Power dispatching strategy determination method and device, and electronic device

Abstract

The application discloses a power dispatching strategy determination method and device and electronic equipment. The method comprises the following steps: acquiring the region parameters of a target power region. According to the region parameters, a target function with the minimum target power region power consumption as the target is determined, and a first constraint condition for the target function is determined. According to the target function under the first constraint condition, a power dispatching strategy corresponding to the target power region is determined. The application solves the technical problem that in the related art, when the power dispatching strategy of the target power region is determined, only the adjustable load device is adjusted, the adjustable resources are few, and the power operation cost is high.

Description

TECHNICAL FIELD

[0001] The present application relates to the field of data processing, and in particular, to a power dispatch strategy determination method and device and electronic equipment. BACKGROUND

[0002] Power dispatch is an effective management means to ensure that the power grid can stably operate and various power production work can orderly develop. Currently, the commonly used power dispatch strategy is that a load aggregation merchant centrally manages and dispatches adjustable load devices. However, this power dispatch strategy has the problems of fewer adjustable load devices and high power operation cost.

[0003] In view of the above problems, no effective solution strategy has been proposed. SUMMARY

[0004] Embodiments of the present application provide a power dispatch strategy determination method and device and electronic equipment to at least solve the technical problem of fewer adjustable resources and high power operation cost in determining a power dispatch strategy of a target power region in the related art.

[0005] According to an aspect of an embodiment of the present application, a power dispatch strategy determination method is provided, including: obtaining a region parameter of a target power region. According to the region parameter, a target function with minimization of power consumption cost of the target power region as a target and a first constraint condition for constraining the target function are determined, wherein the target function includes: a dispatch cost function, a device operation cost function, the dispatch cost function includes a first cost item and a second cost item, the first cost item represents a cost of signing a power price dispatch contract by a target object, the first cost item includes a contract compensation amount item and a contract compensation cost item, the contract compensation amount item represents a compensation amount obtained after the target object signs the power price dispatch contract, the contract compensation cost item represents a compensation cost after the target object signs the power price dispatch contract, the power price dispatch contract is a contract for adjusting power prices in multiple time periods and reducing predetermined power consumption in a load peak period, the load peak period is a period in which load consumption exceeds a predetermined load threshold, the multiple time periods include the load peak period, the second cost item represents a cost saved after the power price dispatch contract is implemented compared with before the power price dispatch contract is implemented, the device operation cost function includes a fuel cost function of a generator set included in the target power region, a start-stop cost function and a wind power abandonment cost function, the first constraint condition includes a power balance constraint of the generator set, a unit start-stop time constraint, a generator set output constraint, a standby unit output constraint and an object power reduction constraint. According to the target function under the first constraint condition, a power dispatch strategy corresponding to the target power region is determined.

[0006] Optionally, before determining the objective function aimed at minimizing the electricity cost of the target power area based on regional parameters, and before setting the first constraint condition for the objective function, the method further includes: determining the initial electricity price and price adjustment coefficient of the target power area based on the regional parameters of the target power area; determining the contract electricity price for multiple time periods based on the price adjustment coefficient and the initial electricity price; determining the first electricity cost function based on the initial electricity price and the initial electricity load function, and determining the second electricity cost function based on the contract electricity price and the contract electricity load function, wherein the initial electricity load is the predicted electricity load of the target entity before signing an electricity price dispatch contract, and the contract electricity load is the predicted electricity load of the target entity after signing an electricity price dispatch contract; and obtaining the second cost term by determining the difference between the first and second electricity cost functions.

[0007] Optionally, before determining the objective function aimed at minimizing the electricity cost of the target power area, and the first constraint condition for constraining the objective function, based on the regional parameters, the method further includes: determining the contract electricity price corresponding to multiple time periods, and the power reduction function corresponding to the target object in each of the multiple time periods, based on the regional parameters of the target power area; determining the contract compensation cost item based on the contract electricity price corresponding to each of the multiple time periods and the power reduction function corresponding to the target object in each of the multiple time periods; determining the contract compensation amount item obtained after the target object signs the electricity price dispatch contract; and obtaining the first cost item based on the contract compensation cost item and the contract compensation amount item.

[0008] Optionally, after determining the objective function (aiming to minimize the electricity cost of the target power region) and the first constraint condition for the objective function based on regional parameters, the process further includes: determining the profit function corresponding to the contract object. Based on the objective function and the profit function, a balance function and a second constraint condition corresponding to the balance function are determined, wherein the balance function is a function that balances maximizing the profit of the contract object and minimizing the electricity cost of the target power region. Under the second constraint condition, the balance function is solved to determine the power balance strategy corresponding to the target power region.

[0009] Optionally, the profit function corresponding to the contract object is determined, including: determining the predetermined profit rate and the contract compensation function obtained after the target object signs the electricity price dispatch contract. The profit function is determined based on the predetermined profit rate and the contract compensation function.

[0010] Optionally, before determining the first electricity cost function based on the initial electricity price and the initial electricity load function, and before determining the second electricity cost function based on the contract electricity price and the contract electricity load function, the method further includes: determining the demand price elasticity coefficient based on the regional parameters of the target power area. The contract electricity load function is then determined based on the demand price elasticity coefficient, the initial electricity price, the initial electricity load function, and the contract electricity price.

[0011] Optionally, after determining the power dispatch strategy corresponding to the target power area based on the objective function under the first constraint, the method further includes: controlling the corresponding power equipment in the target power area and setting it according to the corresponding power dispatch parameters in the power dispatch strategy.

[0012] According to one aspect of the present invention, a power dispatching strategy determination apparatus is provided, comprising: an acquisition module, configured to acquire regional parameters of a target power area; and a first determination module, configured to determine, based on the regional parameters, an objective function aimed at minimizing the electricity cost of the target power area, and a first constraint condition constraining the objective function, wherein the objective function includes: a dispatching cost function and an equipment operating cost function, the dispatching cost function including a first cost item and a second cost item, the first cost item representing the cost of a target object signing a power price dispatching contract, the first cost item including a contract compensation amount item and a contract compensation cost item, the contract compensation amount item representing the compensation amount obtained by the target object after signing the power price dispatching contract, and the contract compensation cost item representing the compensation amount obtained by the target object after signing the power price dispatching contract. The compensation cost is defined as follows: the electricity price dispatch contract is a contract to adjust electricity prices for multiple time periods and reduce predetermined electricity consumption during peak load periods. Peak load periods are the periods when load consumption exceeds a predetermined load threshold. Multiple time periods include peak load periods. The second cost item represents the cost savings after implementing the electricity price dispatch contract compared to before implementing the contract. The equipment operating cost function includes the fuel cost function, start-up and shutdown cost function, and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes the power balance constraint of the generator units, the start-up and shutdown time constraint of the generator units, the output constraint of the generator units, the output constraint of the standby units, and the power reduction constraint of the target. The second determination module is used to determine the power dispatch strategy corresponding to the target power area based on the objective function under the first constraint condition.

