A regional backup auxiliary service transaction method and system

Abstract

The application discloses a kind of regional backup auxiliary service transaction method and system, the method includes calculating the next day backup capacity margin reference value of provincial power grid, and is issued to each provincial power grid dispatching agency;Complete tie-line day-ahead plan update and issue, and publish day-ahead backup market clearing result to market subject;After rationality and safety check to day-ahead unit saleable capacity, form the next day whole network intra-day available up-regulating unit sequence, and publish the next day intra-day backup price index and whole network next day intra-day available up-regulating unit sequence to market subject;Receive the intra-day initial generation plan cycle of provincial power grid reported rolling;Complete tie-line intra-day plan update and issue, and publish intra-day backup market clearing result to market subject, the application establishes marketized backup auxiliary service inter-provincial regulation mechanism, gives full play to the decisive role of market in resource allocation, and comprehensively improves the power security guarantee capability of regional power grid.

Description

Technical Field

[0001] This invention relates to a regional backup ancillary service trading method and system, belonging to the field of power grid dispatching technology. Background Technology

[0002] Reserve capacity is one of the main measures to ensure the safe and reliable operation of the power system. Using market mechanisms to reserve and allocate reserve capacity is a current trend in the market-oriented reform of the power industry. Establishing a reasonable market trading mechanism and reserving as little reserve capacity as possible while meeting system reliability requirements, as well as its allocation within interconnected subsystems, are urgent issues that need to be studied and resolved in my country's regional power grid reserve management, with the aim of proactively stimulating the enthusiasm of reserve service providers.

[0003] The current power grid faces new challenges, including the operation of large-scale AC / DC hybrid power grids with ultra-high voltage transmission lines, the deepening of power market reforms and the execution of market-traded electricity volumes, the rapid development of new energy grid integration and the priority guarantee of consumption, and the increasing proportion of imported electricity. There is a lack of feasible market-based balancing mechanisms between provincial power grids in different regions, and the demand for inter-provincial reserve support is real. Simultaneously, under the current electricity spot market environment, and following the model of a national-provincial two-tier spot market plus a regional ancillary service market, there is an urgent need to develop a regional reserve ancillary service market. Through market mechanisms, this market can fully leverage the role of regional reserve resources in absorbing the risks of load forecast deviations and gaps after large DC faults, connect the trading boundaries of provincial and inter-provincial markets, centrally allocate positive and negative reserve resources, and ensure the safe, stable, and economical operation of the regional power grid. Summary of the Invention

[0004] The purpose of this invention is to overcome the shortcomings of the prior art, provide a regional backup ancillary service trading method and system, establish a market-oriented inter-provincial allocation mechanism for backup ancillary services, give full play to the decisive role of the market in resource allocation, and comprehensively improve the regional power grid's power security guarantee capability.

[0005] To achieve the above objectives, the present invention is implemented using the following technical solution:

[0006] In a first aspect, the present invention provides a regional backup ancillary service trading method, applied to a regional power grid control agency, comprising:

[0007] Based on the pre-completed day-ahead plan for interconnection lines, calculate the reference value for the reserve capacity margin of the provincial power grid for the next day, and distribute it to the dispatching agencies of each provincial power grid.

[0008] Based on the day-ahead reserve demand and available capacity declared by the provincial power grid dispatching agency, and combined with the day-ahead reserve capacity seller quotations declared by power generation enterprises, the reserve market is cleared, the day-ahead plan of the interconnection line is updated and issued, and the day-ahead reserve market clearing results are released to market participants;

[0009] After verifying the rationality and safety of the daytime available capacity of generating units, a sequence of generating units available for intraday adjustment across the entire network for the next day is formed, and the intraday standby price index and the sequence of generating units available for intraday adjustment across the entire network for the next day are released to market participants.

[0010] Receive rolling reports of the initial daily power generation plan cycle of the provincial power grid;

[0011] Based on the daily reserve demand and available capacity declared by the provincial power grid dispatching agency, and combined with the daily reserve capacity seller quotations declared by power generation enterprises, the reserve market is cleared, the daily plan for interconnection lines is updated and issued, and the results of the daily reserve market clearing are released to market participants.

[0012] Among them, the provincial power grid dispatching agency is used for:

[0013] Select the day-ahead reserve market buyer and seller based on the next-day reserve capacity margin reference value of the provincial power grid, and declare the day-ahead reserve ancillary service demand capacity and the available capacity of the grid units for sale;

[0014] Select the buyer and seller in the intraday standby market based on the standby capacity situation during the intraday trading session of this network, and declare the intraday standby ancillary service demand capacity and the available capacity of the network's generating units for sale.

