient of determination is dimensionless.

[0050] Finally, after iterating through all parameter combinations, it becomes... The largest set of parameters are time delay and heat loss. This process is repeated for each heat exchange station, and these parameters are substituted into equation (1) to obtain the model of the water supply process.

[0051] In addition, the time delay and heat loss of the return water network can be identified using the same steps as described above, and will not be repeated here.

[0052] Step S1.2.2: For each heat exchange station, based on the thermal system structure, the connection method of the main and auxiliary heat exchangers, and the start-up and shutdown conditions of the auxiliary heat exchanger, establish a mathematical model for heat exchange calculation of the heat exchange station. The essence of this mathematical model is a heat exchange verification calculation program that considers different heat exchange station configurations, using the heat transfer effectiveness-number of heat transfer units method as the calculation basis.

[0053] Specifically, for a particular heat exchanger in the system, its heat capacity ratio is defined as: (4) (5) (6) In the above formula, For primary side flow, This refers to the secondary side flow rate; , The primary and secondary thermal flow rates characterize the fluid's ability to carry heat.

[0054] The number of heat transfer units (NTU) is defined as follows: (7) In the above formula, The overall heat transfer coefficient is expressed in W / (m²).2 ·℃); This refers to the number of plates included when calculating the heat transfer area; The effective heat transfer area of ​​a single panel, in m². 2 ; The specific heat capacity of water at constant pressure is expressed in J / (kg·℃). Subscript 1 indicates the primary side (i.e., the high-temperature side), and subscript 2 indicates the secondary side (i.e., the low-temperature side). Plate heat exchangers commonly used in heating projects are mostly arranged in a counter-current configuration. For counter-current heat exchangers, the heat transfer efficiency can be calculated according to formula (8). This efficiency represents the ratio of actual heat transfer to the maximum possible heat transfer. The formula for calculating this heat transfer efficiency is: (8) After obtaining the heat transfer efficiency, the heat transfer capacity and outlet temperature of the heat exchanger can be calculated according to formula (9): (9) (10) (11) in, Heat exchange is measured in W. and The outlet temperatures of the primary and secondary sides of the heat exchanger are expressed in °C.

[0055] In practical applications, an iterative calculation procedure considering changes in physical property parameters is adopted. Different calculation methods are selected depending on whether the secondary heat exchanger is in use: if the secondary heat exchanger is not in use, the calculation result of the main heat exchanger is used as the final calculation result; if the secondary heat exchanger is in use, the calculation process is organized according to the characteristics of primary side series connection and secondary side parallel connection, that is, the primary side outlet temperature of the main heat exchanger is used as the primary side inlet temperature of the secondary heat exchanger for calculation, and the primary side outlet temperature of the secondary heat exchanger is used as the primary side return water temperature of the heating station. From the perspective of input and output quantities, this method can be expressed as shown in equation (12): (12) In the above formula, This refers to the primary return water temperature at each heat exchange station. The primary feedwater temperature at each heat exchange station is a continuous variable. Number A Boolean sequence indicating whether the auxiliary heat exchanger of the heat exchange station is enabled, with each element having a value of 0 or 1, and being an integer variable. Number Thermodynamic calculation function for the heat exchange station. In this embodiment, the water supply temperature sequence of the primary heating station. Start-up and shutdown sequence of auxiliary heat exchangers in all heat exchange stations Together they constitute the heating strategy.

[0056] Step S1.2.3: Based on the building's heat balance equation, establish a mathematical model for heat users and determine the dynamic response characteristics of indoor temperature to air temperature and secondary network water supply temperature.

[0057] Specifically, based on the building type, heating area, and whether energy-saving measures are adopted by the heat user, the basic heat load of each heat user is calculated according to formula (13) based on its comprehensive heating index value, as follows: (13) In the above formula, The heating area is expressed in m². This is a comprehensive heating index, expressed in W / m².

