A power grid dispatching method, device and equipment

Abstract

The application discloses a power grid dispatching method, device and equipment, and relates to the technical field of power systems. The method comprises the following steps: acquiring the current operation state of a power grid; determining the dispatching time scale in which the power grid is currently located according to the current operation state; determining a target control area from the power grid according to the dispatching time scale and the current operation state; selecting a target dispatching rule base from a plurality of preset dispatching rule bases according to the dispatching time scale and the target control area, and generating a dispatching instruction based on the target dispatching rule base; and sending the dispatching instruction to corresponding energy storage equipment in the target control area, so that the energy storage equipment adjusts the charging and discharging power according to the dispatching instruction. Compared with the prior art, the application dynamically identifies the dispatching time scale and the target control area of the power grid, and matches the corresponding dispatching rule base, so that the precise adaptation of multi-element energy storage to the real-time state of the power grid is realized.

Description

Technical Field

[0001] This application relates to the field of power system technology, and in particular to a power grid dispatching method, apparatus and equipment. Background Technology

[0002] In power grid dispatching and operation, to address the uncertainties brought about by fluctuating power sources such as hydropower, wind power, and solar power, dispatching systems typically incorporate diverse energy storage resources, including reservoir hydropower, pumped storage, and electrochemical energy storage, for coordinated regulation. Existing technical solutions establish optimization models at different time scales (annual, monthly, day-ahead, and real-time) to impose corresponding technical constraints on the operation of each energy storage resource. Based on fixed or empirical rules, they switch dispatching modes at preset time nodes, thereby generating dispatching instructions to guide energy storage devices in adjusting their charging and discharging power.

[0003] However, the dominant demand and key conflict areas of the power grid will dynamically shift with the real-time status of new energy output and load changes. Fixed cycles and regional divisions are difficult to match the most urgent balance needs and security bottlenecks in a timely and accurate manner, resulting in lag or mismatch in the activation and switching of constraint models. This makes it impossible for the regulation capacity of diversified energy storage resources to be efficiently utilized at the most needed spatiotemporal scales.

[0004] Therefore, how to adaptively schedule diverse energy storage resources based on the real-time status of the power grid is an urgent problem to be solved. Summary of the Invention

[0005] The main objective of this application is to provide a power grid dispatching method, apparatus, and equipment, which aims to solve the technical problem of how to adaptively dispatch diverse energy storage resources according to the real-time state of the power grid.

[0006] To achieve the above objectives, this application proposes a power grid dispatching method, which is applied to a power dispatching system connected to various energy storage devices. The method includes: Obtain the current operating status of the power grid; The current scheduling time scale of the power grid is determined based on the current operating status; Based on the scheduling timescale and the current operating status, a target control area is determined from the power grid; Based on the scheduling time scale and the target control area, a target scheduling rule library is selected from multiple preset scheduling rule libraries, and scheduling instructions are generated based on the target scheduling rule library. The scheduling command is sent to the corresponding energy storage device within the target control area so that the energy storage device adjusts its charging and discharging power according to the scheduling command.

[0007] In one embodiment, the scheduling time scale includes a first scheduling time scale, a second scheduling time scale, and a third scheduling time scale, and the step of determining the current scheduling time scale of the power grid based on the current operating state includes: Obtain the preset scheduling calendar and the time information in the current running state; Based on the preset scheduling calendar and the time information, determine the planning stage type at the current moment; If the planning phase type is an annual planning phase or a monthly planning phase, then the scheduling time scale is determined as the first scheduling time scale; If the planning phase type is the day-ahead planning phase, then the scheduling time scale is determined as the second scheduling time scale; If the planning phase type is a real-time planning phase, then the scheduling time scale is determined as the third scheduling time scale.

[0008] In one embodiment, the step of determining the target control area from the power grid based on the scheduling timescale and the current operating state includes at least one of the following: When the scheduling time scale is the first scheduling time scale, the deviation data between the planned power and the actual power generation of the cross-regional tie line is obtained from the current operating state, and the power concentration area connected by the cross-regional tie line with the largest deviation in the deviation data is determined as the target control area. When the scheduling time scale is the second scheduling time scale, the load rate of the key transmission section is obtained from the current operating state, and the area where the key transmission section with the highest load rate is located is determined as the target control area; When the scheduling time scale is the third scheduling time scale, system frequency deviation, voltage deviation and power fluctuation data are obtained from the current operating state, and the load concentration area where the system frequency deviation exceeds the preset frequency threshold, the load concentration area where the voltage deviation exceeds the preset voltage threshold, or the load concentration area where the power fluctuation exceeds the preset power threshold is determined as the target control area.

[0009] In one embodiment, the plurality of preset scheduling rule bases include a first scheduling rule base, a second scheduling rule base, and a third scheduling rule base, and the step of selecting a target scheduling rule base from the plurality of preset scheduling rule bases includes: When the scheduling time scale is the first scheduling time scale, the first scheduling rule base is selected as the target scheduling rule base; When the scheduling time scale is the second scheduling time scale, the second scheduling rule base is selected as the target scheduling rule base, wherein the operating boundary of the second scheduling rule base is determined by the planned value of adjustable hydropower generation and the planned value of cross-regional tie line transmission power output by the first scheduling rule base. When the scheduling time scale is the third scheduling time scale, the third scheduling rule base is selected as the target scheduling rule base, wherein the operating framework of the third scheduling rule base is determined by the energy storage benchmark charging and discharging plan and the power flow plan value of the key transmission section output by the second scheduling rule base.

[0010] In one embodiment, the energy storage device includes a hydroelectric reservoir, the scheduling instruction includes a first scheduling instruction, and the step of generating the scheduling instruction based on the target scheduling rule base includes: When the target scheduling rule base is the first scheduling rule base, the water level constraint parameters of the hydropower reservoir and the power constraint parameters of the inter-regional connecting line are obtained. The first scheduling instruction is generated based on the water level constraint parameters and the power constraint parameters.

[0011] In one embodiment, the energy storage device further includes an energy storage power station, the scheduling instruction includes a second scheduling instruction, and the step of generating the scheduling instruction based on the target scheduling rule base further includes: When the target scheduling rule base is the second scheduling rule base, the power balance parameters of the power grid and the daily cycle operation parameters of the energy storage power station are obtained; The second scheduling instruction is generated based on the power balance parameters and the daily cycle operation parameters.

[0012] In one embodiment, the energy storage device further includes a fast-response energy storage device, the scheduling instruction further includes a third scheduling instruction, and the step of generating the scheduling instruction based on the target scheduling rule base further includes: When the target scheduling rule base is the third scheduling rule base, power fluctuation smoothing parameters and transmission section safety parameters are obtained from the current operating state; Obtain the rapid adjustment response parameters in the fast-response energy storage device; The third scheduling instruction is generated based on the power fluctuation smoothing parameters, the transmission section safety parameters, and the rapid adjustment response parameters.

[0013] In one embodiment, before the step of sending the scheduling command to the energy storage device corresponding to the target control area, the method further includes: Determine whether the dispatching instruction satisfies the cross-regional power grid stability constraints; When the dispatch instruction satisfies the cross-regional power grid stability constraint, the step of sending the dispatch instruction to the corresponding energy storage device within the target control area is executed. When the scheduling instruction does not meet the cross-regional power grid stability constraints, the target scheduling rule base is constrained and strengthened, and the scheduling instruction is regenerated based on the constrained target scheduling rule base.

[0014] Furthermore, to achieve the above objectives, this application also proposes a power grid dispatching device, the device comprising: The status acquisition module is used to acquire the current operating status of the power grid; The scale determination module is used to determine the current scheduling time scale of the power grid based on the current operating state. The region determination module is used to determine the target control region from the power grid based on the scheduling time scale and the current operating status; The instruction generation module is used to select a target scheduling rule library from multiple preset scheduling rule libraries according to the scheduling time scale and the target control area, and generate scheduling instructions based on the target scheduling rule library; The power adjustment module is used to send the scheduling command to the corresponding energy storage device within the target control area, so that the energy storage device adjusts its charging and discharging power according to the scheduling command.

[0015] In addition, to achieve the above objectives, this application also proposes a power grid dispatching device, the device comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, the computer program being configured to implement the steps of the power grid dispatching method as described above.

[0016] One or more technical solutions proposed in this application have at least the following technical effects: This application first obtains the current operating state of the power grid. Then, it determines the current dispatch timescale of the power grid based on the current operating state. Next, based on the dispatch timescale and the current operating state, it identifies the target control area from the power grid. Then, based on the dispatch timescale and the target control area, it selects a target dispatch rule library from multiple pre-set dispatch rule libraries and generates dispatch instructions based on the target dispatch rule library. Finally, it sends the dispatch instructions to the corresponding energy storage devices within the target control area, so that the energy storage devices adjust their charging and discharging power according to the dispatch instructions. Compared with existing methods, this application achieves precise adaptation between diversified energy storage and the real-time state of the power grid by dynamically identifying the dispatch timescale and target control area of ​​the power grid and matching the corresponding dispatch rule library. Attached Figure Description

[0017] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0018] To more clearly illustrate the technical solutions in the embodiments of this application or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, for those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0019] Figure 1 This is a flowchart illustrating a first embodiment of a power grid dispatching method according to this application; Figure 2 This is a flowchart illustrating a second embodiment of a power grid dispatching method according to this application; Figure 3 This is a flowchart illustrating a third embodiment of a power grid dispatching method according to this application; Figure 4 This is a schematic diagram of the module structure of the power grid dispatching device according to an embodiment of this application; Figure 5 This is a schematic diagram of the equipment structure of the hardware operating environment involved in the power grid dispatching method in this application embodiment.

[0020] The purpose, features, and advantages of this application will be further explained in conjunction with the embodiments and with reference to the accompanying drawings. Detailed Implementation

[0021] It should be understood that the specific embodiments described herein are merely illustrative of the technical solutions of this application and are not intended to limit this application.

[0022] To better understand the technical solution of this application, a detailed description will be provided below in conjunction with the accompanying drawings and specific implementation methods.

[0023] In power grid dispatching and operation, to address the uncertainties brought about by fluctuating power sources such as hydropower, wind power, and solar power, dispatching systems typically incorporate diverse energy storage resources, including reservoir hydropower, pumped storage, and electrochemical energy storage, for coordinated regulation. Existing technical solutions establish optimization models at different time scales (annual, monthly, day-ahead, and real-time) to impose corresponding technical constraints on the operation of each energy storage resource. Based on fixed or empirical rules, they switch dispatching modes at preset time nodes, thereby generating dispatching instructions to guide energy storage devices in adjusting their charging and discharging power.

[0024] However, the dominant demand and key conflict areas of the power grid will dynamically shift with the real-time status of new energy output and load changes. Fixed cycles and regional divisions are difficult to match the most urgent balance needs and security bottlenecks in a timely and accurate manner, resulting in lag or mismatch in the activation and switching of constraint models. This makes it impossible for the regulation capacity of diversified energy storage resources to be efficiently utilized at the most needed spatiotemporal scales.

[0025] Therefore, how to adaptively schedule diverse energy storage resources based on the real-time status of the power grid is an urgent problem to be solved.

[0026] This application provides a solution that first obtains the current operating state of the power grid. Then, it determines the current dispatch timescale of the power grid based on the current operating state. Next, based on the dispatch timescale and the current operating state, it identifies the target control area within the power grid. Then, based on the dispatch timescale and the target control area, it selects a target dispatch rule library from multiple pre-set dispatch rule libraries and generates dispatch instructions based on the target dispatch rule library. Finally, it sends the dispatch instructions to the corresponding energy storage devices within the target control area, enabling the energy storage devices to adjust their charging and discharging power according to the dispatch instructions. Compared to existing solutions, this application achieves precise adaptation between diverse energy storage and the real-time state of the power grid by dynamically identifying the dispatch timescale and target control area of ​​the power grid and matching them with the corresponding dispatch rule library.

[0027] It should be noted that the executing entity in this embodiment can be a computing service device with data processing, network communication, and program execution functions, such as a tablet computer, personal computer, or mobile phone, or an electronic device or power grid dispatching device capable of performing the above functions. The following description uses a power grid dispatching device (hereinafter referred to as the device) as an example to illustrate this embodiment and the subsequent embodiments.

[0028] Based on this, the embodiments of this application provide a power grid dispatching method, referring to... Figure 1 , Figure 1 This is a flowchart illustrating the first embodiment of a power grid dispatching method according to this application.

[0029] In this embodiment, the method is applied to a power dispatching system, which is connected to various energy storage devices. The method includes steps S10 to S50: Step S10: Obtain the current operating status of the power grid.

[0030] It should be noted that the aforementioned power grid can refer to a power network system at the provincial level or above, including a collection of power infrastructure consisting of power generation equipment, transmission lines, substations, energy storage equipment, and electricity loads.