[0013] According to one aspect of the present invention, an electronic device is provided, comprising: a processor; and a memory for storing processor-executable instructions; wherein the processor is configured to execute instructions to implement any of the above-described power dispatch strategy determination methods.

[0014] According to one aspect of the present invention, a computer-readable storage medium is provided, which, when the instructions in the computer-readable storage medium are executed by a processor of an electronic device, enables the electronic device to perform any of the above-described power dispatch strategy determination methods.

[0015] In this embodiment of the invention, regional parameters of the target power area are obtained; based on the regional parameters, an objective function is determined with the goal of minimizing the electricity cost of the target power area, and a first constraint condition is set to constrain the objective function. The objective function includes: a dispatch cost function and a device operation cost function. The dispatch cost function includes a first cost item and a second cost item. The first cost item represents the cost of the target object signing an electricity price dispatch contract. The first cost item includes a contract compensation amount item and a contract compensation cost item. The contract compensation amount item represents the compensation amount obtained by the target object after signing the electricity price dispatch contract, and the contract compensation cost item represents the compensation cost of the target object after signing the electricity price dispatch contract. The electricity price dispatch contract is for multiple... The invention involves adjusting electricity prices during specific time periods and contracts to reduce predetermined electricity consumption during peak load periods. Peak load periods are defined as times when load consumption exceeds a predetermined load threshold. Multiple time periods are included. The second cost term represents the cost savings after implementing the electricity price dispatch contract compared to before. The equipment operating cost function includes the fuel cost function, start-up and shutdown cost function, and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes generator power balance constraints, generator start-up and shutdown time constraints, generator output constraints, standby generator output constraints, and target power reduction constraints. Based on the objective function under the first constraint condition, a power dispatch strategy corresponding to the target power area is determined. It can be seen that this invention achieves the goal of minimizing the electricity cost of the target power area by determining the objective function with the aim of minimizing the electricity cost of the target power area based on regional parameters and by imposing the first constraint condition on the objective function. Since the objective function is composed of the equipment operation cost function and the power system dispatch cost function of the power system in the target power area, and takes into account constraints such as the power output and start-up / shutdown time of the power system generators, the power dispatch strategy for the target power area determined by the objective function can minimize the power cost while meeting the power demand of the target power area. This solves the technical problem in related technologies where the power dispatch strategy for the target power area only adjusts adjustable load equipment, resulting in limited dispatchable resources and high power operation costs. Attached Figure Description

[0016] The accompanying drawings, which are included to provide a further understanding of the invention and form part of this application, illustrate exemplary embodiments of the invention and, together with their description, serve to explain the invention and do not constitute an undue limitation thereof. In the drawings:

[0017] Figure 1 This is a flowchart of a power dispatching strategy determination method according to an embodiment of the present invention;

[0018] Figure 2 This is a structural block diagram of a power dispatching strategy determination device according to an embodiment of the present invention. Detailed Implementation

[0019] To enable those skilled in the art to better understand the strategies of this invention, the technical strategies in the embodiments of this invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are merely some, not all, of the embodiments of this invention. All other embodiments obtained by those skilled in the art based on the embodiments of this invention without creative effort should fall within the scope of protection of this invention.

[0020] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0021] Example 1

[0022] According to an embodiment of the present invention, an embodiment of a power dispatching strategy determination method is provided. It should be noted that the steps shown in the flowchart in the accompanying drawings can be executed in a computer system such as a set of computer-executable instructions. Furthermore, although a logical order is shown in the flowchart, in some cases, the steps shown or described may be executed in a different order than that shown here.

[0023] Figure 1 This is a flowchart of a power dispatching strategy determination method according to an embodiment of the present invention, such as... Figure 1 As shown, the method includes the following steps:

[0024] Step S102: Obtain the regional parameters of the target power area.

[0025] In step S102 of this application, the regional parameters of the target power area are obtained.

[0026] This involves the target power area, which refers to a specific geographical area in the power system, consisting of specific busbars, substations, or distribution networks.

[0027] This involves regional parameters, which refer to various data and indicators related to the operating status, load characteristics, power generation and transmission capacity, and system flexibility of the target power area. Examples include the power demand within the area, the total power generation potential of all power generation units within the area, and information on distributed power sources.

[0028] In this step, the regional parameters of the target power region are obtained, which is the basic step for determining the objective function corresponding to the target power region.

[0029] It should be noted that regional parameters can be obtained through various means such as sensors, metering equipment, historical databases, and predictive models.

[0030] Step S104: Based on the regional parameters, determine the objective function aimed at minimizing the electricity cost in the target power area, and the first constraint condition for constraining the objective function. The objective function includes: a dispatch cost function and an equipment operating cost function. The dispatch cost function includes a first cost item and a second cost item. The first cost item represents the cost of the target entity signing the electricity dispatch contract. The first cost item includes a contract compensation amount item and a contract compensation cost item. The contract compensation amount item represents the compensation amount received by the target entity after signing the electricity dispatch contract, and the contract compensation cost item represents the compensation cost of the target entity after signing the electricity dispatch contract. A price dispatch contract is an agreement to adjust electricity prices for multiple time periods and reduce predetermined electricity consumption during peak load periods. Peak load periods are the periods when load consumption exceeds a predetermined load threshold. Multiple time periods include peak load periods. The second cost item represents the cost savings after implementing the price dispatch contract compared to before implementing the price dispatch contract. The equipment operating cost function includes the fuel cost function, start-up and shutdown cost function, and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes the power balance constraint of the generator units, the start-up and shutdown time constraint of the units, the output constraint of the generator units, the output constraint of the standby units, and the power reduction constraint of the target.

[0031] In step S104 of this application, an objective function aimed at minimizing the electricity cost of the target power area is determined based on the regional parameters, and a first constraint condition is used to constrain the objective function.

[0032] This involves electricity costs, which refer to all costs incurred to meet the electricity demand of a target power area, such as generation costs, transmission and distribution costs, grid upgrade and expansion costs, and power system dispatch costs.

[0033] This involves the objective function, which describes a specific goal or set of goals that needs to be achieved in an optimization problem. Under the premise of satisfying a series of constraints, the goal is to find a set of values ​​for decision variables so that the objective function reaches its optimal value.

[0034] This involves the first constraint condition, which refers to a series of constraints that must be met when planning power dispatch strategies, including generator power balance constraints, generator start-up and shutdown time constraints, generator output constraints, standby generator output constraints, and target power reduction constraints.

[0035] This involves the scheduling cost function, which refers to a function of the various direct and indirect costs incurred by power dispatching operations.

[0036] This involves the equipment operating cost function, which refers to a function of the direct and indirect costs generated during the power generation process.

[0037] This involves the first cost item, which refers to the costs incurred in signing electricity price dispatch contracts with target entities during the power dispatch process. This includes the contract compensation amount for economic compensation to the target entities.

[0038] This involves a second cost item, which refers to the cost reduction after implementing the contracted electricity price in the electricity price dispatch contract compared to the initial electricity price.