[0015] Furthermore, based on the pre-completed day-ahead plan for interconnection lines, the reference value for the reserve capacity margin of the provincial power grid for the next day is calculated using the following formula:

[0016] Reference value for the reserve capacity margin of the provincial power grid the next day = the maximum adjustable capacity of the provincial power grid according to the dispatching caliber the next day + the planned interconnection line of the provincial power grid the next day – the predicted load of the provincial power grid according to the dispatching caliber the next day.

[0017] Furthermore, after the day-ahead reserve market closes, the intraday reserve market enters the overnight preparation phase. This overnight preparation phase generates the next day's nationwide intraday available capacity sequence and the next day's intraday reserve price index, including:

[0018] The available capacity sequence for the entire network within a day is as follows: The capacity of each tier declared by the generator sets that can participate in the market unit combination is determined by deducting the capacity blocked due to the generator set's own reasons, the capacity blocked due to reasons other than the generator set, the planned output, and the reserve capacity reserved by the dispatching agency. The capacity sequence is formed by sorting the seller's intraday landing price from low to high.

[0019] Intraday Reserve Price Index: This refers to the intraday price quoted by the seller of the last tier of generating unit capacity in the intraday reserve market sequence that meets the calculated reserve demand of the entire network for the next day. It is used to reflect the tightness of supply and demand for intraday reserve capacity for the next day.

[0020] The estimated reserve requirement for the entire network is the sum of the maximum and minimum values ​​of the spinning reserve capacity of each provincial power grid in the monthly power production and maintenance plan issued by the regional power grid, and shall not exceed the total daily capacity of the entire network's upgraded generating units.

[0021] Furthermore, the clearing of the reserve market adopts a segmented marginal price clearing principle, including:

[0022] The sellers are ranked from lowest to highest based on their bid price to form a seller sequence. The seller's bid price = seller's bid price + seller's provincial power grid company transmission price + regional power grid company electricity transmission price.

[0023] The seller sequence is segmented according to the buyer's quotation. The seller's reserve capacity in each segment is allocated according to the proportion of each buyer's demand capacity, provided that the seller's final quotation does not exceed the quotation of each buyer.

[0024] The marginal clearing price for each segment is the seller's bid for the capacity of the last winning unit in each segment. If the sellers' bids are the same, the last winning unit will be determined in the following order: hydropower units, electrochemical energy storage power stations, gas turbine units, ultra-low emission large-capacity coal-fired units, ultra-low emission small-capacity coal-fired units, non-ultra-low emission large-capacity coal-fired units, and non-ultra-low emission small-capacity coal-fired units. For units with the same bid and priority, the winning bid will be allocated according to the proportion of the declared power.

[0025] If a seller's unit cannot be sold due to constraints such as grid safety conditions or unit load change rate, the next unit in the order will be selected to fill the vacancy.

[0026] Furthermore, this also includes: adjusting the power generation plans of each provincial power grid interconnection point within the region based on the results of the standby market clearing and conducting safety verification; if the safety verification fails, the standby market clearing will be carried out again; if the safety verification passes, the adjusted power generation plans of the interconnection points will be issued to each provincial power grid dispatching agency, and the clearing results will be published to each market participant.

[0027] Secondly, the present invention provides a regional backup ancillary service transaction system, comprising:

[0028] Market Management: This is used to centrally manage and maintain various input data required for market clearing calculations, providing accurate and reliable input data and market models for subsequent backup auxiliary service market clearing calculations, including market model management, market parameter management, and market data management;

[0029] The reporting and publishing module is used to complete the reporting and publishing of basic data and transaction data to market participants.

[0030] Transaction Management Module: Used to manage various processes and related input / output data in the day-ahead and intraday standby markets;

[0031] Safety verification module: Used for day-ahead and intraday power generation plan safety verification considering the results of standby market transactions;

[0032] Market settlement module: Used for settlement of standby capacity purchasers, sellers, and transmission parties in the standby market, providing comprehensive settlement display and various settlement analysis reports;

[0033] Data interaction module: used to realize data interaction with horizontal systems, as well as vertical data interaction with upper and lower level schedulers.

[0034] Furthermore, the system also includes a transaction statistics analysis module: used to perform statistical analysis on each clearing period from a price perspective, taking into account constraints such as ramp-up and slide-down, and to analyze the rationality of the clearing results.

[0035] Furthermore, the system also includes an information disclosure module: used to release to market participants the standby supply and demand situation of the previous day's market and the intraday market of the previous day, market clearing results, and market settlement information.