[0058] Based on this, a lumped parameter model is established to analyze the variation law of indoor temperature for heating users. The heating user is equivalent to a zero-dimensional node with a certain heat capacity; input the first... Heat sequence of individual heat users (HC) It is determined by the heat exchanger thermodynamic calculations shown in equations (4)-(9), based on the heat loss sequence at the nodes. Then it is determined by equation (14): (14) in: (15) (16) In the above formula, The time step is expressed in seconds (s). For the first Step heat load correction factor, dimensionless; This is the predicted indoor temperature value for the nth heat user. Calculate the indoor temperature for the nth heat user. Calculate outdoor temperature The outdoor predicted temperature is in °C. C The equivalent heat capacity of a building, expressed in kJ / (m³). 2 ·℃).

[0059] Step S1.2.4: Based on the law of conservation of energy, the relationship between the supply and return water temperatures of the heating first station is obtained by combining the time delay and heat loss parameters of the integrated pipeline, the heat exchange calculation model of the heat exchange station, and the dynamic response model of the heat user. The steam extraction sequence of the cogeneration unit when heating is supplied according to the heating strategy is determined, and a dynamic mathematical model of the heating network is formed.

[0060] Specifically, the return water from each heat exchange station experiences a time delay before flowing to the first station. Based on energy conservation, the discrete relationship between the mixed temperatures of the return water from each heat exchange station and the final temperature can be derived as follows: (17) in, This is the primary flow sequence of heat exchange station numbered n, with units of kg / s.

[0061] Meanwhile, according to the law of conservation of energy, the water supply temperature at the first station Compared with the return water temperature of the first station The relationship is: (18) In the above formula, This is a sequence of extraction steam rates, with units of kg / s; The enthalpy difference between the extracted steam and the condensate from the generator unit; This represents the isobaric specific heat capacity of the circulating water on the heating network side. Based on the above calculations, the extraction steam rate sequence can be obtained. This establishes the thermal connection between the heating network and the generating units.

[0062] In step S2, an optimized scheduling program is written and deployed based on the central control system.

[0063] Consider a combined heat and power (CHP) system comprising an extraction condensing turbine and a district heating system. A dynamic mathematical model of the heating network is constructed using the method described above. The optimization objective is to adjust the heating-side parameters so that the actual power generation of the extraction condensing turbine tracks the given electrical load demand as closely as possible. The time step index of the problem is... The complete optimization problem is transformed into an optimization scheduling model. This model aims to minimize the deviation between the actual power generation and the demand power of the generating units, and uses factors such as user indoor temperature, the unit's thermal power operating domain, the water supply temperature boundary, and pipeline safety operating parameters as constraints. The final decision variable is the initial water supply temperature sequence. and the start / stop Boolean sequence of the auxiliary heat exchanger in the heat exchange station .

[0064] Specifically, based on the dynamic mathematical model of the heating network constructed above, it can be described as a model function used in optimized scheduling, which can be expressed as: (19) In the above formula, The model function used in the optimization scheduling is used to calculate the power generation sequence under a given heating strategy (i.e., decision variables). And when operating according to this heating strategy N Indoor temperature sequence of a heat user That is, the input to the model function is the heating strategy, which includes the water supply temperature sequence of the primary heating station. , N Boolean sequence for starting and stopping the auxiliary heat exchanger of a heating station. .

[0065] Based on this, the objective function for optimizing the scheduling model can be expressed as: (20) In the above formula, The objective function for optimizing scheduling is, in physical terms, the power generation sequence calculated by the model. With the target electrical load demand sequence of the unit difference; The total number of time steps within the optimized interval. For time step indexing.

[0066] Based on the above design, during the scheduling process, firstly, the predicted outdoor temperature and the given target electrical load sequence are input; then, based on the predicted outdoor temperature, the above model function is used. The power generation sequence and user indoor temperature sequence under different heating strategies are calculated. If the predicted indoor temperature is within the set range, the heating strategy is effective. Then, as shown in Equation (20), the optimization algorithm searches for the heating strategy that minimizes the difference between the power generation sequence and the given target load sequence within all effective strategies, which is the final optimal scheduling strategy obtained. The target load demand sequence refers to the power generation sequence that is predetermined based on the medium- and long-term contract power volume, the day-ahead electricity price forecast, and past operating experience, and that maximizes the profitability of the generating unit.