[0039] This involves the target group, which refers to the electricity users who have signed electricity price dispatch contracts.

[0040] This involves electricity price dispatch contracts, which are a type of electricity market tool that guides users to adjust their electricity consumption behavior by setting different electricity prices for different time periods and reducing predetermined electricity consumption during peak load periods, thereby achieving peak shaving and valley filling of load and optimizing the balance between electricity supply and demand.

[0041] This includes the contract compensation amount, which refers to the cost incurred by the power system in setting a compensation amount to encourage target entities to reduce electricity consumption during peak load periods in the process of implementing electricity price dispatch contracts.

[0042] This includes the contract compensation cost item, which refers to the cost incurred due to the reduction of electricity consumption by the target entity during the implementation of the electricity price dispatch contract.

[0043] This involves peak load periods, which refer to the time periods when electricity demand exceeds the average or a set threshold.

[0044] This involves the planned electricity consumption, which refers to the amount of electricity that needs to be reduced according to the electricity price dispatch contract in order to reduce the load on the power system during peak hours.

[0045] This involves load factor, which refers to the amount of electricity consumed or used.

[0046] This involves a predetermined load threshold, which refers to the maximum electricity consumption of a target power area at a certain time, pre-set according to the area parameters of the target power area.

[0047] This involves generator sets, which are devices that can convert mechanical energy or other forms of energy into electrical energy.

[0048] This involves the fuel cost function, which is a function of the cost of burning fuel during power generation. Its value depends on factors such as power generation, fuel type, fuel price, and generator efficiency.

[0049] This involves the start-up and shutdown cost function, which refers to the cost required for a generator set to switch from a shutdown state to an operating state, or from an operating state to a shutdown state. Start-up and shutdown costs are related to the physical characteristics of the equipment and the frequency of start-up and shutdown.

[0050] This involves the wind curtailment cost function, which is a function of the cost of power generation that the power system abandons due to its inability to fully absorb renewable energy generation. It is usually related to the system's dispatch strategy, the accuracy of renewable energy generation forecasts, and the grid's transmission capacity.

[0051] This involves the power balance constraint, which means that the total power generation of the power system at any given time must be equal to the total power demand, that is, the sum of the output power of all generator sets equals the sum of the power demand of all loads plus network losses.

[0052] This involves unit start-up and shutdown time constraints. These constraints are set to ensure that the start-up and shutdown operations of the generator set comply with specific time rules, avoid damage to the equipment, and ensure stable system operation. They include minimum start-up time constraints and minimum shutdown time constraints. That is, once the generator set starts, it must run continuously for at least a predetermined minimum period of time, and after the generator set is shut down from the running state, it must remain in the shutdown state for at least a predetermined minimum period of time to prevent equipment damage caused by frequent start-ups and shutdowns.

[0053] This involves generator output constraints, which refer to the minimum and maximum output power of each generator set during each scheduling period.

[0054] This involves the standby unit output constraint, which refers to the minimum and maximum standby power that the standby unit can provide during each scheduling period.

[0055] This involves target power reduction constraints, which refer to the upper and lower limits of the amount of power that can be reduced from a target object within a specific time period. This is to ensure the flexibility of power system dispatching and avoid causing excessive inconvenience to users.

[0056] In this step, based on the regional parameters of the target power area, an objective function aimed at minimizing the electricity cost of the target power area is determined, along with a first constraint condition for constraining the objective function.

[0057] This approach comprehensively considers the costs associated with electricity price dispatch contracts and the direct costs of operating power generation equipment, thereby determining the objective function and achieving optimal economic costs while ensuring the safe operation of the power system and the balance between power supply and demand.

[0058] This involves step S106, which determines the power dispatch strategy corresponding to the target power area based on the objective function under the first constraint condition.

[0059] In step S106 provided in this application, a power dispatch strategy corresponding to the target power area is determined based on the objective function under the first constraint condition.

[0060] This involves power dispatching strategies, which refer to how to arrange the operation plan of generator units, adjust the load, allocate available resources, and cope with the fluctuations in renewable energy generation under a given objective function and constraint framework.

[0061] Through steps S102-S106 above, the regional parameters of the target power area are obtained. Based on the regional parameters, an objective function is determined with the goal of minimizing the electricity cost of the target power area, and a first constraint condition is established to constrain the objective function. The objective function includes: a dispatch cost function and an equipment operation cost function. The dispatch cost function includes a first cost item and a second cost item. The first cost item represents the cost of the target entity signing a power dispatch contract. The first cost item includes a contract compensation amount item and a contract compensation cost item. The contract compensation amount item represents the compensation amount received by the target entity after signing the power dispatch contract, and the contract compensation cost item represents the compensation cost of the target entity after signing the power dispatch contract. This invention relates to a contract for adjusting electricity prices across multiple time periods and reducing predetermined electricity consumption during peak load periods. Peak load periods are defined as times when load consumption exceeds a predetermined load threshold. The multiple time periods include peak load periods. The second cost term represents the cost savings after implementing the electricity price dispatch contract compared to before. The equipment operating cost function includes the fuel cost function, start-up and shutdown cost function, and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes generator power balance constraints, generator start-up and shutdown time constraints, generator output constraints, standby generator output constraints, and target power reduction constraints. Based on the objective function under the first constraint condition, a power dispatch strategy corresponding to the target power area is determined. It can be seen that this invention achieves the goal of minimizing the electricity cost of the target power area by determining the objective function with the aim of minimizing the electricity cost of the target power area based on regional parameters and by imposing the first constraint condition on the objective function. Since the objective function is composed of the equipment operation cost function and the power system dispatch cost function of the power system in the target power area, and takes into account constraints such as the power output and start-up / shutdown time of the power system generators, the power dispatch strategy for the target power area determined by the objective function can minimize the power cost while meeting the power demand of the target power area. This solves the technical problem in related technologies where the power dispatch strategy for the target power area only adjusts adjustable load equipment, resulting in limited dispatchable resources and high power operation costs.

[0062] As an optional embodiment, before determining the objective function aimed at minimizing the electricity cost of the target power area based on regional parameters, and before imposing a first constraint condition on the objective function, the method further includes: determining the initial electricity price and electricity price adjustment coefficient of the target power area based on the regional parameters of the target power area; determining the contract electricity price corresponding to multiple time periods based on the electricity price adjustment coefficient and the initial electricity price; determining a first electricity cost function based on the initial electricity price and the initial electricity load function, and determining a second electricity cost function based on the contract electricity price and the contract electricity load function, wherein the initial electricity load is the predicted electricity load of the target object before signing an electricity price dispatch contract, and the contract electricity load is the predicted electricity load of the target object after signing an electricity price dispatch contract; and determining the difference between the first electricity cost function and the second electricity cost function to obtain the second cost term.

[0063] This embodiment describes the specific steps for determining the objective function with the goal of minimizing the electricity cost of the target power area based on regional parameters, and for determining the second cost term before imposing the first constraint condition on the objective function.