[0031] The aforementioned current operating status can refer to a set of parameter data reflecting the current operating status of the power grid, including real-time power of source-load-storage at each level, power flow at key transmission sections, system frequency and voltage, reservoir water level, and wind and solar ultra-short-term predicted output.

[0032] Among them, the real-time power of source-load-storage at each level refers to the real-time active power output of all conventional power sources (thermal power and hydropower), the real-time active power output of all fluctuating power sources (wind power and photovoltaic), the real-time active power demand of all load nodes, and the real-time charging and discharging power of all energy storage devices (pumped storage and electrochemical energy storage) at different levels such as the provincial dispatching level, regional control level, and plant level.

[0033] The aforementioned key transmission section power flow refers to the active power transmission value of important transmission lines or line groups that connect different power source areas and load areas and play a decisive role in the stability of the power grid structure.

[0034] The aforementioned system frequency and voltage refer to the real-time frequency values ​​of the power system and the real-time voltage amplitudes of each key bus node. The aforementioned reservoir water level refers to the real-time water level data of hydropower reservoirs with regulating capabilities. The aforementioned ultra-short-term wind and solar power output forecasts refer to the power forecast data for wind farms and photovoltaic power plants for the next few minutes to hours.

[0035] Step S20: Determine the current scheduling time scale of the power grid based on the current operating status.

[0036] The aforementioned dispatch timescales refer to the time planning range adopted by the power grid dispatch, including the first, second, and third dispatch timescales. The first dispatch timescale corresponds to long-cycle dispatching during the annual or monthly planning phases, with its core task being cross-seasonal and cross-month energy transfer and resource pre-allocation. The second dispatch timescale corresponds to medium- and short-term dispatching during the day-ahead planning phase, with its core task being to ensure real-time balance of power supply and demand within minutes to hours for the next day. The third dispatch timescale corresponds to real-time dispatching during the real-time planning phase, with its core task being to respond to instantaneous power fluctuations and maintain the real-time stable operation of the power grid.

[0037] The principle for determining the scheduling time scale mentioned above is to match the objective time process with the fixed stages of scheduling plan preparation and execution.

[0038] The aforementioned power dispatching system determines the planning stage type at the current moment based on a preset dispatching calendar and time information in the current operating status.

[0039] The aforementioned preset dispatch calendar refers to a fixed timetable pre-formulated by the power dispatching agency that specifies the start, end, and rolling update times of various periodic dispatch plans (annual plans, monthly plans, and day-ahead plans).

[0040] The above-mentioned planning phase types are mainly divided into annual planning phase, monthly planning phase, daily planning phase, and real-time planning phase.

[0041] In practical implementation, a data acquisition and monitoring system is deployed to obtain real-time information on the current operating status of the provincial power grid, serving as the data foundation for all subsequent analysis and decision-making. Specifically, the acquired current operating status includes data in the following five aspects: First, acquiring real-time power at each level of source-load-storage. At the provincial dispatch level, this involves acquiring the real-time active power output of all conventional power sources (including thermal power units and hydropower units), the real-time active power output of all fluctuating power sources (including wind farms and photovoltaic power stations), the real-time active power demand of all load nodes, and the real-time charging and discharging power of all energy storage devices (including pumped storage power stations and electrochemical energy storage power stations). Data at the regional control level and the substation level is acquired in the same manner. Second, acquiring power flow at key transmission sections. This involves identifying important transmission lines or line groups that connect different power source areas and load areas and play a decisive role in the stability of the power grid structure, and acquiring the active power transmission values ​​of these transmission lines or line groups. The aforementioned power flow at key transmission sections is a key physical quantity for measuring the transmission bottleneck and safety margin of the power grid. Third, acquiring system frequency and voltage. The system acquires real-time frequency values ​​of the power system and real-time voltage amplitudes of key bus nodes. Fourth, it acquires reservoir water levels. For hydropower with regulation capabilities, it acquires real-time reservoir water level data for subsequent calculations of available hydropower and storage / release strategies. Fifth, it acquires ultra-short-term forecast power output of wind and solar power. It acquires ultra-short-term power forecast data for wind farms and photovoltaic power plants for the next few minutes to hours to assess the risk of impending power fluctuations. Next, based on the acquired current operating status, it determines the current dispatch timescale of the power grid. First, it acquires the preset dispatch calendar and time information in the current operating status. The preset dispatch calendar is a fixed timetable pre-established by the power dispatching agency, specifying the start and end times, and rolling update times of various periodic dispatch plans such as annual plans, monthly plans, and day-ahead plans. The time information refers to the standard timestamp corresponding to the collected data. Next, based on the preset dispatch calendar and time information, it determines the type of planning stage at the current moment. The types of planning stages are divided into four types: annual planning stage, monthly planning stage, day-ahead planning stage, and real-time planning stage. If the current moment is determined to be within the annual or monthly planning phase, the dispatch timescale is defined as the first dispatch timescale. Under the first dispatch timescale, the core task of grid dispatch is to conduct cross-seasonal and cross-month energy transfer and resource pre-allocation. If the current moment is determined to be within the day-ahead planning phase, the dispatch timescale is defined as the second dispatch timescale. Under the second dispatch timescale, the core task of grid dispatch is to ensure real-time balance of power supply and demand within minutes to hours for the next day, while also considering grid security. If the current moment is determined to be within the real-time planning phase, the dispatch timescale is defined as the third dispatch timescale. Under the third dispatch timescale, the core task of grid dispatch is to respond to instantaneous power fluctuations and maintain the real-time stable operation of the grid.

[0042] For example, assuming the current time is 10:00 AM on June 1st of a certain year, the following current operating status is obtained through the data acquisition and monitoring system: the provincial dispatch level data shows that the total output of thermal power units is 45,000 MW, the total output of hydropower units is 8,000 MW, the real-time output of wind power is 12,000 MW, the real-time output of photovoltaic power is 15,000 MW, and the total load is 78,000 MW; the active power transmission values ​​of the three key transmission sections are 2,800 MW, 1,950 MW, and 3,200 MW, respectively; the system frequency is 49.98 Hz; the current water level of a large reservoir is 165 meters; the wind power ultra-short-term forecast output for the next 15 minutes shows that the wind power output will decrease by 800 MW.

[0043] Next, the preset scheduling calendar and the time information in the current operating status are obtained. According to the preset scheduling calendar, December is the annual planning stage, and the 25th of each month is the monthly planning stage. 10:00 AM each day falls within the day-ahead planning window (i.e., the generation plan for the next day from 00:00 to 24:00). Based on this, the current planning stage is determined to be the day-ahead planning stage. Therefore, the scheduling time scale is determined as the second scheduling time scale, corresponding to the short-term scheduling plan for the next 24 hours. Under the second scheduling time scale, the focus will be on intraday power balance data such as the load factor of key transmission sections to ensure real-time balance of power supply and demand for the next day.

[0044] Step S30: Determine the target control area from the power grid based on the scheduling time scale and the current operating status.

[0045] It should be noted that the aforementioned target control area can refer to a local power grid area that poses a major challenge to maintaining the overall power balance or safety and stability of the power grid, or has significant regulatory value, within the current dispatch time scale. The method for determining the aforementioned target control area corresponds to the dispatch time scale.

[0046] When the scheduling timescale is the first scheduling timescale, the aforementioned target control area is determined based on the deviation data between the planned and actual power generation of inter-regional interconnection lines. The aforementioned inter-regional interconnection lines can refer to transmission lines connecting different provincial power grids or different regional power grids. The aforementioned planned power generation can refer to the power transmission target that must be completed within a specific period, as determined by medium- and long-term trading contracts or intergovernmental agreements. The aforementioned actual power generation can refer to the actual power generation value transmitted by the inter-regional interconnection lines. The aforementioned deviation data can refer to the difference between the planned and actual power generation. The power concentration area connected by the inter-regional interconnection line with the largest deviation is the source of the largest discrepancy between the inter-regional power balance plan and the actual situation, and is therefore identified as the target control area.

[0047] When the scheduling timescale is the second scheduling timescale, the aforementioned target control area is determined based on the load factor of key transmission sections. The aforementioned key transmission sections can refer to a set of transmission channels composed of multiple transmission lines that play a decisive role in the stable operation of the power grid. The aforementioned load factor can refer to the ratio of the actual transmission power of the key transmission section to its stable operating limit power. The area where the key transmission section with the highest load factor is located is the weakest link in power grid security and most prone to transmission congestion; therefore, it is identified as the target control area.

[0048] When the scheduling timescale is the third scheduling timescale, the aforementioned target control area is determined based on system frequency deviation, voltage deviation, and power fluctuation data. The system frequency deviation can refer to the difference between the actual frequency and the rated frequency of the power grid. The voltage deviation can refer to the difference between the actual voltage amplitude and the rated voltage of a key bus node. The power fluctuation data can refer to the rate of change or amplitude of change of net load power over time within a local area. The aforementioned preset frequency threshold, preset voltage threshold, and preset power threshold are safety boundary values ​​pre-set based on power grid safe operation procedures, equipment capacity, and stability analysis. Load concentration areas where the system frequency deviation exceeds the preset frequency threshold, the voltage deviation exceeds the preset voltage threshold, or the power fluctuation exceeds the preset power threshold are the main sources of disturbance or weak points that cause or exacerbate real-time instability in the power grid, and are therefore identified as target control areas.

[0049] In practice, the target control area is determined from the power grid based on the established scheduling time scale and the acquired current operating status.

[0050] When the determined scheduling timescale is the first scheduling timescale, the deviation data between the planned power generation and the actual power generation of all inter-regional interconnection lines is obtained from the current operating status. This deviation data directly reflects the execution status of the long-term power balance plan. Next, the deviation value of each inter-regional interconnection line is calculated, the inter-regional interconnection line with the largest deviation value is identified, and the power concentration area connected to the inter-regional interconnection line with the largest deviation is determined as the target control area. For example, if the actual power transmission of an inter-regional interconnection line that transmits western hydropower to the eastern load center is significantly lower than the planned value, it indicates that the power generation capacity or reservoir scheduling of the western hydropower-rich area has not been realized as planned. This hydropower-rich area is then identified as a key control area that requires focused regulation to correct the long-term power balance deviation.

[0051] When the determined scheduling timescale is the second scheduling timescale, power flow data and load rates for each key transmission section are obtained from the current operating status. These load rates directly reflect the stress level of the sections. Next, the load rate values ​​of each key transmission section are compared to identify the key transmission section with the highest load rate, and the area containing this key transmission section is designated as the target control area. For example, if the load rate of a key transmission section connecting a renewable energy base to the main grid continuously approaches or exceeds the safety limit, then the renewable energy base or its sending-end grid area is identified as a key control area. Priority should be given to adjusting the output of resources within this area to prevent the section from exceeding its limits and to ensure that the grid does not become unstable under single-component failure conditions.

[0052] When the determined scheduling timescale is the third scheduling timescale, system frequency deviation, voltage deviation, and power fluctuation data are obtained from the current operating status. Voltage deviation at each key bus node, system frequency deviation in each load-concentrated area, and local net load power fluctuation data are obtained separately. Then, it is determined whether the system frequency deviation exceeds a preset frequency threshold, whether the voltage deviation exceeds a preset voltage threshold, and whether the power fluctuation exceeds a preset power threshold. Load-concentrated areas or renewable energy-concentrated areas that meet any of the following conditions are identified as target control areas: load-concentrated areas where the system frequency deviation exceeds a preset frequency threshold, load-concentrated areas where the voltage deviation exceeds a preset voltage threshold, or load-concentrated areas or renewable energy-concentrated areas where the power fluctuation exceeds a preset power threshold. For example, if a high-power equipment switching in an industrial load-concentrated area causes a sudden drop in frequency, that area is identified as a critical control area; if a large photovoltaic power station experiences severe power output fluctuations due to cloud movement, the area where the photovoltaic power station is located is identified as a critical control area.

[0053] Step S40: Based on the scheduling time scale and the target control area, select a target scheduling rule library from multiple preset scheduling rule libraries, and generate scheduling instructions based on the target scheduling rule library.

[0054] It should be noted that the aforementioned pre-set dispatch rule bases refer to sets of constraint rules pre-stored in the power dispatch system, designed for different dispatch time scales, including a first dispatch rule base, a second dispatch rule base, and a third dispatch rule base. The first dispatch rule base corresponds to the first dispatch time scale (long-cycle dispatch), including constraints on water storage and release from hydropower reservoirs and planned power generation constraints for inter-regional interconnection lines, coupled with flood control constraints and ecological flow constraints. The second dispatch rule base corresponds to the second dispatch time scale (medium- and short-term dispatch), including power balance constraints for each region and contingency safety verification constraints, and embedding daily cycle charging and discharging constraints for multi-energy storage. The third dispatch rule base corresponds to the third dispatch time scale (real-time dispatch), including power fluctuation smoothing constraints, transmission section limit constraints, and voltage safety domain constraints, and incorporating constraints on the rapid regulation capabilities of electrochemical energy storage and hydropower units.