[0036] Furthermore, the system also includes a market announcement module: used by market operators to publish transaction notices, policy and regulatory announcements, and other information online.

[0037] Furthermore, the system also includes a market entity approval module: used by market operators to manage market members online and approve applications submitted by provincial dispatch agencies related to market entities' participation in the market, exit from the market, and maintenance parameters.

[0038] Compared with the prior art, the beneficial effects achieved by the present invention are as follows:

[0039] This invention provides a regional backup ancillary service trading method and system, establishes a market-oriented inter-provincial allocation mechanism for backup ancillary services, gives full play to the decisive role of the market in resource allocation, and comprehensively enhances the regional power grid's power security capabilities. Attached Figure Description

[0040] Figure 1 This is a flowchart illustrating the regional backup ancillary service transaction method provided in an embodiment of the present invention. Detailed Implementation

[0041] The present invention will be further described below with reference to the accompanying drawings. The following embodiments are only used to more clearly illustrate the technical solution of the present invention, and should not be used to limit the scope of protection of the present invention.

[0042] Example 1

[0043] This embodiment introduces a regional reserve ancillary service trading method, applied to a regional power grid control agency, including:

[0044] Based on the pre-completed day-ahead plan for interconnection lines, calculate the reference value for the reserve capacity margin of the provincial power grid for the next day, and distribute it to the dispatching agencies of each provincial power grid.

[0045] Based on the day-ahead reserve demand and available capacity declared by the provincial power grid dispatching agency, and combined with the day-ahead reserve capacity seller quotations declared by power generation enterprises, the reserve market is cleared, the day-ahead plan of the interconnection line is updated and issued, and the day-ahead reserve market clearing results are released to market participants;

[0046] After verifying the rationality and safety of the daytime available capacity of generating units, a sequence of generating units available for intraday adjustment across the entire network for the next day is formed, and the intraday standby price index and the sequence of generating units available for intraday adjustment across the entire network for the next day are released to market participants.

[0047] Receive rolling reports of the initial daily power generation plan cycle of the provincial power grid;

[0048] Based on the daily reserve demand and available capacity declared by the provincial power grid dispatching agency, and combined with the daily reserve capacity seller quotations declared by power generation enterprises, the reserve market is cleared, the daily plan for interconnection lines is updated and issued, and the results of the daily reserve market clearing are released to market participants.

[0049] Among them, the provincial power grid dispatching agency is used for:

[0050] Select the day-ahead reserve market buyer and seller based on the next-day reserve capacity margin reference value of the provincial power grid, and declare the day-ahead reserve ancillary service demand capacity and the available capacity of the grid units for sale;

[0051] Select the buyer and seller in the intraday standby market based on the standby capacity situation during the intraday trading session of this network, and declare the intraday standby ancillary service demand capacity and the available capacity of the network's generating units for sale.

[0052] like Figure 1 As shown, the regional backup ancillary service transaction method provided in this embodiment can be executed by the transaction system, and its application process specifically involves the following steps:

[0053] Step 1: Commence the day-ahead market process. Receive day-ahead and intraday reserve capacity seller quotations from power generation companies; receive market operation-related information from each provincial power grid within the region, including next-day dispatch forecast load, next-day dispatch maximum adjustable capacity, next-day pre-combination of units eligible to participate in the market, next-day pre-planned capacity of units eligible to participate in the market, next-day non-unit-related capacity obstruction of units eligible to participate in the market, next-day reserve capacity reserved for units eligible to participate in the market, day-ahead reserve market buyer quotations, and intraday reserve market buyer quotations; the regional power grid completes the submission of market operation-related information, including next-day dispatch maximum adjustable capacity of dispatched units, next-day pre-combination of units eligible to participate in the market, next-day pre-planned capacity of units eligible to participate in the market, next-day non-unit-related capacity obstruction of units eligible to participate in the market, and next-day reserve capacity reserved for units eligible to participate in the market.

[0054] Step 2: Receive the official inter-regional DC transmission line power transmission plan issued by the National Dispatch Center, complete the approval of the maintenance plan for the next day, and enter the relevant section limits into the safety verification system. The subsequent procedures will be extended depending on the arrival status of the official inter-regional DC transmission line power transmission plan.

[0055] Step 3: Receive the regional inter-provincial interconnection line plan completed by the planning system, calculate the reference value of the provincial power grid's reserve capacity margin for the next day, and distribute it to the provincial power dispatching agencies.