[0064] This involves the initial electricity price, which refers to the price level set by the electricity market or power company before the signing of the electricity price dispatch contract. This forms the basis of the electricity price dispatch contract, and subsequent contract prices will be adjusted based on this.

[0065] This involves the electricity price adjustment coefficient, which is a parameter used in power dispatching strategies to adjust the initial electricity price.

[0066] This involves contract electricity prices, which are electricity prices set by power companies in electricity dispatch contracts to incentivize users to adjust their electricity consumption behavior. Compared to the initial electricity price, the contract electricity price increases during peak hours and decreases during off-peak hours to achieve peak shaving and valley filling, and optimize electricity supply and demand.

[0067] This involves the initial electricity load function, which refers to the expected electricity load function of users in the target power area at each time period before the signing of the electricity price dispatch contract.

[0068] This involves the first electricity cost function, which refers to the total cost function of the power system calculated based on the initial electricity price and the initial electricity load function. It reflects the electricity cost of the power system when no optimization strategy is implemented.

[0069] This involves the contracted electricity load function, which refers to the adjusted projected electricity load function generated after the signing of an electricity price dispatch contract, whereby the electricity load of the target power area will be directly affected by the contracted electricity price.

[0070] This involves the second electricity cost function, which refers to the total cost function of the power system calculated based on the contracted electricity price and the contracted electricity load function. It reflects the electricity cost after implementing the electricity price dispatch optimization strategy.

[0071] In this step, firstly, based on the regional parameters of the target power area, the initial electricity price and electricity price adjustment coefficient for that area are determined. The electricity price adjustment coefficient can adjust the electricity price at different times. Secondly, based on the electricity price adjustment coefficient and the initial electricity price, the contract electricity price after implementing the electricity price dispatch contract in each time period is calculated, thus completing the adjustment of electricity prices for multiple time periods. This guides users to increase electricity consumption during periods with lower electricity prices and decrease electricity consumption during periods with higher electricity prices, thereby reducing the operating costs of the power system. Next, based on the initial electricity price and the initial electricity load function, the electricity cost without implementing any dispatch strategy is calculated. Using the contract electricity price and the contract electricity load function, the electricity cost after implementing the dispatch strategy is calculated. Finally, by comparing the first electricity cost function and the second electricity cost function, the cost savings after implementing the power dispatch strategy are determined.

[0072] This step calculates the second cost item, which directly quantifies the economic benefits brought about by adjusting electricity prices at different times and guiding users to stagger their electricity consumption during the implementation of the electricity price dispatch strategy. By subsequently determining the power dispatch strategy, this part of the economic benefits can be maximized.

[0073] As an optional embodiment, before determining the objective function aimed at minimizing the electricity cost of the target power area based on regional parameters, and before imposing a first constraint condition on the objective function, the method further includes: determining the contract electricity price corresponding to multiple time periods and the power reduction function corresponding to the target object in each of the multiple time periods based on the regional parameters of the target power area; determining the contract compensation cost item based on the contract electricity price corresponding to each of the multiple time periods and the power reduction function corresponding to the target object in each of the multiple time periods; determining the contract compensation amount item obtained by the target object after signing the electricity price dispatch contract; and obtaining the first cost item based on the contract compensation cost item and the contract compensation amount item.

[0074] This embodiment describes the specific steps for determining the first cost term before determining the objective function with the goal of minimizing the electricity cost of the target power area based on the regional parameters, and before imposing the first constraint condition on the objective function.

[0075] This involves a power reduction function, which describes the predicted reduction in electricity load for a target object during different time periods after signing an electricity price dispatch contract, relative to when it did not have a contract.

[0076] In this step, firstly, based on the regional parameters of the target power area, the contract electricity price and the power reduction function of the target entity for each time period are determined. Both the contract electricity price and the power reduction are intended to guide the target entity to reduce electricity consumption during periods of higher electricity prices, thereby alleviating the load pressure on the power system. Secondly, based on the contract electricity price and the corresponding power reduction function for each time period, the contract compensation cost item is determined. The contract compensation cost item is the cost incurred due to the target entity's electricity price adjustment and power reduction after the implementation of the electricity price dispatch contract. Then, the contract compensation amount item obtained after the target entity signs the electricity price dispatch contract is determined. Finally, based on the contract compensation cost item and the contract compensation amount item, the first cost item is obtained.

[0077] This step determines the total dispatch cost incurred by executing the electricity dispatch contract. By subsequently determining the power dispatch strategy and designing a reasonable contract price and power reduction function, the cost of the entire dispatch process can be minimized, saving the total electricity cost.

[0078] As an optional embodiment, after determining the objective function aimed at minimizing the electricity cost of the target power area based on regional parameters, and the first constraint condition constraining the objective function, the method further includes: determining the profit function corresponding to the contract object. Based on the objective function and the profit function, a balance function and a second constraint condition corresponding to the balance function are determined, wherein the balance function is a function that balances maximizing the profit of the contract object and minimizing the electricity cost of the target power area. Under the second constraint condition, the balance function is solved to determine the power balance strategy corresponding to the target power area.

[0079] This embodiment describes the steps of determining an objective function based on regional parameters, aiming to minimize the electricity cost of the target power region, and then, after imposing a first constraint on the objective function, solving the balance function under a second constraint to determine the power balance strategy corresponding to the target power region.

[0080] This involves establishing contract objects, which refers to the entity that formulates power dispatch contracts and provides power resources.

[0081] This involves a profit function, which describes the profit or revenue of a contract object after the target object signs a power dispatch contract.

[0082] This involves the balance function, which is a function used in electricity market dispatch to coordinate the interests of different participants.

[0083] This involves a second constraint, which refers to an additional restriction that must be followed when designing a power balancing strategy: maximizing the profitability of the contract object while minimizing the electricity cost of the target power area.

[0084] In this step, firstly, the profit function corresponding to the contract object is determined; secondly, based on the objective function and the profit function, the balance function and the corresponding second constraint are determined. The determination of the balance function and its corresponding second constraint expands the objective of power dispatch optimization to finding a balance between maximizing the profit of the contract object and minimizing the power system cost; finally, under the second constraint, the balance function is solved to determine the power balance strategy corresponding to the target power area. The power balance strategy obtained through this step can significantly reduce the operating cost of the power system while ensuring that the contract object obtains reasonable profits, thus maximizing economic benefits.

[0085] As an optional embodiment, determining the profit function corresponding to the contract object includes: determining a predetermined profit rate and a contract compensation function obtained after the target object signs an electricity price dispatch contract. The profit function is determined based on the predetermined profit rate and the contract compensation function.

[0086] This embodiment describes the specific steps for determining the profit function corresponding to the contract object.

[0087] This involves the predetermined profit margin, which is the profit target percentage set by the contracting party based on costs.

[0088] This involves the contract compensation function, which is a mathematical model used to describe the compensation amount obtained by a target object due to signing a power dispatch contract.