[0067] In steps S3 and S4, during actual production operation, the input parameters of the optimization algorithm are obtained and the above-mentioned optimization scheduling program is applied to solve the optimization scheduling model to obtain the optimal scheduling strategy and execute it to achieve thermoelectric synergy.

[0068] Specifically, firstly, the input parameters of the optimization algorithm are determined: on the one hand, by comprehensively considering the medium- and long-term contracted electricity volume, day-ahead electricity price forecasts, and past operating experience, the power generation sequence that maximizes the profitability of the generating units is determined, and this sequence is used as the electricity load demand sequence. On the one hand, the temperature forecast for the next day is input into the central control system, and on the other hand, the temperature forecast for the next day is input into the central control system as the basis for calculating the heat load.

[0069] Secondly, the optimization algorithm is invoked in the central control system. The optimization scheduling model is solved by using mixed integer programming algorithm or intelligent optimization algorithm to obtain the optimal scheduling strategy, namely the water supply temperature sequence of the first heating station (the daily steam extraction curve of the unit can be calculated from this sequence) and the control strategy of the heat exchange station. Based on this strategy, combined with the unit's thermal power operation domain and specific operating experience, the daily power adjustment boundary of the unit side is given, and the daily power generation and heating plan is determined on this basis.

[0070] Finally, the start-up and shutdown times of the auxiliary heat exchangers at each heat exchange station are sent to each heat exchange station for execution. Each heat exchange station can adjust the secondary flow rate and the start-up and shutdown time of the auxiliary heat exchangers based on the specific indoor temperature of the heat users, in order to ensure that the heat supplied to users matches the actual heat load.

[0071] The system and method proposed in this embodiment are verified and illustrated through the following example. Specifically, the purpose of this example is to use simulation calculations, taking a 330MW extraction condensing unit and its supporting heating network as the research object, to supplement the system composition and connection method, and further illustrate the effect that the system and method for improving the peak capacity of the cogeneration unit and the heating network by utilizing the start-up and shutdown of the auxiliary heat exchanger can achieve in actual production operation.

[0072] First, the scenario setting for the example (i.e., the instance) is explained: the unit involved in the example is a 330MW extraction condensing turbine with a rated load, where steam is extracted through perforated low- and medium-pressure connecting pipes, and condensate is returned to the deaerator. In this instance, the calculations are based on the following... Figure 5 The operating domain is calculated based on the principle thermodynamic system diagram of the steam turbine shown. Figure 6 As shown.

[0073] Secondly, in this example, the combined heat and power unit supplies heat to three heat exchange stations located at different distances through a long-distance pipeline network. The parameter settings of these heat exchange stations are shown in Table 1 below.

[0074] Table 1. Parameter configuration of heat exchange station in the embodiments

[0075] In the example, HES (1) is a heating area for energy-efficient buildings, HES (2) is a heating area for ordinary buildings, and HES (3) is a heating area for old buildings. All of the above buildings are brick-concrete / steel-concrete structures with the same total heat load; compared with energy-efficient buildings, old buildings have higher heat load indices and lower total heat capacity. This allows the example to demonstrate the effectiveness of the method when the heating network contains buildings of different ages and types.

[0076] In addition, all three heat exchange stations are equipped with auxiliary heat exchangers that are exactly the same as the original heat exchangers in terms of model and heat exchange area. The primary side of the main and auxiliary heat exchangers is connected in series and the secondary side is connected in parallel, which can be put into operation and cut off at specific time points according to the results given by the optimization algorithm.