[0055] The operational boundary propagation relationships of the aforementioned scheduling rule bases are as follows: The operational boundary of the second scheduling rule base is determined by the first scheduling rule base, specifically consisting of the planned values ​​of adjustable hydropower generation and inter-regional tie-line transmission power output after optimization of the first scheduling rule base. The operational framework of the third scheduling rule base is determined by the second scheduling rule base, specifically consisting of the multi-element energy storage benchmark charge / discharge plan, the state-of-charge benchmark curve, and the power flow plan values ​​of key transmission sections output after optimization of the second scheduling rule base. The aforementioned operational boundary can refer to the set of upper and lower limit parameters restricting the range of feasible solutions in the second scheduling rule base. The aforementioned operational framework can refer to the set of reference values ​​providing the benchmark operating point for the third scheduling rule base.

[0056] The aforementioned dispatch instructions can refer to specific commands generated by the power dispatch system to control the operation of energy storage devices, including parameters such as the charging and discharging power value, operating period, and target value of the energy storage device's state of charge.

[0057] In practice, based on the determined scheduling time scale and the determined target control area, a target scheduling rule library is selected from multiple preset scheduling rule libraries, and scheduling instructions are generated based on the target scheduling rule library.

[0058] Step 1: Select the target scheduling rule base; Based on the scheduling time scale, the corresponding scheduling rule library is selected from the first scheduling rule library, the second scheduling rule library, and the third scheduling rule library as the target scheduling rule library.

[0059] When the determined scheduling timescale is the first scheduling timescale, the first scheduling rule base is selected as the target scheduling rule base. The first scheduling rule base is specifically designed for the long-cycle scheduling phase with energy transfer and resource pre-allocation as the core tasks. Its constraints are used to ensure that reservoir hydropower resources can be used safely, economically, and sustainably in long-term scheduling spanning months and quarters, while ensuring the smooth execution of inter-provincial and inter-regional power trading contracts.

[0060] When the determined scheduling timescale is the second scheduling timescale, the second scheduling rule base is selected as the target scheduling rule base. The operating boundary of the second scheduling rule base is determined by the planned values ​​of adjustable hydropower generation and inter-regional tie-line transmission power output from the first scheduling rule base. These planned values ​​serve as boundary conditions, ensuring the consistency between short- and medium-term scheduling schemes and long-term power balance strategies. The second scheduling rule base is specifically designed for the short- and medium-term scheduling phase, with the core tasks of ensuring real-time intraday power balance and grid operation safety.

[0061] When the determined scheduling timescale is the third scheduling timescale, the third scheduling rule base is selected as the target scheduling rule base. The operational framework of the third scheduling rule base is determined by the multi-element energy storage benchmark charge and discharge plan and state of charge benchmark curve output from the second scheduling rule base, as well as the power flow plan values ​​of key transmission sections. These plan values ​​constitute the benchmark operating points for real-time scheduling. The third scheduling rule base is specifically designed for the real-time scheduling phase, with the core task of responding to transient disturbances and maintaining the stable operation of the power grid at the second to minute level.

[0062] Step 2: Generate scheduling instructions based on the target scheduling rule base; Based on the selected target scheduling rule base, scheduling instructions are generated for energy storage devices within the target control area.

[0063] If the selected target scheduling rule base is the first scheduling rule base, scheduling instructions are generated based on the first scheduling rule base. The first scheduling rule base includes constraints on the water storage and release volume of hydropower reservoirs and the planned power generation constraints of inter-regional connecting lines, and couples flood control constraints with ecological flow constraints. Based on reservoir water level data, planned power generation data of inter-regional connecting lines, downstream discharge flow data required for flood control scheduling, and downstream discharge flow data required for downstream ecological flow, scheduling instructions for hydropower reservoirs and inter-regional connecting lines are generated.

[0064] If the selected target scheduling rule base is the second scheduling rule base, scheduling instructions are generated based on the second scheduling rule base. The second scheduling rule base includes power balance constraints for each zone, safety verification constraints for anticipated faults, and daily cycle charge and discharge constraints for multi-energy storage. Based on the real-time power of the source-load-storage system within each control zone, the safety verification parameters of the anticipated fault set, and the state of charge data of the energy storage devices, scheduling instructions are generated for pumped storage power stations and electrochemical energy storage power stations.

[0065] If the selected target scheduling rule base is the third scheduling rule base, scheduling instructions are generated based on the third scheduling rule base. The third scheduling rule base includes power fluctuation smoothing constraints, transmission section limit constraints, voltage safety domain constraints, and rapid adjustment capability constraints. Based on net load power fluctuation data, real-time power flow data of key transmission sections, voltage data of each key node, and response rate data of electrochemical energy storage and hydropower units, real-time scheduling instructions for electrochemical energy storage power stations and hydropower units are generated.

[0066] Step S50: Send the scheduling instruction to the corresponding energy storage device within the target control area, so that the energy storage device adjusts its charging and discharging power according to the scheduling instruction.

[0067] It should be noted that the aforementioned energy storage devices can refer to a collection of energy storage resources located within the target control area, communicating with and controlled by the power dispatch system, including hydropower reservoirs, pumped storage power stations, electrochemical energy storage power stations, and fast-regulating hydropower units. The connection between the aforementioned energy storage devices and the power dispatch system can be a real-time two-way communication link established through the dispatch automation system and the data communication network.

[0068] The aforementioned adjustment of charging and discharging power refers to the energy storage device changing its charging or discharging power value according to the received dispatch instructions. For electrochemical energy storage power stations and pumped storage power stations, the aforementioned adjustment of charging and discharging power includes four operating modes: increasing discharging power, decreasing discharging power, increasing charging power, or decreasing charging power. For hydropower reservoirs, the aforementioned adjustment of charging and discharging power includes increasing power generation output (increasing downstream flow) or decreasing power generation output (decreasing downstream flow). The purpose of the aforementioned adjustment of charging and discharging power is to change the distribution of active power within the target control area, thereby smoothing power fluctuations, alleviating section congestion, or restoring system frequency and voltage to normal ranges.

[0069] In practice, the generated scheduling instructions are sent to the corresponding energy storage devices within the target control area, enabling the devices to adjust their charging and discharging power according to the instructions. Through its scheduling automation system and data communication network, the final generated scheduling instructions are accurately distributed to each corresponding energy storage device. These scheduling instructions contain quantified control parameters, specifically including: the planned charging and discharging power curve of the energy storage device, the planned operating period, the target value of the state of charge, the target water level control, and the setpoint for power generation. The content of the scheduling instructions received by different energy storage devices varies. For hydropower reservoirs located within the target control area, the planned power generation curve or the reservoir water level control target for the future period is sent to them. After receiving the instructions, the hydropower reservoir adjusts the reservoir's outflow through its local control system, thereby changing its power output. For pumped storage power stations located within the target control area, time-segmented charging and discharging power instructions and target state of charge are sent to them. After receiving the instructions, the pumped storage power station executes pumping (charging) or power generation (discharging) operations through its local control system. For electrochemical energy storage power stations located within the target control area, time-segmented charging and discharging power commands and target state of charge are issued to them. Upon receiving the commands, the electrochemical energy storage power station controls its energy storage converter to perform charging or discharging operations through its local control system. For fast-regulating hydropower units located within the target control area, real-time power setpoints for participation in automatic generation control or frequency regulation services are issued to them. Upon receiving the commands, the fast-regulating hydropower units quickly adjust their output to track the power setpoints through their local control systems. After receiving dispatch commands, the aforementioned energy storage devices execute corresponding power generation, pumping, charging / discharging, or regulation operations through their local control systems, thereby translating the optimization decisions of the power dispatch system into adjustments to the actual operating status of the power grid. Specifically, after the energy storage device adjusts its charging and discharging power according to the dispatch instructions, the active power distribution within the target control area changes. Specifically: if the energy storage device increases its discharging power, the power supply within the area increases, helping to alleviate power shortages or support frequency; if the energy storage device increases its charging power, the power consumption within the area increases, helping to absorb excess renewable energy generation or alleviate excessive voltage; if the energy storage device reduces its discharging or charging power, the opposite adjustment effect occurs. Through these adjustments, the power flow at key transmission sections within the target control area is alleviated (load rate decreases), system frequency and voltage deviations are corrected (approaching rated values), and power fluctuations are smoothed (net load fluctuation amplitude decreases), thereby achieving power balance and safe, stable operation of the power grid.

[0070] This embodiment first obtains the current operating state of the power grid. Then, it determines the current scheduling timescale of the power grid based on the current operating state. Next, based on the scheduling timescale and the current operating state, it identifies the target control area from the power grid. Then, based on the scheduling timescale and the target control area, it selects a target scheduling rule library from multiple preset scheduling rule libraries and generates scheduling instructions based on the target scheduling rule library. Finally, it sends the scheduling instructions to the corresponding energy storage devices within the target control area, so that the energy storage devices adjust their charging and discharging power according to the scheduling instructions. Compared with existing methods, this embodiment achieves precise adaptation between diversified energy storage and the real-time state of the power grid by dynamically identifying the scheduling timescale and target control area of ​​the power grid and matching the corresponding scheduling rule library.

[0071] Based on the first embodiment of this application, a second embodiment of this application is proposed. In the second embodiment, content that is the same as or similar to that in the first embodiment described above can be referred to the above description, and will not be repeated hereafter. Based on this, please refer to... Figure 2 , Figure 2 This is a flowchart illustrating a second embodiment of a power grid dispatching method according to this application.

[0072] In this embodiment, the scheduling time scale includes a first scheduling time scale, a second scheduling time scale, and a third scheduling time scale. The step of determining the current scheduling time scale of the power grid based on the current operating state includes: Step S201: Obtain the preset scheduling calendar and the time information in the current running state.

[0073] Step S202: Determine the planning stage type at the current moment based on the preset scheduling calendar and the time information.

[0074] It should be noted that the aforementioned preset dispatch calendar refers to a fixed schedule pre-established by the power dispatching agency, which specifies the start, end, and rolling update times of various periodic dispatch plans. Specifically, the preset dispatch calendar defines the time windows for the annual planning phase, monthly planning phase, day-ahead planning phase, and real-time planning phase. For example, the annual planning phase is typically set in a specific period of the fourth quarter of each year (e.g., November 1st to December 31st) for developing the next year's power generation plan and reservoir dispatch plan; the monthly planning phase is typically set in a specific period in the latter half of each month (e.g., the 20th to the 25th) for developing the next month's power generation plan, tie-line plan, and reservoir operation plan; the day-ahead planning phase is typically set in a specific period each day (e.g., 10:00 AM to 4:00 PM) for developing the power generation output, load balance, and network security plan for the next 24 hours; and the real-time planning phase is typically set with a rolling execution cycle of every 5 minutes or 15 minutes for rolling adjustments to power generation output, frequency, and voltage for the next few minutes based on ultra-short-term forecasts.

[0075] The aforementioned time information can refer to the standard timestamp corresponding to the current operating status collected by the power dispatching system, including the current year, month, day, hour, minute, and second. The aforementioned planning stage type can refer to the classification result of the dispatching business cycle to which the current moment belongs based on the preset dispatching calendar and the current time information, specifically including four types: annual planning stage, monthly planning stage, day-ahead planning stage, and real-time planning stage.

[0076] The correspondence between the above planning phase types and scheduling tasks is as follows: the annual planning phase and the monthly planning phase correspond to long-cycle scheduling tasks, the core of which is to carry out cross-seasonal and cross-month energy transfer and resource pre-allocation; the day-ahead planning phase corresponds to medium- and short-term scheduling tasks, the core of which is to ensure the real-time balance of power supply and demand at the minute to hour level within the next day while taking into account grid security; the real-time planning phase corresponds to real-time scheduling tasks, the core of which is to deal with instantaneous power fluctuations and maintain the real-time stable operation of the grid.

[0077] In the specific implementation, the system first acquires the preset scheduling calendar and the time information from the current operating status. The preset scheduling calendar is read from the internal memory. This preset scheduling calendar is a fixed timetable pre-established by the power dispatching agency according to the power system operation management regulations, specifying the start and end times and rolling update times for various periodic scheduling plans. For example, the preset scheduling calendar records the start and end dates of the annual planning phase (e.g., November 1st to December 31st each year), the start and end dates of the monthly planning phase (e.g., the 20th to the 25th of each month), the daily start and end times of the day-ahead planning phase (e.g., 10:00 AM to 4:00 PM daily), and the rolling cycle of the real-time planning phase (e.g., every 5 minutes or every 15 minutes). Simultaneously, the time information is extracted from the acquired current operating status. This time information is a standard timestamp recorded by the data acquisition and monitoring system when collecting power grid operation data, including the current year, month, day, hour, minute, and second. Next, based on the preset scheduling calendar and the time information, the type of planning phase the current moment falls into is determined. The current moment in the time information is compared one by one with the time windows of each planning phase defined in the preset scheduling calendar.