[0089] In this step, firstly, the predetermined profit margin and the contract compensation function obtained after the target entity signs the electricity price dispatch contract are determined. That is, the expected profit level of the contract entity from the electricity price dispatch contract is established, and the compensation amount that the target entity should receive for participating in the contract is calculated. Then, based on the predetermined profit margin and the contract compensation function, the profit function is determined. By designing a reasonable profit function, it is possible to ensure that while providing sufficient economic incentives for the target entity to participate in electricity price dispatch, it is also possible to maintain its own profit target.

[0090] As an optional embodiment, before determining the first electricity cost function based on the initial electricity price and the initial electricity load function, and before determining the second electricity cost function based on the contract electricity price and the contract electricity load function, the method further includes: determining the demand price elasticity coefficient based on the regional parameters of the target power area. The contract electricity load function is then determined based on the demand price elasticity coefficient, the initial electricity price, the initial electricity load function, and the contract electricity price.

[0091] In this embodiment, before determining the first electricity cost function based on the initial electricity price and the initial electricity load function, and before determining the second electricity cost function based on the contract electricity price and the contract electricity load function, the specific steps for determining the contract electricity load function are as follows.

[0092] This involves the price elasticity coefficient of demand, which is a numerical value used to quantify the relationship between changes in electricity prices and changes in electricity demand, and measures the sensitivity of electricity demand to changes in electricity prices.

[0093] In this step, firstly, the demand price elasticity coefficient is determined, and the relationship between the change in electricity price and the change in electricity demand is determined. Then, based on the demand price elasticity coefficient, the initial electricity price, the initial electricity load function, and the contract electricity price, the contract electricity load function is determined.

[0094] This step allows for accurate prediction of the contracted electricity load function, enabling better allocation of power generation resources, avoiding over-generation during peak hours and resource waste during off-peak hours, and saving on power generation costs.

[0095] As an optional embodiment, after determining the power dispatch strategy corresponding to the target power area based on the objective function under the first constraint condition, the method further includes: controlling the corresponding power equipment in the target power area and setting it according to the power dispatch parameters corresponding to the power dispatch strategy.

[0096] This embodiment describes the steps of adjusting power dispatching parameters after determining the power dispatching strategy corresponding to the target power area based on the objective function under the first constraint condition.

[0097] This involves power equipment, which refers to various devices in the power system, such as generators, transformers, circuit breakers, load controllers, energy storage devices, and smart meters. These devices form the physical foundation for the operation of the power system, and the implementation of power dispatch strategies requires adjusting the operating status of these devices.

[0098] This involves power dispatch parameters, which are specific quantitative indicators of power dispatch strategies, including generator output, load management dispatch instructions, energy storage device charging and discharging plans, and substation operation modes.

[0099] In this step, power equipment within the target power area is controlled according to the parameters set in the power dispatch strategy. In this way, the operation of power equipment can be precisely controlled to meet the power demand of the target power area, while reducing unnecessary power generation costs, increasing the proportion of renewable energy such as wind power, and reducing the overall power generation cost.

[0100] Based on the above embodiments and optional embodiments, an optional implementation method is provided, which is described in detail below.

[0101] An optional embodiment of the present invention provides a method for determining a power dispatching strategy, applicable to the area involved by power equipment connected to the same busbar.

[0102] First, peak-valley-flat electricity pricing is used to optimize the peak-valley-flat load forecast curves for some busbars. This method reduces the peak values ​​and increases the valley values ​​of the load forecast curves for some busbars, lowering the load standard deviation and thus achieving peak shaving and valley filling.

[0103] Peak-valley flat pricing is considered to control the timing of electricity consumption by adjusting the price of electricity for users. During peak consumption periods, the electricity price is increased by a certain percentage based on the base price, and during off-peak periods, the electricity price is decreased by a certain percentage based on the base price. During periods of low consumption, electricity can be sold at the base price, while during peak and off-peak periods, the price fluctuates by the same percentage as the base price. This can optimize the load curve, reduce the standard deviation of the load, and better play the role of peak shaving and valley filling.

[0104] Secondly, load aggregators (LAs) are introduced to establish load reduction contracts. After optimizing the load curve, peak-valley-flat pricing allows electricity users to make corresponding adjustments according to their plans during peak and valley periods, which brings about reasonable scheduling of generating units to reduce the burden on the power system. However, it will not completely achieve the desired reduction of peak loads. By introducing load aggregators (LAs) to establish load reduction contracts, the load during peak periods can be further reduced.

[0105] Finally, a day-ahead scheduling model was developed to achieve cost savings.

[0106] It should be noted that the dispatching system in the power system related to the day-ahead dispatching model is based on meeting the load demand of users. It establishes constraints such as supply and demand balance, reserve capacity, and system power balance, so as to minimize the operating cost of the power system.

[0107] With the improvement of people's living standards in recent years, the power grid capacity has been gradually expanding, and users' demand for power supply and the reliability of power supply are also constantly increasing. Therefore, it is becoming increasingly important to formulate reasonable dispatch optimization models. Traditional power system operating costs only consider the output cost of conventional units. However, the addition of new energy sources has increased the difficulty. The traditional approach of minimizing the cost of conventional units is no longer sufficient. Therefore, the optional implementation of this invention considers the integration of new energy sources into the grid. When formulating the day-ahead dispatch model, it considers the cost of wind curtailment, the start-up and shutdown costs of conventional units, the cost of power generation fuel, and uses peak-valley-flat electricity pricing and load aggregator pricing to minimize the compensation profit obtained for optimization modeling.

[0108] The optional implementation of this invention uses a bus load situation prediction method and prediction results to obtain a bus load prediction curve, which is then optimized using an energy storage system. This method combines the overall load situation of each bus in each region with the characteristic that peak-valley-flat pricing can optimize the load prediction curve. It also compensates for the limitation of load aggregators only being able to suppress peak loads. Therefore, by combining load aggregators and peak-valley-flat pricing to optimize the overall load situation curve, the standard deviation of the overall load curve and the peak-valley difference are effectively reduced. Furthermore, based on ensuring the safety, stability, and reliability of the power system, a day-ahead power dispatch model is established. Load aggregators and peak-valley-flat pricing coordinate to participate in dispatch, reducing the operating cost of power system generator units and realizing the rational arrangement of generator output in power grid dispatch, thereby maximizing resource utilization.

[0109] Specifically, the steps of the power dispatching strategy determination method provided in the optional embodiments of the present invention include:

[0110] S1. Determine the peak-valley-flat electricity price.

[0111] The model for determining the contract electricity price is represented as follows:

[0112] d t =d0(1+u t β d )

[0113] Where, d t Let d be the electricity price at time t; d0 be the base price; u t This parameter represents the adjustment of electricity prices based on the base price during peak and off-peak periods, taking values ​​of 1, 0, and -1 for peak, normal, and off-peak periods, respectively; β d This represents the percentage fluctuation of the time-of-use electricity price.

[0114] S2. Determine the second cost item.

[0115] The specific steps are as follows:

[0116] A1. Determine the first electricity cost function:

[0117] Before the implementation of peak-valley flat electricity pricing, the system operator's electricity revenue C before,TOU,t for:

[0118] C before,TOU,t =d0P B,t

[0119] Among them, P B,t The electricity load at time t before the implementation of peak-valley flat electricity pricing.