[0056] Step 4: The provincial power grid dispatching agency selects buyers and sellers based on the grid's reserve capacity situation for the following day. Buyers submit their day-ahead reserve ancillary service demand capacity, and sellers submit their day-ahead reserve ancillary service available for sale capacity. The provincial power grid dispatching agency confirms the day-ahead reserve market buyer's bid, and the power generation company confirms the day-ahead reserve market seller's bid.

[0057] Step 5: Clear the standby market as follows:

[0058] The aforementioned standby market clearing is a network-unconstrained clearing process. Considering constraints other than grid security, the results of the network-unconstrained clearing are used to adjust the pre-generation plan of the tie-line terminals and for safety verification. Other constraints include: unit ramp-up rate, unit slippage rate, availability of hydropower storage units, maximum charging / discharging power of energy storage, and energy storage charging / discharging time.

[0059] The reserve market clearing adopts a segmented marginal price clearing principle. Sellers are ranked from lowest to highest based on their bids, forming a seller sequence. This seller sequence is then segmented based on buyer bids. The seller reserve capacity within each segment is allocated according to the proportion of each buyer's demand capacity, provided that the sellers' bids do not exceed the bids of all buyers. The marginal clearing price for each segment is the seller's bid for the last winning unit capacity within that segment. If sellers have the same bid, the final winning unit is determined in the following order: hydropower units, electrochemical energy storage power stations, gas turbine units, ultra-low emission large-capacity coal-fired units, ultra-low emission small-capacity coal-fired units, non-ultra-low emission large-capacity coal-fired units, and non-ultra-low emission small-capacity coal-fired units. For units with the same bid and priority, the winning bid is allocated according to the proportion of the declared power.

[0060] Step 6: Adjust the generation plans of each provincial power grid interconnection point in the region according to the results of the standby market clearing and conduct a safety verification: If the safety verification fails, the day-ahead standby market clearing is carried out again; if the safety verification passes, the adjusted interconnection point generation plans are issued to each provincial power grid dispatching agency, and the clearing results are published to each market participant.

[0061] Step 7: Daily settlement of day-ahead reserve fees is performed based on the clearing prices of the market for each time period before the trading day, the cleared electricity from reserve capacity buyers, and the winning bids for reserve capacity sellers. Reserve fees are settled on a daily-to-month basis, specifically as follows:

[0062] The inter-provincial transmission fees generated from standby market transactions (including the transmission fees of the seller's power grid company and the inter-provincial transmission fees of the regional power grid) shall be borne by the buyer's provincial power grid company;

[0063] The cost of purchasing standby power by the buyer's provincial power grid enterprise shall be paid by the buyer's provincial power grid enterprise to the regional power grid enterprise;

[0064] The regional power grid company shall pay the total cost of the reserve capacity of the units under the jurisdiction of the provincial power grid company where the seller's units are dispatched to be settled. The reserve settlement cost of the seller's units shall be settled between the provincial power grid company or the regional power grid company where the seller's units are dispatched and the relevant power generation company according to the existing settlement process.

[0065] Buyer's provincial power grid enterprise's reserve purchase cost (buyer's power grid enterprise pays regional power grid costs) = Σ Cleared electricity volume purchased by this grid for each segment × Marginal cleared electricity price for each segment

[0066] The cost of reserve capacity awarded in the bid for generating units (the cost paid by the regional power grid company to the power grid company where the selling unit is located) = Σ[the cleared bid volume of each unit × (the marginal cleared price of each unit - the regional power grid transmission price)]

[0067] The seller's standby settlement cost (the cost paid by the power grid company where the seller's unit is located to the power generation company) = Σ[the executed bid volume of each unit × (the marginal clearing price of each unit - the seller's provincial power grid company's transmission price (including losses) - the regional power grid's transmission price]

[0068] Step 8: After the daytime market closes, begin the next day's intraday market preparation process. Receive updated capacity quotations from market participants, and generate the next day's nationwide intraday available capacity sequence and the next day's intraday reserve price index.

[0069] Step 9: The intraday standby market is organized according to a fixed market cycle. The intraday market is divided into 12 fixed market cycles, each lasting 2 hours. The first market cycle runs from 00:15 to 2:00, and so on. The specific process for one market cycle is as follows:

[0070] Before the opening of the intraday reserve market, the provincial power dispatching agency selects to act as the buyer or seller based on the reserve surplus of its own grid in each time period. This includes the intraday reserve demand capacity declared by the buyer's provincial (municipal) power dispatching agency and the intraday reserve available capacity declared by the seller's provincial (municipal) power dispatching agency.

[0071] The intraday reserve market clearing process is the same as the previous day's reserve market clearing, and will be omitted here.