[0078] If the current time falls within the annual planning phase time window or the monthly planning phase time window defined in the preset scheduling calendar, the planning phase type will be determined as either an annual planning phase or a monthly planning phase. Both the annual planning phase and the monthly planning phase belong to the category of long-cycle scheduling. The only difference between the two is in the planning time range (annual planning covers the next 12 months, and monthly planning covers the next 1 month), but they both correspond to the first scheduling time scale in terms of scheduling time scale classification.

[0079] If the current time falls within the day-ahead planning phase time window defined in the preset scheduling calendar, then the planning phase type is determined to be the day-ahead planning phase. The day-ahead planning phase corresponds to the second scheduling time scale.

[0080] If the current time falls within the real-time planning phase time window defined in the preset scheduling calendar, then the planning phase type is determined to be the real-time planning phase. The real-time planning phase corresponds to the third scheduling time scale.

[0081] Once the planning phase type is determined, it will be used as the basis for subsequent scheduling time scale judgments.

[0082] Step S203: If the planning stage type is an annual planning stage or a monthly planning stage, then the scheduling time scale is determined as the first scheduling time scale.

[0083] Step S204: If the planning phase type is the day-ahead planning phase, then the scheduling time scale is determined as the second scheduling time scale.

[0084] Step S205: If the planning phase type is a real-time planning phase, then the scheduling time scale is determined as the third scheduling time scale.

[0085] It should be noted that there is a fixed mapping relationship between the first, second, and third scheduling time scales and the overall scheduling time scale. The first scheduling time scale corresponds to a long-term scheduling time scale and is used to handle scheduling tasks during the annual or monthly planning phases. Its core function is to perform cross-seasonal and cross-month energy transfer and resource pre-allocation. The second scheduling time scale corresponds to a medium-to-short-term scheduling time scale and is used to handle scheduling tasks during the day-ahead planning phase. Its core function is to ensure real-time balance of power supply and demand within the next day, ranging from minutes to hours, while also considering grid security. The third scheduling time scale corresponds to a real-time scheduling time scale and is used to handle scheduling tasks during the real-time planning phase. Its core function is to respond to instantaneous power fluctuations and maintain the real-time stable operation of the grid.

[0086] In the specific implementation, the scheduling timescale is determined as the corresponding scheduling rule base based on the determined planning phase type. Specifically, the following judgment logic is executed: First, the handling of the annual or monthly planning phase.

[0087] If the planning phase type determined in the previous step is an annual planning phase or a monthly planning phase, then the scheduling time scale is determined as the first scheduling time scale.

[0088] The annual planning phase refers to the stage conducted at a specific time each year, which involves comprehensive and strategic arrangements for power generation and consumption, as well as reservoir water storage and release, for the entire year ahead. The monthly planning phase refers to the stage conducted monthly, which involves detailed arrangements for the following month's power generation plan, interconnection line plan, and reservoir operation plan. The common characteristics of both the annual and monthly planning phases are: long planning timeframes (monthly and longer), decision variables primarily based on total energy (such as reservoir water storage and release, and total electricity generation from inter-regional interconnection lines), and constraints primarily focused on long-term resource balance (such as annual reservoir inflow forecasts and annual inter-regional trading contracts).

[0089] After determining the first scheduling time scale, subsequent scheduling instructions will be generated using constraints from the first scheduling rule base (including constraints on water storage and release from hydropower reservoirs, planned power generation from inter-regional connecting lines, flood control constraints, and ecological flow constraints). The planned values ​​of adjustable hydropower generation and inter-regional connecting line transmission power output after optimization of the first scheduling rule base will serve as the operating boundaries of the second scheduling rule base.

[0090] Second, the handling of the current planning phase.

[0091] If the planning phase type determined in the previous step is the day-ahead planning phase, then the scheduling time scale is determined as the second scheduling time scale.

[0092] The day-ahead planning phase refers to the daily phase in which precise arrangements are made for power generation output, load balance, and network security every 15 minutes or 1 hour for the next 24 hours to several days. The characteristics of the day-ahead planning phase are that the planning time range is for the next 24 hours to several days, the decision variables are mainly hourly or 15-minute power, and the constraint types are mainly intraday power balance and network security (such as power balance in each time period, transmission capacity limits of critical sections, and daily cycle constraints of energy storage).

[0093] After determining the second scheduling time scale, subsequent scheduling instructions will be generated using constraints from the second scheduling rule base (including power balance constraints for each region, contingency safety verification constraints, and daily cyclic charging and discharging constraints for multi-electrode energy storage). The operating boundary of the second scheduling rule base is determined by the first scheduling rule base. The multi-electrode energy storage baseline charging and discharging plan and state-of-charge baseline curve, as well as the power flow plan values ​​for key transmission sections, output after optimization of the second scheduling rule base, will serve as the operating framework for the third scheduling rule base.

[0094] Third, the handling of the real-time planning phase.

[0095] If the planning phase type determined in the previous step is the real-time planning phase, then the scheduling time scale is determined as the third scheduling time scale.

[0096] The real-time planning phase refers to the stage of rolling adjustments and closed-loop control of power generation output, frequency, and voltage from the next few minutes to the present moment, based on the day-ahead plan and ultra-short-term forecasts. The characteristics of the real-time planning phase are: the planning time range is from the next few minutes to the present moment; the decision variables are mainly power adjustments at the second or minute level; and the constraint types are mainly instantaneous stability constraints (such as frequency response, voltage support, and ramp rate limits).

[0097] Once the third scheduling timescale is determined, subsequent scheduling instructions will be generated using constraints from the third scheduling rule base (including power fluctuation smoothing constraints, transmission section limit constraints, voltage safety domain constraints, and rapid regulation capability constraints for electrochemical energy storage and hydropower units). The operational framework of the third scheduling rule base is determined by the second scheduling rule base.

[0098] After determining the scheduling time scale, the scheduling time scale (i.e., the first scheduling rule base, the second scheduling rule base, or the third scheduling rule base) will be used as the basis for selecting the target scheduling rule base and generating scheduling instructions.

[0099] Furthermore, in this embodiment, the step of determining the target control area from the power grid based on the scheduling time scale and the current operating state includes at least one of the following: Step S301: When the scheduling time scale is the first scheduling time scale, obtain the deviation data between the planned power generation and the actual power generation of the inter-regional tie line from the current operating state, and determine the power concentration area connected by the inter-regional tie line with the largest deviation in the deviation data as the target control area.

[0100] It should be noted that the above deviation data may refer to the difference between the planned power volume and the actual power volume transmitted by the inter-regional connecting line.

[0101] The aforementioned planned electricity volume can refer to the total electricity transmission target that must be completed or is not allowed to be exceeded within a specific period (such as monthly or annually) as determined by medium- and long-term transaction contracts or intergovernmental agreements.

[0102] The aforementioned actual power generation can refer to the cumulative power volume actually transmitted by the inter-regional connection line within a specified period. The formula for calculating the deviation data is: Deviation data = Planned power volume - Actual power generation. The deviation value can be positive (actual transmitted power volume is lower than the planned value) or negative (actual transmitted power volume is higher than the planned value).

[0103] The inter-regional tie line with the largest deviation mentioned above can refer to the inter-regional tie line with the largest absolute value of the deviation data or the largest deviation value (depending on the actual dispatching requirements) among all inter-regional tie lines. In long-cycle dispatching scenarios, the focus is usually on the situation where the actual transmitted power is lower than the planned value (i.e., insufficient power supply capacity). Therefore, the inter-regional tie line with the largest deviation value can be identified as the inter-regional tie line with the largest deviation.

[0104] The aforementioned concentrated power generation area can refer to the geographical area on the power generation side connected by the inter-regional interconnection line with the largest deviation, typically an area where one or more power plants (such as hydropower stations, thermal power bases, or new energy bases) are clustered. This area is the source of the largest discrepancy between the inter-regional power balance plan and the actual situation, and is therefore identified as a target control area to correct long-term power balance deviations.

[0105] In practical implementation, when the determined scheduling timescale is the first scheduling timescale (corresponding to long-cycle scheduling, i.e., the annual planning stage or the monthly planning stage), the deviation data between the planned power generation and the actual power generation of the inter-regional interconnection lines are obtained from the current operating status. The power concentration area connected to the inter-regional interconnection line with the largest deviation in the deviation data is determined as the target control area. First, relevant information of all inter-regional interconnection lines is extracted from the current operating status. The current operating status includes the planned power generation data (from medium- and long-term transaction contracts or intergovernmental agreements) and the actual power generation data (from the cumulative readings of the power metering system) for each inter-regional interconnection line. Next, for each inter-regional interconnection line, the deviation data between the planned power generation and the actual power generation is calculated. The formula for calculating the deviation data is: Deviation data = Planned power generation - Actual power generation. If the planned power generation is greater than the actual power generation, the deviation data is positive, indicating that the actual transmitted power generation is lower than the planned target, i.e., insufficient power supply capacity; if the planned power generation is less than the actual power generation, the deviation data is negative, indicating that the actual transmitted power generation exceeds the planned target, i.e., over-transmission. The deviation data of all inter-regional interconnection lines are sorted to identify the one with the largest deviation value. In long-cycle dispatching scenarios, the core contradiction in power grid operation lies in the energy planning and allocation across regions and seasons. Typically, the interconnection line with the largest deviation reflects the most severe energy imbalance problem. Next, the power source connection information of the inter-regional interconnection line with the largest deviation is obtained to determine the concentrated power source area connected to this interconnection line. This concentrated power source area can be a river basin area where a hydropower station group is located, a mining area where a thermal power base is located, or a resource-rich area where a new energy base is located. This area is the source of the largest discrepancy between the planned and actual inter-regional power balance. Finally, this concentrated power source area is determined as the target control area. After determining the target control area, key regulation will be implemented in this area. Regulation measures may include: adjusting the water storage and release plan of hydropower reservoirs in the area (increasing or decreasing power generation), adjusting the power generation plan of thermal power units in the area, or adjusting the output forecasting and dispatching strategy of new energy sources in the area, to correct long-term power balance deviations and gradually bring the actual power transmission of the inter-regional interconnection line closer to the planned target.

[0106] Step S302: When the scheduling time scale is the second scheduling time scale, obtain the load rate of the key transmission section from the current operating state, and determine the area where the key transmission section with the highest load rate is located as the target control area.

[0107] It should be noted that the aforementioned key transmission sections can refer to a set of transmission channels consisting of multiple transmission lines that play a decisive role in the stable operation of the power grid.

[0108] The aforementioned key transmission sections are usually the bottleneck links in power transmission connecting different power supply areas and load areas, and their transmission capacity limits the power exchange capacity between regions.

[0109] The load factor mentioned above can refer to the ratio of the actual transmission power to the stable operating limit power of a critical transmission section. The formula for calculating the load factor is: Load Factor = (Actual Transmission Power / Stable Operating Limit Power) × 100%.

[0110] The aforementioned load factor directly reflects the stress level of the cross section. The higher the load factor, the closer the cross section is to the transmission limit, and the greater the risk of transmission congestion or over-limit faults.

[0111] The critical transmission section with the highest load factor mentioned above refers to the section with the largest load factor among all critical transmission sections. The area where the critical transmission section with the highest load factor is located is the weakest link in the power grid and the most prone to transmission congestion, and is therefore identified as the target control area. Priority should be given to adjusting the output of resources in this area to prevent the section from exceeding its limits and to ensure that the power grid does not become unstable under the condition of a single component failure.

[0112] In practical implementation, when the determined scheduling timescale is the second scheduling timescale (corresponding to short-to-medium-term scheduling, i.e., the day-ahead planning stage), the load rate of key transmission sections is obtained from the current operating status, and the area where the key transmission section with the highest load rate is located is determined as the target control area. Under the second scheduling timescale, the core contradiction of power grid operation shifts to intraday real-time power balance and network security. It is necessary to identify the weakest links in power grid security and the most prone to transmission congestion in order to prioritize regulation. First, relevant information of all key transmission sections is extracted from the current operating status. The current operating status includes the real-time transmission power data of each key transmission section (from power measurement devices on the transmission lines) and the pre-stored stable operating limit power value (calculated by power system stability analysis). Next, for each key transmission section, its load rate is calculated. The actual transmission power of each key transmission section is divided by the stable operating limit power of that section, and then multiplied by 100% to obtain the load rate percentage value of that section. The load rates of all key transmission sections are sorted, and the key transmission section with the highest load rate value is identified. The transmission section with the highest load factor means its actual transmission power is closest to its stable operating limit, with the smallest safety margin, making it the weakest link in the power grid. Next, the geographical location information of this critical transmission section with the highest load factor is obtained to determine the region where the section is located. This region can refer to the sending-end region (power source side region), the receiving-end region (load side region), or the geographical area spanned by the section. This region is the weakest link in power grid security, requiring priority adjustment of resource output within the region. Finally, the region where the critical transmission section with the highest load factor is located is determined as the target control area. After determining the target control area, key regulation will be implemented in this area. Regulation measures may include: reducing the power output of the region's power sources (reducing sending-end power), increasing the charging power of energy storage in the region (absorbing excess power), adjusting the power consumption plan of the load in the region (demand-side response), or increasing the local power generation output of the receiving-end region to reduce the load factor of the critical transmission section and prevent the section from exceeding its limits.