[0120] A2. Determine the contracted electricity load function:

[0121] Determine the price elasticity coefficient ε of demand:

[0122]

[0123] Among them, P B,TOU,t To determine the electricity load at time t after the peak-valley flat electricity price is set.

[0124] After implementing peak-valley flat electricity pricing, the user load function becomes:

[0125]

[0126] A3. Determine the second electricity cost function:

[0127] After the implementation of peak-valley flat electricity pricing, the electricity fee charged by the system operator is C. later.TOU.t for:

[0128] C later.TOU.t =d t P B,TOU,t

[0129] A4. Determine the second cost item:

[0130] The system operator's cost, i.e., the change C in electricity revenue before and after the implementation of peak-valley-flat pricing. TOU,t , represented as:

[0131] C TOU,t =C before,TOU,t -C later.TOU.t

[0132] S2. Determine the first cost item.

[0133] When load aggregators participate in power system dispatch, there will inevitably be certain costs involved. Load aggregators also incur costs when participating in the electricity market and executing reduction contracts. The specific calculation steps are as follows:

[0134] B1. Determine the amount of contract compensation.

[0135] To arrange power system dispatching plans according to the stipulated contracts, the first step is to determine the contract reduction compensation amount C received by the nth user during the transaction process from the load aggregator. ef,LA,n,t yes:

[0136]

[0137] Among them, w 1n Let w be the coefficient of the quadratic term of the compensation amount received by the nth user. 2n Let P be the coefficient of the linear term representing the compensation amount received by the nth user. LA,n,t This represents the power reduction value of the nth user at time t when executing the load aggregator (LA) reduction contract. It is 1 when the contract is executed and 0 when it is not executed.

[0138] B2. Determine the first cost item:

[0139]

[0140] Among them, C LA,t This represents the cost incurred by the load aggregator in executing the reduction contract, where i represents the number of users who have signed contracts with the load aggregator, and C represents the cost. ef,LA,t This represents the total amount of contract compensation received by all users.

[0141] S3. Determine the scheduling cost function.

[0142] The cost C of the dispatch system is the sum of the change in electricity revenue from the contracted electricity price and the cost incurred by the aggregator in executing the reduction contract. LA,TOU,t :

[0143] C LA,TOU,t =C TOU,t +C LA,t

[0144] S4. Determine the equipment operating cost function.

[0145] C1. Determine the objective function for the total cost of power generation:

[0146] Fuel cost C of conventional units coal.g as follows:

[0147]

[0148] Where, θ coal This represents the cost of fuel for conventional generating units, u j,t P represents the operating state of conventional unit j at time t as a 0-1 variable, where 1 represents the start-up state and 0 represents the shutdown state; j,t Let N be the output of conventional unit j at time t, where T is the total time period and N is the total output of unit j at time t. g This represents the total number of generating units.

[0149] f j (P j,t The energy consumption characteristic curve of a conventional unit is shown below.

[0150]

[0151] Where, parameter a j b j c j This is the output coefficient for conventional generating units.

[0152] C2. Determine the start-up and shutdown costs of conventional units. on,off,g :

[0153] C on,off,g =u j,t (1-u j,t-1 )S on,t +u j,t-1 (1-u j,t )S off,t

[0154] Among them, S on,t and S off,t These represent the start-up cost and shutdown cost of unit j, respectively.

[0155] C3. Determine the wind curtailment cost of conventional units:

[0156] Firstly, to ensure that wind turbines are connected to the grid before conventional turbines and to improve wind power utilization, the system curtailment cost C is introduced. w Its model is:

[0157]

[0158] Where, θ ws The penalty price for wind curtailment represents the acceptable range for wind curtailment within the power system; P pre,w,t P is the predicted wind power output at time t; w,t The actual wind power output at time t; T is the total time period.

[0159] C4. Determine the equipment operating cost function C G :

[0160] C G =C coal.g +C on,off,g +C w +C LA,TOU,t

[0161] S5. Determine the objective function C.

[0162] To maximize resource utilization and rationally allocate unit output, the following settings are configured:

[0163] minC=min(C G )

[0164] The optimal power dispatch strategy can be obtained by solving for minC.

[0165] S6. Determine the constraints.

[0166] However, when solving the objective function and determining the power dispatch strategy with the lowest cost, it is also necessary to take into account the actual situation, such as the actual operating conditions of the generator sets and the user experience, and to determine a series of constraints.

[0167] D1. Power balance constraint:

[0168]

[0169] D2. Unit start-up and shutdown time constraints:

[0170] u j,t (1-u j,t+1 M on,j ≤X on,j,t

[0171] u j,t+1 (1-u j,t M off,j ≤X off,j,t

[0172] Among them, X on,j,t Let X represent the continuous operating time of unit j. off,j,t M represents the duration of continuous downtime of unit j; on,j This represents the minimum operating time of unit j, M. off,j This represents the minimum downtime set for unit j.

[0173] D3. Determine the constraints for conventional generating units:

[0174] u j,t P min,j ≤P j,t ≤u j,t P max,j

[0175]

[0176] Among them, P min,j P max,j These are the minimum and maximum outputs of conventional unit j, respectively. This represents the range of allowable ramping power variation for thermal power units within two adjacent time periods.

[0177] D4. System Backup Constraints:

[0178]

[0179] Among them, R ds,t R represents the required spin-off reserve capacity of the system at time t. ts,t This represents the upspin-off reserve capacity required by the system at time t.

[0180] D5. Add upper and lower constraints to LA.

[0181] Since load aggregators deal directly with users, the load reduction ratio must be set based on user satisfaction levels and should not exceed certain upper and lower limits. Therefore, the load reduction scheduling ratio P for a single user is... LA,n,t for:

[0182] P LA,n,t ≤σP max,B,i,t

[0183] Where σ represents the limiting proportionality coefficient, P max,B,i,t This represents the maximum load for user i before optimization.

[0184] S6. Determine the profit function.

[0185] At the same time, it should be noted that load aggregators need to obtain a certain profit in participating in the power system, and their profit amount C cf,LA,t for:

[0186]

[0187] In the formula, λ is the profit margin, which is a parameter pre-determined by the system operator and LA.

[0188] S7. Based on the objective function under the first constraint, determine the power dispatch strategy corresponding to the target power area.

[0189] The objective function is the objective function mentioned above that aims to minimize the electricity cost of the target power area. The first constraint condition is the first constraint condition that constrains the objective function. That is, the objective function includes the following: scheduling cost function, equipment operation cost function. The scheduling cost function includes a first cost item and a second cost item. The equipment operation cost function includes the fuel cost function, start-up and shutdown cost function and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes the power balance constraint of the generator units, the start-up and shutdown time constraint of the units, the output constraint of the generator units, the output constraint of the standby units, and the power reduction constraint of the target.

[0190] Furthermore, a balance function can be established.