[0077] Next, a mixed-integer genetic algorithm is used for optimization. The variables to be optimized are the water supply temperature sequence of the primary heating station and the start-up strategy of the auxiliary heat exchanger. The objective function is the peak capacity of the combined heat and power unit. During actual operation, all intermediate variables involved in the calculation should also be saved to check whether the system operating conditions under the above strategy meet the requirements of the following algorithm constraints.

[0078] The constraints of the algorithm include: (1) Indoor temperature constraints: In this example, the indoor design temperature for heat users is 22℃, and the allowable range of room temperature variation is 20℃-24℃; (2) Operating domain constraints: The operating point of the cogeneration unit needs to be kept within the unit's operating domain; (3) Water supply temperature constraints: The maximum water supply temperature of the primary network shall not exceed 120℃ and the minimum shall not be lower than 80℃.

[0079] The aforementioned optimization algorithm allows for the integration of variables such as deep peak-shaving capacity and the range of changes in user room temperature into the objective function, ensuring peak-shaving capacity while also considering deep peak-shaving and user thermal comfort. The operating parameters of the generating units and the primary heating station obtained using this algorithm are shown in Table 2 below.

[0080] Table 2. Operating parameters of the generating unit and the first station in the example.

[0081] like Figure 7 The example shown illustrates the co-generation unit and primary heating station operating conditions during the coordinated peak-shaving process of the auxiliary heat exchanger start-up and shutdown. Based on the results of the optimization algorithm, the specific system operation flow is as follows: The most challenging period for deep peak shaving occurs around 1 PM, requiring the unit to reduce output and decrease steam extraction, with the actual operating point located at the lower boundary of the operating domain. The most challenging period for supply assurance occurs around 6 PM, requiring the unit to increase peak capacity, further reducing steam extraction. The main advantage of this strategy is that reducing heat and increasing power output increases the peak load by 23.27 MW, effectively achieving coordinated peak-shaving supply through co-generation. Simultaneously, the peak load is reduced by 22.49 MW during the deep peak shaving period, indicating that the method is also beneficial for deep peak shaving.

[0082] like Figure 8The example shown illustrates the operating conditions of heat exchange stations and heat users during the coordinated peak-shaving process of the auxiliary heat exchanger's start-up and shutdown. The focus is on the operating conditions of older buildings with the smallest heat capacity. As the figure shows, during the daytime when temperatures are high, the optimization algorithm utilizes the higher primary network water supply temperature to store heat for users, at which time the auxiliary heat exchanger is shut down to prevent users from overheating. However, after the water supply temperature decreases, to ensure stable indoor temperatures for heat users, each heat exchange station activates the auxiliary heat exchanger to increase heat transfer efficiency. This ensures a higher heat supply even under low water supply temperature conditions, curbing the downward trend in user temperatures.

[0083] During peak-hour operation of a combined heat and power (CHP) unit in conjunction with a heating network, the reduction in steam extraction inevitably leads to a decrease in the supply water temperature. In traditional systems, this decrease in supply water temperature inevitably results in a reduction in the actual heat supply to users after a certain period. However, as the above example demonstrates, the impact of primary network supply water temperature fluctuations is significantly mitigated by introducing the start-up and shutdown of the auxiliary heat exchanger as a network-side regulation measure. The activation of the auxiliary heat exchanger increases the overall heat transfer efficiency of the heat exchange station, resulting in a decrease in the primary return water temperature. This low-temperature return water returns to the unit at night, where the unit increases steam extraction to reheat it to the temperature level before the combined heat and power network operation. In this cycle, the primary network completes a full heat release-storage process, fully utilizing its heat capacity. Although the primary network temperature fluctuates significantly during this process, the indoor temperature of users remains within acceptable limits, and heating safety is not affected by the combined heat and power operation.

[0084] Therefore, the method proposed in this embodiment utilizes the isolation effect of the heat exchange station to limit the impact of primary network water temperature fluctuations to the primary network side. This combined heat and power (CHP) measure optimizes the spatiotemporal distribution of heat, alleviating the limitation of daytime heating on the unit's peak capacity while utilizing the unit's redundant heating capacity at night. The above examples also fully demonstrate that this scheme can effectively improve peak capacity through the coordinated operation of CHP units and the heating network.