[0113] Step S303: When the scheduling time scale is the third scheduling time scale, obtain system frequency deviation, voltage deviation and power fluctuation data from the current operating state, and determine the load concentration area where the system frequency deviation exceeds the preset frequency threshold, the load concentration area where the voltage deviation exceeds the preset voltage threshold, or the load concentration area where the power fluctuation exceeds the preset power threshold as the target control area.

[0114] It should be noted that the aforementioned system frequency deviation refers to the difference between the actual frequency of the power grid and the rated frequency (usually 50 Hz or 60 Hz). The calculation formula is: System frequency deviation = Actual frequency - Rated frequency. The sign of the system frequency deviation reflects the supply and demand relationship of active power in the power grid: a positive frequency deviation indicates that the power generation is greater than the load demand, and a negative frequency deviation indicates that the power generation is less than the load demand.

[0115] The voltage deviation mentioned above refers to the difference between the actual voltage amplitude and the rated voltage at a critical busbar node. It is usually expressed as a percentage of the rated voltage, and the calculation formula is: Voltage Deviation = (Actual Voltage - Rated Voltage) / Rated Voltage × 100%. The voltage deviation reflects the reactive power balance in a local area.

[0116] The aforementioned power fluctuation data can refer to the rate or magnitude of change of net load power over time within a local area. The aforementioned net load can refer to the remaining power value after subtracting the power generated by new energy sources from the load power. The aforementioned power fluctuation data can include the rate of change of power (such as the change in megawatts per minute) or the magnitude of change of power per unit time (such as the difference between the maximum and minimum power changes within 5 minutes).

[0117] The aforementioned preset frequency threshold, preset voltage threshold, and preset power threshold are safety boundary values ​​pre-set based on power grid safe operation procedures, equipment capacity, and stability analysis. For example, the preset frequency threshold can be set to ±0.1 Hz (i.e., the allowable frequency fluctuation range is 49.9 Hz to 50.1 Hz); the preset voltage threshold can be set to ±5% (i.e., the allowable voltage fluctuation range is 95% to 105% of the rated voltage); and the preset power threshold can be set to 50 MW per minute (i.e., the maximum allowable net load change rate).

[0118] The aforementioned concentrated load areas refer to geographical areas with relatively dense power loads, typically power supply areas centered around cities, industrial parks, or important power-consuming units. These concentrated load areas are the main sources of disturbance or weak points that cause or exacerbate real-time instability in the power grid. For example, the switching of high-power equipment in industrial load-concentrated areas may cause a sudden drop in frequency, and large photovoltaic power plants may experience severe fluctuations in output due to cloud movement.

[0119] In practical implementation, when the determined scheduling timescale is the third scheduling timescale (corresponding to real-time scheduling, i.e., the real-time planning stage), system frequency deviation, voltage deviation, and power fluctuation data are obtained from the current operating state. Load concentration areas where the system frequency deviation exceeds a preset frequency threshold, the voltage deviation exceeds a preset voltage threshold, or the power fluctuation exceeds a preset power threshold are identified as target control areas. At the third scheduling timescale, the core challenge of power grid operation lies in suppressing instantaneous fluctuations and maintaining system frequency and voltage stability. It is necessary to identify the main sources of disturbance or weak points that cause or exacerbate real-time instability in the power grid so that rapid adjustment resources can be mobilized immediately for mitigation. First, system frequency deviation data is extracted from the current operating state. This system frequency deviation data comes from the frequency measurement device of the power dispatching system, typically sampled multiple times per second. The absolute value of the obtained system frequency deviation is compared with the preset frequency threshold. If the absolute value of the system frequency deviation exceeds the preset frequency threshold, it indicates a risk of frequency instability in the power grid, and the load concentration areas causing the frequency deviation need to be identified. Simultaneously, voltage deviation data for each key bus node is extracted from the current operating state. The voltage deviation data mentioned above comes from voltage transformer measurements at each substation. The absolute value of the voltage deviation at each node is compared with a preset voltage threshold. If the absolute value of the voltage deviation at a node exceeds the preset voltage threshold, it indicates that there is a risk of voltage instability in the area where that node is located, and this load concentration area needs to be monitored. Simultaneously, power fluctuation data for each area is extracted from the current operating status. This power fluctuation data can be obtained by differentiating the net load power, i.e., calculating the power change rate per unit time. The obtained power fluctuation data (such as the power change rate) for each area is compared with a preset power threshold. If the power fluctuation in a certain area exceeds the preset power threshold, it indicates that there is a severe power disturbance in that area, and it needs to be identified as a target control area. Next, load concentration areas that meet any of the following conditions are identified as target control areas: load concentration areas where the system frequency deviation exceeds a preset frequency threshold (i.e., the area where the main disturbance source causing the frequency deviation is located), load concentration areas where the voltage deviation exceeds a preset voltage threshold (i.e., the area where the weak node causing the voltage overshoot is located), or load concentration areas where the power fluctuation exceeds a preset power threshold (i.e., the area where the disturbance source causing severe power fluctuation is located). The aforementioned target control area may simultaneously encompass multiple areas (for example, areas where frequency deviation exceeds the threshold, voltage deviation exceeds the threshold, and power fluctuation exceeds the threshold may be different areas). All areas that meet the conditions will be designated as the target control area. Once the target control area is determined, rapid regulation resources within the target control area (such as electrochemical energy storage and rapid regulation hydropower units) will be immediately mobilized to mitigate the impact and restore system stability.

[0120] Based on the first and second embodiments of this application, a third embodiment of this application is proposed. In this third embodiment, content that is the same as or similar to the first and second embodiments described above can be referred to the above description, and will not be repeated hereafter. Based on this, please refer to... Figure 3 , Figure 3 This is a flowchart illustrating a third embodiment of a power grid dispatching method according to this application.

[0121] In this embodiment, the step of selecting a target scheduling rule base from multiple preset scheduling rule bases includes: Step S401: When the scheduling time scale is the first scheduling time scale, select the first scheduling rule base as the target scheduling rule base.

[0122] Step S402: When the scheduling time scale is the second scheduling time scale, the second scheduling rule base is selected as the target scheduling rule base, wherein the operating boundary of the second scheduling rule base is determined by the planned value of adjustable hydropower generation and the planned value of cross-regional tie line transmission power output by the first scheduling rule base.

[0123] Step S403: When the scheduling time scale is the third scheduling time scale, the third scheduling rule base is selected as the target scheduling rule base, wherein the operating framework of the third scheduling rule base is determined by the energy storage benchmark charging and discharging plan and the power flow plan value of the key transmission section output by the second scheduling rule base.

[0124] It should be noted that the first, second, and third dispatch rule bases mentioned above are hierarchically related. The operating boundary of the second dispatch rule base is determined by the planned values ​​of adjustable hydropower generation and inter-regional tie line transmission power output from the first dispatch rule base. The operating framework of the third dispatch rule base is determined by the multi-element energy storage benchmark charge and discharge plan and state of charge benchmark curve, as well as the power flow plan values ​​of key transmission sections output from the second dispatch rule base.

[0125] The aforementioned planned value of adjustable hydropower generation can refer to the active power generation value of the hydropower station within a specific period (such as monthly or annually), which is output after optimization and solution by the first scheduling rule base.

[0126] The above-mentioned planned values ​​for adjustable hydropower generation reflect the energy allocation results of hydropower resources in long-term scheduling, including the planned power generation of each hydropower station and the planned water storage and release of each reservoir.

[0127] The aforementioned planned power value for inter-regional tie lines can refer to the planned power value of the inter-regional tie line within a specific period, or the power value converted from the planned power transmission, output by the optimized solution of the first scheduling rule base.

[0128] The aforementioned operational boundaries refer to the set of upper and lower limits of parameters that restrict the range of feasible solutions in the second scheduling rule base. These operational boundaries consist of the planned adjustable hydropower generation output from the first scheduling rule base and the planned power transmission of inter-regional tie lines. Specifically, when performing short- to medium-term scheduling optimization, the maximum adjustable hydropower generation cannot exceed the planned adjustable hydropower generation output from the first scheduling rule base, and the power transmission of inter-regional tie lines cannot exceed the planned power transmission of inter-regional tie lines output from the first scheduling rule base. These operational boundaries ensure the consistency between short- to medium-term scheduling schemes and long-term power balance strategies.

[0129] The aforementioned energy storage baseline charge and discharge plan can refer to the baseline charge and discharge power curves and baseline state of charge curves of each energy storage device (including pumped storage power stations and electrochemical energy storage power stations) at each time period of the day, output after optimization and solution by the second dispatch rule base. The aforementioned key transmission section power flow plan values ​​can refer to the planned transmission power values ​​of each key transmission section at each time period of the day, output after optimization and solution by the second dispatch rule base.

[0130] The aforementioned operational framework can refer to a set of reference values ​​that provide baseline operating points for the third scheduling rule base. This framework consists of the energy storage baseline charge / discharge plan output by the second scheduling rule base and the power flow plan values ​​for key transmission sections. Specifically, when performing real-time scheduling, the third scheduling rule base uses the energy storage baseline charge / discharge plan output by the second scheduling rule base as the baseline reference point for the charge / discharge power of the energy storage equipment, and the power flow plan values ​​for key transmission sections output by the second scheduling rule base as the baseline reference point for the power flow of the sections. Based on these, small-scale real-time adjustments are made to address instantaneous fluctuations.

[0131] In the specific implementation, based on the determined scheduling time scale, the corresponding scheduling rule library is selected from multiple preset scheduling rule libraries as the target scheduling rule library.

[0132] When the determined scheduling timescale is the first scheduling timescale (corresponding to long-cycle scheduling in the annual or monthly planning phase), the first scheduling rule base is selected as the target scheduling rule base. The first scheduling rule base is specifically designed for long-cycle scheduling phases with energy transfer and resource pre-allocation as core tasks. The constraints in the first scheduling rule base (including constraints on hydropower reservoir water storage and release, planned power generation constraints for inter-regional interconnection lines, flood control constraints, and ecological flow constraints) are used for optimization. After optimization, the planned values ​​for adjustable hydropower generation and the planned power transmission of inter-regional interconnection lines are output. These output values ​​not only serve as the results of long-cycle scheduling but also as the operating boundaries of the second scheduling rule base.

[0133] When the determined scheduling timescale is the second scheduling timescale (corresponding to the short-to-medium-term scheduling in the day-ahead planning stage), the second scheduling rule base is selected as the target scheduling rule base. The operating boundary of the second scheduling rule base is determined by the planned value of adjustable hydropower generation and the planned value of inter-regional tie line transmission power output from the first scheduling rule base. The specific determination method is as follows: The planned value of adjustable hydropower generation is extracted from the optimization results of the first scheduling rule base. This planned value of adjustable hydropower generation specifies the upper limit of the total adjustable hydropower generation determined at the long-term scheduling level (for example, the upper limit of adjustable power generation of a certain hydropower station this month is 20,000 MWh per day). This planned value of adjustable hydropower generation is used as the upper limit constraint boundary of hydropower output in the second scheduling rule base. At the same time, the planned value of inter-regional tie line transmission power is extracted from the optimization results of the first scheduling rule base. This planned value of inter-regional tie line transmission power specifies the upper limit of daily transmission power of inter-regional tie lines determined at the long-term scheduling level (for example, the upper limit of daily transmission power of a certain inter-regional tie line is 1,000 MWh). The planned value of the inter-regional tie line transmission power is used as the upper limit constraint boundary for the inter-regional tie line transmission power in the second scheduling rule base. In this way, the range of feasible solutions in the second scheduling rule base is limited to the boundary determined by the output value of the first scheduling rule base, ensuring the consistency between the short- and medium-term scheduling schemes and the long-term power balance strategy.