[0191] S8. Based on the objective function and the profit function, determine the balance function and the second constraint condition corresponding to the balance function. The balance function is a function that maximizes the profit of the contract object and minimizes the electricity cost of the target power area.

[0192] S9. Under the second constraint, solve the balance function to determine the power balance strategy corresponding to the target power region.

[0193] The above optional implementation methods can achieve at least the following beneficial effects:

[0194] (1) By using peak-valley flat electricity price to optimize the peak-valley flat curve of the load situation prediction curve of some bus, the peak value of the load situation curve of some bus can be reduced and the valley value increased, thus reducing the load standard deviation and playing the role of peak shaving and valley filling.

[0195] (2) Peak-valley flat electricity pricing optimizes the load curve, allowing electricity users to make corresponding adjustments according to their plans during peak and valley periods, which brings reasonable arrangement of generating units to reduce the burden on the power system. However, it will not completely achieve the desired reduction of peak load. By introducing load aggregators (LAs) to establish load reduction contracts, the load during peak periods can be further reduced.

[0196] (3) Traditional power system operating costs only consider the output cost of conventional units. However, the addition of new energy sources has increased the difficulty. The traditional goal of minimizing the cost of conventional units is no longer sufficient. Therefore, the optional implementation of this invention considers the access of new energy to the grid. When formulating the dispatch model, it considers the cost of wind curtailment, the start-up and shutdown cost of conventional units, the cost of power generation fuel, and uses peak-valley flat electricity price and load aggregator to minimize the compensation profit obtained for optimization modeling.

[0197] It should be noted that, for the sake of simplicity, the foregoing method embodiments are all described as a series of actions. However, those skilled in the art should understand that the present invention is not limited to the described order of actions, because according to the present invention, some steps can be performed in other orders or simultaneously. Furthermore, those skilled in the art should also understand that the embodiments described in the specification are preferred embodiments, and the actions and modules involved are not necessarily essential to the present invention.

[0198] Through the above description of the embodiments, those skilled in the art can clearly understand that the methods according to the above embodiments can be implemented by means of software plus necessary general-purpose hardware platforms. Of course, they can also be implemented by hardware, but in many cases the former is a better implementation method. Based on this understanding, the technical strategy of the present invention, or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product is stored in a storage medium (such as ROM / RAM, magnetic disk, optical disk) and includes several instructions to cause a terminal device (which may be a mobile phone, computer, server, or network device, etc.) to execute the methods of the various embodiments of the present invention.

[0199] Example 2

[0200] According to an embodiment of the present invention, an apparatus for implementing the above-described power dispatch strategy determination method is also provided. Figure 2 This is a structural block diagram of a power dispatching strategy determination device according to an embodiment of the present invention, such as... Figure 2 As shown, the device includes: an acquisition module 202, a first determination module 204, and a second determination module 206. The device will be described in detail below.

[0201] The acquisition module 202 is used to acquire regional parameters of the target power area; the first determination module 204, connected to the acquisition module 202, is used to determine, based on the regional parameters, an objective function aimed at minimizing the electricity cost of the target power area, and a first constraint condition for constraining the objective function. The objective function includes: a dispatch cost function and an equipment operation cost function. The dispatch cost function includes a first cost item and a second cost item. The first cost item represents the cost of the target object signing a power price dispatch contract. The first cost item includes a contract compensation amount item and a contract compensation cost item. The contract compensation amount item represents the compensation amount received by the target object after signing the power price dispatch contract, and the contract compensation cost item represents the compensation cost of the target object after signing the power price dispatch contract. The power price dispatch contract is for multiple time periods. The contract involves adjusting the electricity price for a specific period and reducing the predetermined electricity consumption during peak load periods. Peak load periods are defined as the time when the load exceeds a predetermined load threshold. Multiple periods include peak load periods. The second cost item represents the cost savings after implementing the electricity price dispatch contract compared to before implementing the contract. The equipment operating cost function includes the fuel cost function, start-up and shutdown cost function, and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes the power balance constraint of the generator units, the start-up and shutdown time constraint of the generator units, the output constraint of the generator units, the output constraint of the standby units, and the power reduction constraint of the target. The second determination module 206, connected to the first determination module 204, is used to determine the power dispatch strategy corresponding to the target power area based on the objective function under the first constraint condition.

[0202] It should be noted that the above-mentioned acquisition module 202, the first determination module 204 and the second determination module 206 correspond to steps S102 to S106 in the method for determining power dispatch strategy. The multiple modules and the corresponding steps are the same in terms of implementation examples and application scenarios, but are not limited to the content disclosed in the above embodiment 1.

[0203] Example 3

[0204] According to another aspect of the present invention, an electronic device is also provided, comprising: a processor; and a memory for storing processor-executable instructions, wherein the processor is configured to execute instructions to implement the power dispatch strategy determination method of any of the above embodiments.

[0205] Example 4

[0206] According to another aspect of the present invention, a computer-readable storage medium is also provided, which, when the instructions in the computer-readable storage medium are executed by a processor of an electronic device, enables the electronic device to perform the power dispatching strategy determination method described above.

[0207] The sequence numbers of the above embodiments of the present invention are for descriptive purposes only and do not represent the superiority or inferiority of the embodiments.

[0208] In the above embodiments of the present invention, the descriptions of each embodiment have different focuses. For parts not described in detail in a certain embodiment, please refer to the relevant descriptions of other embodiments.

[0209] In the several embodiments provided in this application, it should be understood that the disclosed technical content can be implemented in other ways. The device embodiments described above are merely illustrative; for example, the division of units can be a logical functional division, and in actual implementation, there may be other division methods. For instance, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the displayed or discussed mutual coupling, direct coupling, or communication connection may be through some interfaces; the indirect coupling or communication connection between units or modules may be electrical or other forms.

[0210] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple units. Some or all of the units can be selected to achieve the purpose of the strategy in this embodiment, depending on actual needs.

[0211] Furthermore, the functional units in the various embodiments of the present invention can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0212] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical strategy of this invention, essentially the part that contributes to the prior art, or all or part of the technical strategy, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of this invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, read-only memory (ROM), random access memory (RAM), portable hard drives, magnetic disks, or optical disks.

[0213] The above description is only a preferred embodiment of the present invention. It should be noted that for those skilled in the art, several improvements and modifications can be made without departing from the principle of the present invention, and these improvements and modifications should also be considered within the scope of protection of the present invention.