[0085] Example 3 This embodiment provides an electronic device, including: a memory for storing executable instructions; and a processor for executing the executable instructions stored in the memory to implement the method provided in this embodiment.

[0086] Example 4 This embodiment also provides a computer-readable storage medium storing executable instructions, which, when executed by a processor, will cause the processor to execute the method described above in this embodiment.

[0087] The steps and methods involved in Embodiments 2 to 5 above correspond to those in Embodiment 1. For specific implementation details, please refer to the relevant description section of Embodiment 1. The term "computer-readable storage medium" should be understood as a single medium or multiple media including one or more instruction sets; it should also be understood as including any medium capable of storing, encoding, or carrying an instruction set for execution by a processor and enabling the processor to perform any of the methods in this invention.

[0088] Those skilled in the art will understand that the modules or steps of the present invention described above can be implemented using general-purpose computer devices. Optionally, they can be implemented using computer-executable program code, thereby allowing them to be stored in a storage device for execution by a computer device, or they can be fabricated as separate integrated circuit modules, or multiple modules or steps can be fabricated as a single integrated circuit module. The present invention is not limited to any particular combination of hardware and software.

[0089] The above description is only a preferred embodiment of the present invention. Although the specific implementation of the present invention has been described in conjunction with the accompanying drawings, it is not intended to limit the scope of protection of the present invention. Those skilled in the art should understand that, based on the technical solution of the present invention, various modifications or variations that can be made by those skilled in the art without creative effort are still within the scope of protection of the present invention.

Claims

1. A system for enhancing the peak capacity of a thermal power unit in coordination with a heating network, characterized in that, include: A combined heat and power (CHP) unit is used to simultaneously generate electrical energy and heat energy in the form of steam. The primary heating station is used to heat the primary network return water using steam generated by the combined heat and power unit. The primary network connects the heating station and each heat exchange station, and is used to transmit heat energy; At least one heat exchange station is connected between the primary network and the secondary network for heat exchange; the heat exchange station includes main and auxiliary heat exchangers arranged in parallel, as well as connecting pipes, sensors, and valves, and the valves on the connecting pipes of the auxiliary heat exchangers are controlled by a central control system to respond to adjustment commands to activate or deactivate the auxiliary heat exchangers. The secondary network connects the heat exchanger to the heat exchange equipment of the heat user and is used to transfer heat energy; The central control system receives data collected by sensors, optimizes and calculates to obtain control strategies, and generates adjustment commands for valve opening and closing.

2. The unit peak capacity enhancement system for coordinated co-generation of thermal power units and heating networks as described in claim 1, characterized in that, The main heat exchanger and the auxiliary heat exchanger constitute a heat exchanger group. Both of them use plate heat exchangers of the same specifications. Both heat exchangers are arranged in countercurrent. The primary side is connected in series in the primary network, and the secondary side is connected in parallel in the secondary network. The heat exchanger assembly is equipped with valves on both the primary and secondary sides. The valves between the heat exchanger assembly and the primary side supply and return water pipes, as well as the valve at the secondary side outlet of the main heat exchanger, are normally open during the heating season. The primary side outlet of the main heat exchanger is connected to two branches. One branch is connected to the primary side return water pipe and is equipped with valve 1C. The other branch is connected to the primary side inlet of the auxiliary heat exchanger and is equipped with valve 1D. The secondary side of the auxiliary heat exchanger is directly connected to the secondary network, and valve 2B is provided between the two. Valves 1C, 1D, and 2B are controlled by the central control system and are used to respond to adjustment commands to activate or deactivate the auxiliary heat exchanger.

3. The unit peak capacity enhancement system for coordinating thermal power units and heating networks as described in claim 1, characterized in that, The sensors in the heat exchange station include temperature sensors and flow sensors, both of which are connected to the central control system. Both types of sensors are installed at the inlet and outlet of the primary network and the secondary network of the heat exchange station to collect the temperature and flow rate of the primary network water supply, primary network return water, secondary network water supply, and secondary network return water, and transmit them to the central control system.