[0134] When the determined scheduling timescale is the third scheduling timescale (corresponding to real-time scheduling in the real-time planning phase), the third scheduling rule base is selected as the target scheduling rule base. The operational framework of the third scheduling rule base is determined by the energy storage benchmark charge-discharge plan and the power flow plan values ​​of key transmission sections output by the second scheduling rule base. The specific determination method is as follows: The energy storage benchmark charge-discharge plan is extracted from the optimization results of the second scheduling rule base. This energy storage benchmark charge-discharge plan includes the benchmark charge-discharge power curves and benchmark state-of-charge curves of each energy storage device (pumped storage power station and electrochemical energy storage power station) at each time period during the day (for example, the benchmark discharge power of an electrochemical energy storage station at 14:00 is 50 MW, and the benchmark state of charge is 60%). This energy storage benchmark charge-discharge plan is used as the benchmark reference point for the charge-discharge power and state of charge of energy storage devices in the third scheduling rule base. At the same time, the power flow plan values ​​of key transmission sections are extracted from the optimization results of the second scheduling rule base. The planned power flow value for each critical transmission section specifies the planned transmission power value for each critical transmission section at each time period of the day, as determined at the day-ahead dispatch level (e.g., the planned transmission power of a critical transmission section at 2 PM is 800 MW). This planned power flow value for the critical transmission section is used as the benchmark reference point for the power flow of the section in the third dispatch rule base.

[0135] In this way, the third scheduling rule base uses the output value of the second scheduling rule base as the operating framework, and makes small-scale real-time adjustments on this basis to cope with instantaneous fluctuations, thus ensuring the consistency between the real-time scheduling scheme and the medium- and short-term scheduling scheme.

[0136] Furthermore, in this embodiment, the step of generating scheduling instructions based on the target scheduling rule base includes: Step S404: When the target scheduling rule base is the first scheduling rule base, obtain the water level constraint parameters of the hydropower reservoir and the power constraint parameters of the inter-regional connecting line.

[0137] Step S405: Generate the first scheduling instruction based on the water level constraint parameters and the power constraint parameters.

[0138] It should be noted that the aforementioned hydropower reservoirs can refer to the reservoirs of conventional hydropower stations with regulation capabilities. They are a type of multi-energy storage device and belong to the core objects regulated by the first dispatching rule base. These hydropower reservoirs achieve energy transfer over time through water storage and release: storing water (energy storage) when inflow is abundant or load is low, and releasing water to generate electricity (energy release) when inflow is insufficient or load is high. The water level constraint parameters of the aforementioned hydropower reservoirs can refer to a set of parameters used to constrain the operating state of the hydropower reservoir, including the reservoir's capacity-water level curve parameters, the lower limit of the reservoir's operating water level (dead water level), the upper limit of the reservoir's operating water level (normal storage level or flood control limit water level), and the lower and upper limits of the reservoir's power generation flow. These water level constraint parameters are used to ensure the safe, economical, and sustainable operation of hydropower reservoirs in long-term dispatching.

[0139] The aforementioned power constraint parameters for inter-regional power lines refer to a set of parameters used to constrain power exchange between inter-regional power lines. These parameters include the lower and upper limits of the transmission power of the inter-regional power line (determined by the thermal stability limit or stable operation limit of the power line), and the daily or monthly cumulative value of the planned power volume of the power line (determined by medium- and long-term transaction contracts or intergovernmental agreements). These power constraint parameters are used to control the total amount of power exchange between regions, ensuring the smooth execution of inter-provincial and inter-regional power trading contracts.

[0140] The aforementioned first dispatch instruction can refer to a specific control command generated by the power dispatching system for long-cycle dispatching when the target dispatching rule base is the first dispatching rule base. The content of the aforementioned first dispatch instruction may include: the planned power generation curve of the hydropower reservoir, the reservoir water level control target, the planned power transmission target of the inter-regional interconnection line, and the downstream flow control target, etc. The aforementioned first dispatch instruction will be sent to the control execution units of the hydropower reservoir and the inter-regional interconnection line.

[0141] In the specific implementation, when the selected target scheduling rule base is the first scheduling rule base, the water level constraint parameters of the hydropower reservoir and the power constraint parameters of the inter-regional tie line are obtained, and a first scheduling instruction is generated based on the water level constraint parameters and the power constraint parameters. Firstly, determining that the target scheduling rule base is the first scheduling rule base indicates that the current stage is a long-cycle scheduling phase (corresponding to the annual planning phase or monthly planning phase). Next, the water level constraint parameters of the hydropower reservoir are obtained from the current operating status and pre-stored scheduling parameters. These water level constraint parameters include the following: First, obtain the capacity-water level curve parameters for each hydropower reservoir. These capacity-water level curves describe the deterministic functional relationship between reservoir storage capacity and water level, and are the fundamental physical parameters for hydropower scheduling calculations.

[0142] Second, obtain the lower and upper limits of water level operation for each hydropower reservoir. The lower limit of water level operation is determined by the dead water level of the reservoir, which specifies the minimum water level allowed for long-term regulation; the upper limit of water level operation is determined by the normal storage level or flood control limit level of the reservoir, which specifies the maximum water level allowed for long-term regulation.

[0143] Third, obtain the lower and upper limits of the power generation flow of each hydroelectric reservoir. These lower and upper limits are determined by the technical characteristics of the turbines, which limit the power regulation capability of the hydroelectric power station.

[0144] Fourth, for a cascade hydropower station group, hydraulic connection parameters and flow delay parameters between the cascade hydropower stations are also obtained. The hydraulic connection parameters describe the coupling relationship between the discharge flow from the upstream power station and the inflow flow from the downstream power station; the flow delay parameters describe the time required for the flow to propagate from the upstream power station to the downstream power station.

[0145] Simultaneously, the power constraint parameters for the inter-regional tie line are obtained from the current operating status and pre-stored scheduling parameters. These power constraint parameters include the following: First, obtain the lower and upper limits of transmission power for each inter-regional tie line. These lower and upper limits are determined by the thermal stability limit or stable operation limit of the tie line, defining the boundaries of instantaneous transmission capacity.

[0146] Second, obtain the daily or monthly cumulative values ​​of the planned electricity volume for each inter-regional interconnection line. These planned electricity volumes are determined by medium- and long-term transaction contracts or intergovernmental agreements, specifying the total transmission volume targets that must be met or are not permitted to be exceeded within a specific period.

[0147] In addition, the system obtains downstream discharge constraint parameters for flood control scheduling (to ensure flood season safety) and downstream ecological flow requirements (to maintain the basic ecological functions of the downstream river channel). Then, based on the obtained water level and power generation constraint parameters, combined with inflow forecast data, load forecast data, and medium- and long-term trading contracts, a long-term optimization solution is performed. The goal of this optimization solution is to minimize power generation costs, minimize water wastage, or maximize overall benefits while satisfying the water level and power generation constraint parameters. Based on the optimization solution results, a first scheduling instruction is generated. This first scheduling instruction includes the following: First, the dispatch instructions for each hydropower reservoir: the planned power generation curve for the next month or year (usually in daily or monthly units), the water level control target for each reservoir (such as the target water level at the end of the month or year), and the planned outflow curve for each reservoir.

[0148] Second, the dispatch instructions for each inter-regional connection line: the planned power transmission target (daily cumulative value or monthly cumulative value) for the next month or the next year, and the planned transmission power curve for each time period.

[0149] Third, for cascade hydropower station groups, the aforementioned first dispatch instruction also includes a cascade joint operation plan, which clarifies the coordination and cooperation relationship between upstream and downstream power stations.

[0150] After the first dispatch instruction is generated, it is sent to the control execution units corresponding to the hydropower reservoir and the inter-regional tie line. Simultaneously, the planned adjustable hydropower generation value and the planned transmission power value of the inter-regional tie line output from the first dispatch instruction will serve as the operating boundaries of the second dispatch rule base, used for optimization calculations during the short-to-medium-term dispatch phase.

[0151] Furthermore, in this embodiment, the step of generating scheduling instructions based on the target scheduling rule base further includes: Step S406: When the target scheduling rule base is the second scheduling rule base, obtain the power balance parameters of the power grid and the daily cycle operation parameters of the energy storage power station.

[0152] Step S407: Generate the second scheduling instruction based on the power balance parameters and the daily cycle operation parameters.

[0153] It should be noted that the aforementioned power balance parameters refer to a set of parameters used to constrain the instantaneous balance of power generation and consumption within each control zone of the power grid. These parameters include the active power output of all power sources (thermal, hydro, wind, and solar) within each control zone, the active power demand of all loads, network losses, and the charging and discharging power of energy storage devices. These power balance parameters are used to construct real-time balance equation constraints, ensuring that at any given time, the sum of power generation and energy storage discharge within the control zone equals the sum of load power, network losses, and energy storage charging power.

[0154] The aforementioned energy storage power stations can refer to electrochemical energy storage power stations and pumped storage power stations among multi-element energy storage devices, and are the core objects regulated by the second dispatch rule base. The daily cycle operation parameters of the aforementioned energy storage power stations can refer to a set of parameters used to constrain the intraday operating behavior of the energy storage devices, including the lower and upper limits of the energy storage device's charging and discharging power (determined by the rated power of the energy storage converter), the lower and upper limits of the state of charge (set to avoid overcharging and over-discharging and extend battery life, usually set at 10% and 90%), and the state of charge balance condition at the beginning and end of the daily dispatch cycle (requiring the energy storage device to maintain a consistent state of charge or a predetermined value at the beginning and end of the daily dispatch cycle). These daily cycle operation parameters are used to guide the energy storage to perform effective charging and discharging conversion within the day, so as to exert its core value of peak shaving and valley filling, and balancing fluctuations.

[0155] The aforementioned second dispatch instruction refers to a specific control command generated by the power dispatch system for short-to-medium-term dispatch (day-ahead planning phase) when the target dispatch rule base is the second dispatch rule base. The content of the aforementioned second dispatch instruction may include: day-ahead power generation plans for all generating units (thermal power, hydropower, and new energy) within each control zone (one point every 15 minutes or every hour), time-of-use charging and discharging power instructions for pumped storage power stations and electrochemical energy storage power stations, and target state-of-charge curves for each energy storage device, etc. The aforementioned second dispatch instruction will be sent to the control execution units of each generating unit and energy storage device.

[0156] In the specific implementation, when the selected target scheduling rule base is the second scheduling rule base, the power balance parameters of the power grid and the daily cycle operation parameters of the energy storage power station are obtained, and a second scheduling instruction is generated based on the power balance parameters and the daily cycle operation parameters.

[0157] First, the target scheduling rule base is determined as the second scheduling rule base, indicating that the current stage is the medium-to-short-term scheduling phase (corresponding to the day-ahead planning phase). The operating boundary of the second scheduling rule base is determined by the planned value of adjustable hydropower generation output from the first scheduling rule base and the planned value of inter-regional tie line transmission power, ensuring the consistency between the medium-to-short-term scheduling scheme and the long-term power balance strategy.

[0158] Next, the power balance parameters of the power grid are obtained from the current operating status and pre-stored scheduling parameters. These power balance parameters include the following: First, obtain the predicted active power output data for all power sources within each control zone. These power sources include thermal power units, hydropower units, wind farms, and photovoltaic power plants. For thermal and hydropower, obtain their planned output range; for wind and photovoltaic, obtain ultra-short-term or short-term power forecast data.

[0159] Second, obtain the predicted active power demand data for all loads within each control zone. This load data typically comes from a load forecasting system, with a time granularity of 15 minutes or 1 hour.

[0160] Third, obtain the network loss parameters between each control zone. The aforementioned network loss reflects the power loss during power transmission and is related to the transmission power and line parameters.

[0161] Fourth, obtain the charging and discharging power data of the energy storage device, including the current charging and discharging status and the planned charging and discharging power.

[0162] Simultaneously, the daily cycle operation parameters of the energy storage power station are acquired. These daily cycle operation parameters include the following: First, obtain the lower and upper limits of the charging and discharging power for each energy storage device (pumped storage power station and electrochemical energy storage power station). The lower limit of the charging and discharging power is usually 0 (no charging or discharging), and the upper limit of the charging and discharging power is determined by the rated power of the energy storage converter.

[0163] Second, obtain the minimum and maximum state of charge (SOC) values ​​for each energy storage device. The minimum SOC value is typically set at 10%, and the maximum SOC value is typically set at 90%, to avoid overcharging and over-discharging from damaging battery life.

[0164] Third, obtain the state of charge (SOC) balance conditions for each energy storage device at the beginning and end of the daily scheduling cycle. These conditions require that the SOC of the energy storage devices remain consistent or maintain a predetermined value at the beginning and end of each daily scheduling cycle. For example, the initial SOC of the energy storage power station must be equal to the final SOC, or the final SOC must be no less than 95% of the initial SOC.

[0165] Next, based on the obtained power balance parameters and daily cycle operation parameters, combined with the ultra-short-term predicted output data of wind and solar power, load forecast data, and the operating boundaries (planned values ​​of adjustable hydropower generation and planned values ​​of inter-regional transmission power) provided by the first dispatch rule base, a medium- and short-term optimization solution is performed. The goal of the above optimization solution is to minimize power generation costs and maximize the absorption of new energy sources or the overall benefits, while satisfying the power balance constraints and daily cycle operation constraints.