Claims

1. A method for determining power dispatching strategies, characterized in that, include: Obtain the regional parameters of the target power area; Based on the aforementioned regional parameters, an objective function is determined with the goal of minimizing the electricity cost in the target power region, along with a first constraint condition to constrain the objective function. The objective function includes: a dispatch cost function and a device operation cost function. The dispatch cost function includes a first cost item and a second cost item. The first cost item represents the cost of the target entity signing an electricity price dispatch contract. The first cost item includes a contract compensation amount item and a contract compensation cost item. The contract compensation amount item represents the compensation amount received by the target entity after signing the electricity price dispatch contract, and the contract compensation cost item represents the compensation cost incurred by the target entity after signing the electricity price dispatch contract. The contract is an agreement to adjust electricity prices for multiple time periods and reduce predetermined electricity consumption during peak load periods. The peak load period is the period when the load consumption exceeds a predetermined load threshold. The multiple time periods include the peak load period. The second cost item represents the cost saved after implementing the electricity price dispatch contract compared to before implementing the electricity price dispatch contract. The equipment operating cost function includes the fuel cost function, start-up and shutdown cost function, and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes the power balance constraint of the generator unit, the start-up and shutdown time constraint of the unit, the output constraint of the generator unit, the output constraint of the standby unit, and the power reduction constraint of the target unit. Based on the objective function under the first constraint, a power dispatch strategy corresponding to the target power area is determined; The process includes, based on the regional parameters, determining an objective function aimed at minimizing the electricity cost of the target power region, and a first constraint condition for the objective function, followed by: determining a profit function corresponding to the contract object; determining a balance function and a second constraint condition corresponding to the balance function based on the objective function and the profit function, wherein the balance function is a function that balances maximizing the profit of the contract object and minimizing the electricity cost of the target power region; and solving the balance function under the second constraint condition to determine a power balance strategy corresponding to the target power region. Before determining the objective function aimed at minimizing the electricity cost of the target power region based on the regional parameters, and before setting the first constraint condition for the objective function, the process further includes: determining the initial electricity price and price adjustment coefficient of the target power region based on the regional parameters; determining the contract electricity price corresponding to each of the multiple time periods based on the price adjustment coefficient and the initial electricity price; determining a first electricity cost function based on the initial electricity price and the initial electricity load function, and determining a second electricity cost function based on the contract electricity price and the contract electricity load function, wherein the initial electricity load is the predicted electricity load of the target object before signing the electricity price dispatch contract, and the contract electricity load is the predicted electricity load of the target object after signing the electricity price dispatch contract; and determining the difference between the first electricity cost function and the second electricity cost function to obtain the second cost item. Before determining the objective function aimed at minimizing the electricity cost of the target power region based on the regional parameters, and before setting the first constraint condition for the objective function, the method further includes: determining the contract electricity price corresponding to each of the multiple time periods and the power reduction function corresponding to each of the multiple time periods for the target object based on the regional parameters of the target power region; determining the contract compensation cost item based on the contract electricity price corresponding to each of the multiple time periods and the power reduction function corresponding to each of the multiple time periods for the target object; determining the contract compensation amount item obtained by the target object after signing the electricity price dispatch contract; and obtaining the first cost item based on the contract compensation cost item and the contract compensation amount item.

2. The method according to claim 1, characterized in that, Determine the profit function corresponding to the contract object, including: Determine the predetermined profit margin and the contract compensation function obtained after the target object signs the electricity price dispatch contract; The profit function is determined based on the predetermined profit rate and the contract compensation function.

3. The method according to claim 1, characterized in that, Before determining the first electricity cost function based on the initial electricity price and initial electricity load function, and before determining the second electricity cost function based on the contract electricity price and contract electricity load function, the process further includes: Based on the regional parameters of the target power region, determine the demand price elasticity coefficient; The contract electricity load function is determined based on the demand price elasticity coefficient, the initial electricity price, the initial electricity load function, and the contract electricity price.

4. The method according to any one of claims 1 to 3, characterized in that, After determining the power dispatch strategy corresponding to the target power area based on the objective function under the first constraint, the method further includes: Control the corresponding power equipment in the target power area, and set the power dispatch parameters according to the power dispatch strategy.

5. A power dispatching strategy determination device, characterized in that, include: The acquisition module is used to acquire the regional parameters of the target power area; The first determining module is used to determine, based on the regional parameters, an objective function aimed at minimizing the electricity cost of the target power region, and a first constraint condition for constraining the objective function. The objective function includes: a dispatch cost function and a device operating cost function. The dispatch cost function includes a first cost item and a second cost item. The first cost item represents the cost of the target object signing the electricity price dispatch contract. The first cost item includes a contract compensation amount item and a contract compensation cost item. The contract compensation amount item represents the compensation amount received by the target object after signing the electricity price dispatch contract, and the contract compensation cost item represents the compensation cost of the target object after signing the electricity price dispatch contract. The electricity price dispatch contract is an agreement to adjust electricity prices for multiple time periods and reduce predetermined electricity consumption during peak load periods. The peak load period is the period when the load consumption exceeds a predetermined load threshold. The multiple time periods include the peak load period. The second cost item represents the cost saved after implementing the electricity price dispatch contract compared to before implementing the electricity price dispatch contract. The equipment operating cost function includes the fuel cost function, start-up and shutdown cost function, and wind curtailment cost function of the generator units included in the target power area. The first constraint condition includes the power balance constraint of the generator unit, the start-up and shutdown time constraint of the unit, the output constraint of the generator unit, the output constraint of the standby unit, and the power reduction constraint of the target unit. The second determining module is used to determine the power dispatching strategy corresponding to the target power area based on the objective function under the first constraint condition. The first determining module is further configured to determine the profit function corresponding to the contract object; determine the balance function and the second constraint condition corresponding to the balance function based on the objective function and the profit function, wherein the balance function is a function that balances maximizing the profit of the contract object and minimizing the electricity cost of the target power area; and solve the balance function under the second constraint condition to determine the power balance strategy corresponding to the target power area. The first determining module is further configured to: determine the initial electricity price and electricity price adjustment coefficient of the target power area based on the regional parameters of the target power area; determine the contract electricity price corresponding to the multiple time periods based on the electricity price adjustment coefficient and the initial electricity price; determine the first electricity cost function based on the initial electricity price and the initial electricity load function, and determine the second electricity cost function based on the contract electricity price and the contract electricity load function, wherein the initial electricity load is the predicted electricity load of the target object before signing the electricity price dispatch contract, and the contract electricity load is the predicted electricity load of the target object after signing the electricity price dispatch contract; and determine the difference between the first electricity cost function and the second electricity cost function to obtain the second cost item. The first determining module is further configured to: determine the contract electricity price corresponding to each of the multiple time periods and the power reduction function corresponding to each of the multiple time periods for the target object, based on the regional parameters of the target power area; determine the contract compensation cost item based on the contract electricity price corresponding to each of the multiple time periods and the power reduction function corresponding to each of the multiple time periods for the target object; determine the contract compensation amount item obtained by the target object after signing the electricity price dispatch contract; and obtain the first cost item based on the contract compensation cost item and the contract compensation amount item.

6. An electronic device, characterized in that, include: processor; Memory used to store the processor's executable instructions; The processor is configured to execute the instructions to implement the power dispatch strategy determination method as described in any one of claims 1 to 4.

7. A computer-readable storage medium, characterized in that, When the instructions in the computer-readable storage medium are executed by the processor of the electronic device, the electronic device is able to perform the power dispatch strategy determination method as described in any one of claims 1 to 4.

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