4. A method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network, characterized in that, The system for enhancing the peak capacity of a cogeneration unit in coordination with a heating network, as described in any one of claims 1-3, includes: Establish the cogeneration operation domain of the cogeneration unit and the dynamic mathematical model of the heating network; the dynamic mathematical model of the heating network takes the water supply temperature sequence of the primary heating station and the start-up and shutdown time points of the auxiliary heat exchangers of each heat exchange station as inputs, and outputs the predicted indoor temperature of the heat users. Based on the dynamic mathematical model of the heating network, with the goal of minimizing the deviation between the actual power generation and demand of the units, and with user indoor temperature and the thermal power operation domain of the units as constraints, an optimized scheduling model is constructed. The optimal scheduling strategy is obtained by solving the optimal scheduling model with the unit power load demand sequence and outdoor temperature forecast value in the future target period as input; the optimal scheduling strategy is the water supply temperature sequence of the heating station in the future target period and the start-stop status sequence of the auxiliary heat exchangers of each heat exchange station. During the actual operation of the target time period in the future, the optimal scheduling strategy will be executed.

5. The method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network as described in claim 4, characterized in that, Based on the heat balance diagram of the combined heat and power (CHP) unit, the CHP operating domain of the unit is established as follows: By identifying thermal calculations or historical operating data, the upper and lower boundaries of the power generation capacity of the cogeneration unit under different heat loads are determined. These boundaries are represented as a planar polygon with the extraction steam flow / heat supply as the horizontal axis and the actual power generation capacity as the vertical axis. The area within the polygon is the cogeneration operating domain of the unit for stable operation.

6. The method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network as described in claim 4, characterized in that, A dynamic mathematical model of the heating network is constructed using the discrete equation method based on time-delay heat loss identification, as follows: Identify the time delay and heat loss parameters of the heat medium transmission in the supply and return water pipelines of each heat exchange station; Based on the heat transfer effectiveness-number of heat transfer units method, a heat transfer calculation model for a heat exchange station is established, including the start-up and shutdown conditions of the main heat exchanger and the auxiliary heat exchanger. Based on the building's heat balance equation, a dynamic response model of indoor temperature to heating supply and outdoor temperature for heat users is established. Based on the law of conservation of energy, the relationship between the supply and return water temperatures of the heating first station is obtained by combining the time delay and heat loss parameters of the integrated pipeline, the heat exchange calculation model of the heat exchange station, and the dynamic response model of the heat user. The steam extraction sequence of the unit is determined, and a dynamic mathematical model of the heating network is formed.

7. The method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network as described in claim 6, characterized in that, The identification of time delay and heat loss parameters for supply and return water pipelines is as follows: Historical time-series data of supply and return water temperatures at the primary heating station and each heat exchange station were collected and preprocessed by cleaning and interpolation. A temperature correlation model was established between the supply and return water temperature sequences of the primary heating station and the primary side supply and return water temperature sequences of each heat exchange station. Using preprocessed data as input, a grid search method was employed to traverse parameter combinations to determine the coefficients. With the goal of maximizing, the optimal parameters of time delay and heat loss of the supply and return water pipelines of each heat exchange station are obtained by solving.

8. The method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network as described in claim 4, characterized in that, The power load demand sequence is a power generation curve that is determined based on power market information or grid dispatch instructions and is expected to be tracked by combined heat and power units.

9. An electronic device, characterized in that, include: Memory, used to store executable instructions; The processor, when executing executable instructions stored in the memory, implements the method for enhancing the peak capacity of a cogeneration unit in coordination with a heating network as described in any one of claims 4-8.

10. A computer-readable storage medium, characterized in that, The device stores executable instructions that, when executed by a processor, implement the method for enhancing the peak capacity of a co-generation unit and a heating network as described in any one of claims 4-8.

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