[0166] Based on the optimization solution, a second scheduling instruction is generated. This second scheduling instruction includes the following: First, the dispatch instructions for each generator unit: the daytime power generation plan of each thermal power unit and hydropower unit (one point every 15 minutes or every hour), and the output limit of each wind farm and photovoltaic power station (wind curtailment and solar curtailment instructions).

[0167] Second, the dispatch instructions for pumped storage power stations and electrochemical energy storage power stations include: time-segmented charging and discharging power instructions (e.g., how many megawatts of power to charge in a certain time period, how many megawatts of power to discharge in a certain time period), and target curves for the state of charge in each time period.

[0168] Third, for scheduling instructions for inter-regional tie lines: time-segmented transmission power plan values, which are subject to boundary constraints of the inter-regional tie line transmission power plan values ​​output by the first scheduling rule base.

[0169] After the second dispatch instruction is generated, it is sent to the control execution units corresponding to each generator set and energy storage device. At the same time, the energy storage reference charge and discharge plan (the reference charge and discharge power curve and the reference state of charge curve of the energy storage device) and the power flow plan value of the key transmission section output in the second dispatch instruction will serve as the operating framework of the third dispatch rule base for rolling adjustments during the real-time dispatch phase.

[0170] Furthermore, in this embodiment, the step of generating scheduling instructions based on the target scheduling rule base further includes: Step S408: When the target scheduling rule base is the third scheduling rule base, obtain the power fluctuation smoothing parameters and transmission section safety parameters from the current operating state.

[0171] Step S409: Obtain the fast adjustment response parameters in the fast response energy storage device.

[0172] Step S410: Generate the third scheduling instruction based on the power fluctuation smoothing parameters, the transmission section safety parameters, and the rapid adjustment response parameters.

[0173] It should be noted that the aforementioned power fluctuation mitigation parameters can refer to constraint parameters used to mitigate net load power fluctuations, including the regional power deviation minimization target parameter and the lower and upper limits of the regulation power ramp-up rate for energy storage and generating units. The aforementioned regional power deviation minimization target parameter is used to construct an objective function aimed at minimizing the deviation between the actual net load and the planned value. The aforementioned regulation power ramp-up rate refers to the maximum power increment per unit time, used to limit the rate of power change of energy storage devices and generating units to prevent sudden power surges from impacting the power grid.

[0174] The aforementioned transmission section safety parameters refer to constraint parameters used to ensure the safe operation of critical transmission sections, including the real-time absolute value of power flow and the stability limit value of the critical transmission section. The real-time absolute value of power flow comes from power measurement devices on the transmission line, and the stability limit value comes from the power system stability analysis calculation results. The aforementioned transmission section safety parameters are used to construct inequality constraints that ensure the real-time absolute value of power flow does not exceed the stability limit value.

[0175] The aforementioned fast-response energy storage devices can refer to energy storage devices with second-level or minute-level rapid adjustment capabilities, including electrochemical energy storage power stations and fast-regulating hydropower units. These fast-response energy storage devices are the core objects regulated by the third dispatch rule base. The aforementioned rapid adjustment response parameters can refer to parameters used to constrain the adjustment capabilities of fast-response energy storage devices, including the second-level or minute-level response rate of electrochemical energy storage (i.e., the time required for the energy storage converter to output a specified power from receiving a command), the minute-level adjustment rate of hydropower units (i.e., the maximum rate of power increase or decrease of the hydropower unit per unit time), and the limit on the number of start-stop cycles within a certain time period (used to protect the lifespan of the unit equipment).

[0176] The aforementioned third dispatch instruction refers to a specific control command generated by the power dispatch system for real-time dispatch (real-time planning phase) when the target dispatch rule base is the third dispatch rule base. The content of this third dispatch instruction may include: second-level or minute-level charging and discharging power adjustment values ​​for electrochemical energy storage power stations, real-time power setpoints for fast-regulating hydropower units, and real-time control targets for the state of charge of each fast-response energy storage device. This third dispatch instruction will be sent to the local control system of the fast-response energy storage device and executed on a second-level or minute-level cycle.

[0177] In the specific implementation, when the selected target scheduling rule base is the third scheduling rule base, the power fluctuation smoothing parameters and transmission section safety parameters are obtained from the current operating status, the fast adjustment response parameters in the fast response energy storage device are obtained, and the third scheduling instruction is generated based on the power fluctuation smoothing parameters, transmission section safety parameters and fast adjustment response parameters.

[0178] First, the target scheduling rule base is determined to be the third scheduling rule base, indicating that the current stage is real-time scheduling (corresponding to the real-time planning stage). The operational framework of the third scheduling rule base is determined by the energy storage baseline charge and discharge plan output from the second scheduling rule base and the power flow plan values ​​of key transmission sections, ensuring the consistency between the real-time scheduling scheme and the medium- and short-term scheduling scheme. Next, power fluctuation smoothing parameters are obtained from the current operating status. The aforementioned power fluctuation smoothing parameters include the following: First, obtain the target parameters for minimizing regional power deviation. These target parameters reflect the deviation between the actual net load and the day-ahead planned value, and are used to construct the objective function, with the goal of minimizing the power deviation during real-time scheduling.

[0179] Second, obtain the lower and upper limits of the ramp rate for the regulation power of energy storage and generating units. These ramp rate parameters are used to limit the maximum rate of power change of energy storage devices and generating units per unit time, preventing sudden power changes caused by excessively rapid regulation.

[0180] Simultaneously, the safety parameters of the transmission section are obtained from the current operating status. These safety parameters include the following: First, obtain the real-time absolute values ​​of power flow at each key transmission section. These real-time absolute values ​​of power flow are obtained from synchronous phasor measurement devices or data acquisition and monitoring systems on the transmission lines, and are sampled multiple times per second.

[0181] Second, obtain the stability limit values ​​for each key transmission section. These stability limit values ​​are static stability limits or thermal stability limits calculated based on power system stability analysis and are pre-stored in the power dispatching system.

[0182] Simultaneously, the rapid adjustment response parameters of the fast-response energy storage device are acquired. These rapid adjustment response parameters include the following: First, for electrochemical energy storage power stations, obtain their response rate parameters in the range of seconds or minutes. These response rate parameters reflect the time required for the electrochemical energy storage converter to actually output the specified power from receiving the dispatch command, typically in the range of seconds (e.g., 1 to 5 seconds).

[0183] Second, for rapidly adjustable hydropower units, obtain their minute-level adjustment rate parameters and start-stop frequency limit parameters. The aforementioned minute-level adjustment rate parameter reflects the maximum rate of power increase or decrease of the hydropower unit per unit time (e.g., the rated output of a thermal power unit can be adjusted by 2% to 5% per minute); the aforementioned start-stop frequency limit parameter reflects the maximum number of start-stop cycles allowed for the hydropower unit within a certain time period, used to protect the lifespan of the unit equipment.

[0184] Next, based on the acquired power fluctuation mitigation parameters, transmission section safety parameters, and rapid adjustment response parameters, combined with the operational framework provided by the second scheduling rule base (energy storage baseline charge / discharge plan, key transmission section power flow plan values) and real-time measurement data (system frequency, voltage, power flow, etc.), real-time optimization is performed. The goal of this real-time optimization is to rapidly adjust the charging and discharging power of the rapid response energy storage device, minimizing power deviation, while satisfying power fluctuation mitigation constraints, transmission section safety constraints, and rapid adjustment response constraints.

[0185] Based on the optimization results, a third scheduling instruction is generated. This third scheduling instruction includes the following: First, dispatch instructions for electrochemical energy storage power stations: second-level or minute-level adjustment values ​​for charging and discharging power (for example, adjusting the base discharge power of 50 MW upward by 30 MW to reach 80 MW discharge power) and real-time state of charge control targets.

[0186] Second, dispatch instructions for rapidly adjusting hydropower units: real-time power setpoints at the minute level (e.g., adjusting output from 200 MW to 250 MW), and real-time power instructions for participating in automatic generation control or frequency regulation services.

[0187] Third, dispatch instructions for key transmission sections: real-time control instructions to ensure that the power flow of the section does not exceed the stable limit value, and to alleviate the section congestion when necessary by adjusting the charging and discharging power of the energy storage equipment on both sides of the section.

[0188] After the third dispatch instruction is generated, it is sent to the local control system of the electrochemical energy storage power station and the fast-regulating hydropower unit at a cycle of seconds or minutes, and the local control system executes it immediately.

[0189] Furthermore, in this embodiment, before the step of sending the scheduling command to the corresponding energy storage device within the target control area, the method further includes: Step S51: Determine whether the dispatching instruction satisfies the cross-regional power grid stability constraints.

[0190] Step S52: When the dispatch instruction satisfies the cross-regional power grid stability constraint, execute the step of sending the dispatch instruction to the corresponding energy storage device within the target control area.

[0191] Step S53: When the scheduling instruction does not meet the cross-regional power grid stability constraints, the target scheduling rule base is constrained and strengthened, and the scheduling instruction is regenerated based on the constrained target scheduling rule base.

[0192] It should be noted that the aforementioned cross-regional power grid stability constraints refer to a set of constraints that ensure the safe and stable operation of the power grid over a larger area (across the target control area). These constraints include the difference between the real-time power flow and stability limits of each key transmission section, the difference between the voltage of each key node and the safe operating boundary, and the deviation constraint between the system frequency and the rated value. These cross-regional power grid stability constraints are used to determine whether the currently generated dispatch instructions will cause the power grid to exceed limits or become unstable. The dispatch instructions satisfying the cross-regional power grid stability constraints can mean that after the dispatch instructions are executed, the real-time power flow of all key transmission sections is less than the stability limit value, the voltage of all key nodes is within the safe operating boundary, and the system frequency deviation is within the allowable range.

[0193] The aforementioned constraint strengthening can refer to raising the priority of grid stability constraints in the target control area and tightening the constraints in the target dispatch rule base when dispatch instructions do not meet cross-regional grid stability constraints. Specific methods of constraint strengthening include: tightening the power flow stability limits of key transmission sections within the target control area (e.g., reducing the stability limits by 10%), tightening the voltage safety operation boundaries of key nodes within the target control area (e.g., narrowing the allowable voltage range from ±5% to ±4%), and increasing mandatory requirements on the regulation rate and capacity of energy storage devices within the target control area (e.g., requiring energy storage devices to reserve more standby capacity).

[0194] In the specific implementation, after generating the dispatch instruction but before sending it, it is determined whether the dispatch instruction meets the stability constraints of the cross-regional power grid, and different branch operations are executed according to the determination result. The generated dispatch instruction is obtained, and combined with the current operating state, it is determined whether the execution of the dispatch instruction will lead to grid over-limits or instability. First, based on the current operating state and the control parameters in the dispatch instruction, power flow calculation, frequency response analysis, and voltage stability analysis are performed to predict the power grid state after the execution of the dispatch instruction. The predicted power grid state includes the predicted power flow values ​​of each key transmission section, the predicted voltage values ​​of each key node, and the predicted system frequency value. Next, a first set of indicators characterizing the stability of the cross-regional power grid is obtained. The first set of indicators includes: the difference between the real-time power flow and the stability limit of each key transmission section, the difference between the voltage of each key node and the safe operating boundary, and the deviation of the system frequency from the rated value. Each indicator in the first set of indicators is compared one by one with the preset safety conditions. The preset safety conditions are based on the power grid safe operation procedures, equipment capacity, and thresholds pre-set by the stability analysis. For example, for power flow at critical transmission sections, the safety condition requires the actual power flow to be less than the stability limit (i.e., the difference is greater than zero); for voltage deviation, the safety condition requires the absolute value of the voltage deviation to not exceed the allowable range (e.g., ±5%); for frequency deviation, the safety condition requires the absolute value of the frequency deviation to not exceed the allowable range (e.g., ±0.1 Hz). It is determined whether all indicators in the first indicator set meet the corresponding preset safety conditions. If all indicators meet the preset safety conditions, the dispatch instruction is deemed to meet the cross-regional power grid stability constraints. If at least one indicator does not meet the preset safety conditions, the dispatch instruction is deemed not to meet the cross-regional power grid stability constraints. When the dispatch instruction is determined to meet the cross-regional power grid stability constraints, the step of sending the dispatch instruction to the corresponding energy storage device within the target control area is executed. Through the dispatch automation system and data communication network, the dispatch instruction is sent to each energy storage device, causing the energy storage device to adjust its charging and discharging power according to the dispatch instruction. When the dispatch instruction is determined not to meet the cross-regional power grid stability constraints, the constraint coordination mechanism is triggered. The above constraint coordination mechanism is a dynamic iterative optimization process aimed at improving the safety of the dispatch scheme. First, the first set of indicators is analyzed to identify the critical control areas and dominant instability factors causing constraint non-compliance. The critical control areas refer to the regions with the worst performance (e.g., the region containing the critical transmission section with the highest load factor that has exceeded limits, or the region containing the critical node with the largest voltage deviation). The dominant instability factors refer to the specific reasons causing constraint non-compliance (e.g., exceeding power flow limits, voltage limits, or frequency limits). Next, the priority of grid stability constraints in the critical control areas is increased, and the constraints of the target scheduling rule base are strengthened. The specific methods of constraint strengthening include at least one of the following: First, tighten the power flow stability limits for critical transmission sections within key control areas. For example, reduce the original stability limit of 1000 MW to 900 MW to provide a greater safety margin.

[0195] Second, tighten the voltage safety operating boundaries of critical nodes within critical control areas. For example, reduce the original allowable voltage range of ±5% to ±4% to provide more stringent voltage control requirements.

[0196] Third, mandatory requirements are added regarding the regulation rate and capacity of energy storage equipment in critical control areas. For example, energy storage equipment is required to reserve 20% of its capacity for emergency support, or the ramp-up rate of energy storage equipment is required to not exceed 10 megawatts per minute.

[0197] Based on the enhanced stability constraints, the target scheduling rule base is strengthened. Specifically, additional constraints corresponding to the dominant instability factors are added to the target scheduling rule base, or the boundary values ​​of existing constraints are modified (e.g., the power flow stability limit of a key transmission section is changed from 1000 MW to 900 MW). Next, based on the strengthened target scheduling rule base, the step of generating scheduling instructions is re-executed (i.e., the optimization solution is re-performed to generate new scheduling instructions). The newly generated scheduling instructions are then subjected to the cross-regional grid stability constraint check again, and the above iterative process is repeated until the generated scheduling instructions satisfy the cross-regional grid stability constraints. After the iteration is complete, the scheduling instructions that finally satisfy the cross-regional grid stability constraints are sent to the corresponding energy storage devices within the target control area for execution.

[0198] This application also provides a power grid dispatching device; please refer to [reference needed]. Figure 4 The device includes: Status acquisition module 10 is used to acquire the current operating status of the power grid; The scale determination module 20 is used to determine the current scheduling time scale of the power grid based on the current operating state; The region determination module 30 is used to determine the target control region from the power grid based on the scheduling time scale and the current operating status; The instruction generation module 40 is used to select a target scheduling rule library from multiple preset scheduling rule libraries according to the scheduling time scale and the target control area, and generate scheduling instructions based on the target scheduling rule library; The power adjustment module 50 is used to send the scheduling command to the corresponding energy storage device within the target control area, so that the energy storage device adjusts its charging and discharging power according to the scheduling command.

[0199] The power grid dispatching device provided in this application, employing the power grid dispatching method in the above embodiments, can solve the technical problem of how to adaptively dispatch diverse energy storage resources according to the real-time state of the power grid. Compared with the prior art, the beneficial effects of the power grid dispatching device provided in this application are the same as those of the power grid dispatching method provided in the above embodiments, and other technical features in the power grid dispatching device are the same as those disclosed in the methods of the above embodiments, and will not be repeated here.

[0200] This application provides a power grid dispatching device, which includes: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, and the instructions are executed by the at least one processor to enable the at least one processor to perform the power grid dispatching method in the above embodiment 1.

[0201] The following is for reference. Figure 5 The diagram illustrates a structural schematic suitable for implementing the power grid dispatching equipment in the embodiments of this application. The power grid dispatching equipment in the embodiments of this application may include, but is not limited to, mobile terminals such as mobile phones, laptops, digital broadcast receivers, PDAs (Personal Digital Assistants), PADs (Portable Application Description), PMPs (Portable Media Players), vehicle terminals (e.g., vehicle navigation terminals), and fixed terminals such as digital TVs and desktop computers. Figure 5 The power grid dispatching equipment shown is merely an example and should not impose any limitations on the functionality and scope of use of the embodiments of this application.

[0202] like Figure 5As shown, the power grid dispatching equipment may include a processing unit 1001 (e.g., a central processing unit, a graphics processing unit, etc.), which can perform various appropriate actions and processes according to a program stored in a read-only memory (ROM) 1002 or a program loaded from a storage device 1003 into a random access memory (RAM) 1004. The RAM 1004 also stores various programs and data required for the operation of the power grid dispatching equipment. The processing unit 1001, ROM 1002, and RAM 1004 are interconnected via a bus 1005. An input / output (I / O) interface 1006 is also connected to the bus. Typically, the following systems can be connected to the I / O interface 1006: input devices 1007 including, for example, a touch screen, touchpad, keyboard, mouse, image sensor, microphone, accelerometer, gyroscope, etc.; output devices 1008 including, for example, a liquid crystal display (LCD), speaker, vibrator, etc.; storage devices 1003 including, for example, magnetic tape, hard disk, etc.; and communication devices 1009. Communication device 1009 allows the power grid dispatching equipment to communicate wirelessly or wiredly with other equipment to exchange data. Although the figure shows power grid dispatching equipment with various systems, it should be understood that implementation or possession of all the systems shown is not required. More or fewer systems may be implemented alternatively.

[0203] Specifically, according to the embodiments disclosed in this application, the processes described above with reference to the flowcharts can be implemented as computer software programs. For example, embodiments disclosed in this application include a computer program product comprising a computer program carried on a computer-readable medium, the computer program containing program code for performing the methods shown in the flowcharts. In such embodiments, the computer program can be downloaded and installed from a network via a communication device, or installed from storage device 1003, or installed from ROM 1002. When the computer program is executed by processing device 1001, it performs the functions defined in the methods of the embodiments disclosed in this application.

[0204] The power grid dispatching equipment provided in this application, employing the power grid dispatching method in the above embodiments, can solve the technical problem of how to adaptively dispatch diverse energy storage resources according to the real-time state of the power grid. Compared with the prior art, the beneficial effects of the power grid dispatching equipment provided in this application are the same as those of the power grid dispatching method provided in the above embodiments, and other technical features in this power grid dispatching equipment are the same as those disclosed in the previous embodiment method, and will not be repeated here.

[0205] It should be understood that the various parts disclosed in this application can be implemented using hardware, software, firmware, or a combination thereof. In the description of the above embodiments, specific features, structures, materials, or characteristics can be combined in any suitable manner in one or more embodiments or examples.

[0206] The above description is merely a specific embodiment of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the scope of the technology disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

[0207] The above description is only a part of the embodiments of this application and does not limit the patent scope of this application. All equivalent structural transformations made under the technical concept of this application and using the contents of the specification and drawings of this application, or direct / indirect applications in other related technical fields, are included in the patent protection scope of this application.

Claims

1. A power grid dispatching method, characterized in that, The method is applied to a power dispatching system, which is connected to various energy storage devices. The method includes: Obtain the current operating status of the power grid; The current scheduling time scale of the power grid is determined based on the current operating status; Based on the scheduling timescale and the current operating status, a target control area is determined from the power grid; Based on the scheduling time scale and the target control area, a target scheduling rule library is selected from multiple preset scheduling rule libraries, and scheduling instructions are generated based on the target scheduling rule library. The scheduling command is sent to the corresponding energy storage device within the target control area so that the energy storage device adjusts its charging and discharging power according to the scheduling command.

2. The power grid dispatching method as described in claim 1, characterized in that, The scheduling time scale includes a first scheduling time scale, a second scheduling time scale, and a third scheduling time scale. The step of determining the current scheduling time scale of the power grid based on the current operating state includes: Obtain the preset scheduling calendar and the time information in the current running state; Based on the preset scheduling calendar and the time information, determine the planning stage type at the current moment; If the planning phase type is an annual planning phase or a monthly planning phase, then the scheduling time scale is determined as the first scheduling time scale; If the planning phase type is the day-ahead planning phase, then the scheduling time scale is determined as the second scheduling time scale; If the planning phase type is a real-time planning phase, then the scheduling time scale is determined as the third scheduling time scale.

3. The power grid dispatching method as described in claim 2, characterized in that, The step of determining the target control area from the power grid based on the scheduling time scale and the current operating state includes at least one of the following: When the scheduling time scale is the first scheduling time scale, the deviation data between the planned power and the actual power generation of the cross-regional tie line is obtained from the current operating state, and the power concentration area connected by the cross-regional tie line with the largest deviation in the deviation data is determined as the target control area. When the scheduling time scale is the second scheduling time scale, the load rate of the key transmission section is obtained from the current operating state, and the area where the key transmission section with the highest load rate is located is determined as the target control area; When the scheduling time scale is the third scheduling time scale, system frequency deviation, voltage deviation and power fluctuation data are obtained from the current operating state, and the load concentration area where the system frequency deviation exceeds the preset frequency threshold, the load concentration area where the voltage deviation exceeds the preset voltage threshold, or the load concentration area where the power fluctuation exceeds the preset power threshold is determined as the target control area.

4. The power grid dispatching method as described in claim 3, characterized in that, The plurality of preset scheduling rule bases include a first scheduling rule base, a second scheduling rule base, and a third scheduling rule base. The step of selecting a target scheduling rule base from the plurality of preset scheduling rule bases includes: When the scheduling time scale is the first scheduling time scale, the first scheduling rule base is selected as the target scheduling rule base; When the scheduling time scale is the second scheduling time scale, the second scheduling rule base is selected as the target scheduling rule base, wherein the operating boundary of the second scheduling rule base is determined by the planned value of adjustable hydropower generation and the planned value of cross-regional tie line transmission power output by the first scheduling rule base. When the scheduling time scale is the third scheduling time scale, the third scheduling rule base is selected as the target scheduling rule base, wherein the operating framework of the third scheduling rule base is determined by the energy storage benchmark charging and discharging plan and the power flow plan value of the key transmission section output by the second scheduling rule base.

5. The power grid dispatching method as described in claim 4, characterized in that, The energy storage device includes a hydroelectric reservoir, the scheduling instruction includes a first scheduling instruction, and the step of generating a scheduling instruction based on the target scheduling rule base includes: When the target scheduling rule base is the first scheduling rule base, the water level constraint parameters of the hydropower reservoir and the power constraint parameters of the inter-regional connecting line are obtained. The first scheduling instruction is generated based on the water level constraint parameters and the power constraint parameters.

6. The power grid dispatching method as described in claim 4, characterized in that, The energy storage device further includes an energy storage power station, the scheduling instruction includes a second scheduling instruction, and the step of generating the scheduling instruction based on the target scheduling rule base further includes: When the target scheduling rule base is the second scheduling rule base, the power balance parameters of the power grid and the daily cycle operation parameters of the energy storage power station are obtained; The second scheduling instruction is generated based on the power balance parameters and the daily cycle operation parameters.

7. The power grid dispatching method as described in claim 4, characterized in that, The energy storage device further includes a fast-response energy storage device, and the scheduling instruction further includes a third scheduling instruction. The step of generating the scheduling instruction based on the target scheduling rule base further includes: When the target scheduling rule base is the third scheduling rule base, power fluctuation smoothing parameters and transmission section safety parameters are obtained from the current operating state; Obtain the rapid adjustment response parameters in the fast-response energy storage device; The third scheduling instruction is generated based on the power fluctuation smoothing parameters, the transmission section safety parameters, and the rapid adjustment response parameters.

8. The power grid dispatching method as described in claim 1, characterized in that, Before the step of sending the scheduling command to the corresponding energy storage device within the target control area, the method further includes: Determine whether the dispatching instruction satisfies the cross-regional power grid stability constraints; When the dispatch instruction satisfies the cross-regional power grid stability constraint, the step of sending the dispatch instruction to the corresponding energy storage device within the target control area is executed. When the scheduling instruction does not meet the cross-regional power grid stability constraints, the target scheduling rule base is constrained and strengthened, and the scheduling instruction is regenerated based on the constrained target scheduling rule base.

9. A power grid dispatching device, characterized in that, The device includes: The status acquisition module is used to acquire the current operating status of the power grid; The scale determination module is used to determine the current scheduling time scale of the power grid based on the current operating state. The region determination module is used to determine the target control region from the power grid based on the scheduling time scale and the current operating status; The instruction generation module is used to select a target scheduling rule library from multiple preset scheduling rule libraries according to the scheduling time scale and the target control area, and generate scheduling instructions based on the target scheduling rule library; The power adjustment module is used to send the scheduling command to the corresponding energy storage device within the target control area, so that the energy storage device adjusts its charging and discharging power according to the scheduling command.

10. A power grid dispatching device, characterized in that, The device includes: a memory, a processor, and a computer program stored in the memory and executable on the processor, the computer program being configured to implement the steps of the power grid dispatching method as described in any one of claims 1 to 8.

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