[0072] Based on the results of the reserve market clearing, the power generation plans of each provincial power grid interconnection line in the region will be adjusted and safety verification will be carried out. The safety verification method is the same as that for the day-ahead reserve market clearing, and will be omitted here.

[0073] Step 10: Based on the clearing prices of the market at different times during the trading day, the cleared electricity from the reserve capacity buyers, and the winning bids for the reserve capacity sellers, daily settlement of reserve costs is conducted. Reserve costs are settled on a daily-to-month basis, the same as the daily reserve cost settlement, and are omitted here.

[0074] Example 2

[0075] This embodiment also provides a regional backup ancillary service transaction system, including:

[0076] The market management module centrally manages and maintains various input data required for market clearing calculations, providing accurate and reliable input data and market models for subsequent ancillary service market clearing calculations. Specifically, the market management module includes market parameter management, market model management, and market data management. Market participants, through market members, engage in market bidding, clearing, and settlement. When functions such as grid security verification involve the grid physical model, market members reflect this through their corresponding physical entities on specific network nodes, and the relevant data is automatically injected into the calculation network. Market parameter management configures and manages market parameters that change with the market or production environment, including market operation control parameters, unit technical parameters, and market operation parameters.

[0077] The reporting and publishing module is used to complete the reporting and publishing of basic data and transaction data for market participants. Specifically, the transaction reporting function includes: reporting of the maximum adjustable capacity under the dispatching criteria for the day-ahead and intraday periods, the capacity of units blocked due to reasons other than the units themselves, the reserved reserve capacity of the units, the capacity blocked due to the units themselves, the buyer's quotation for reserve capacity, the buyer's quotation for reserve capacity, the buyer's reserve demand capacity, and the seller's available reserve capacity. The information publishing function includes: publishing the supply and demand situation of reserve capacity in the day-ahead and intraday markets, the market clearing results, and the market settlement information.

[0078] The transaction management module manages all processes and related input / output data for the day-ahead and intraday standby markets. Specifically, it supports the extension, opening, and closing of day-ahead market sub-processes and restricts reporting functions based on process status; if a process is closed, related reporting functions are disabled. Market clearing-related input / output data supports multi-dimensional graphical displays at the overall overview, province / city, market member, and data unit levels.

[0079] Safety Verification Module: Used for day-ahead and intraday generation plan safety verification considering the results of reserve market transactions. Specifically, it includes initial plan safety verification, safety verification considering reserve market transaction results, and unit output optimization. Unit output optimization supports SCED (Self-Controlled Grid Optimization), which finds feasible solutions that meet grid safety constraints by adjusting the output of adjustable units. The optimization algorithm is described below.

[0080] The optimization objectives include two parts: minimizing deviation costs and minimizing the costs of changes in provincial connecting line access points, as shown below:

[0081]

[0082] In the formula: Δ i，t The cost of the output deviation of unit i at time t; represents the incremental input and output (i.e., the change in the transmission rate) of the provincial power grid during time period t, respectively, and is the decision variable; M is the penalty coefficient, which is used to ensure that the transmission rate plans of each province remain unchanged as much as possible.

[0083]

[0084] In the formula: p i，t The output of unit i after adjustment at time t; Let be the initial output of unit i at time t; This represents the positive adjustment of unit i at time t; Let be the negative adjustment amount of unit i at time t. To facilitate the control and allocation strategy for deviation, a segmented adjustment cost for the unit deviation adjustment amount is introduced. As the amount of change increases, the adjustment cost also increases.

[0085] Market Settlement Module: This module facilitates reserve market settlements between reserve capacity buyers, sellers, and transmission providers, providing comprehensive settlement displays and various settlement analysis reports. The module settles regional ancillary service fees and power plant fees according to settlement rules and compiles transaction-related information in report form.

[0086] Data Interaction Module: This module enables data interaction with horizontal systems and vertical data interaction with upper and lower level dispatchers. Specifically, it interacts with the planning system to exchange production data such as day-ahead power generation plans and dispatch-based load forecasts, and distributes and executes clearing results. It also interacts with provincial dispatching agencies through standard format files to complete data submission and publication.

[0087] The transaction statistics and analysis module is used to perform statistical analysis on each clearing period from a price perspective, considering constraints such as ramp-up and slide-down, and analyzing the rationality of the winning bid results. It provides functions for generating daily transaction reports and summaries, forming a daily transaction analysis summary report.

[0088] Information Disclosure Module: This module is used to release information to market participants regarding the reserve supply and demand situation of the previous day's pre-day market and the intraday market of the previous day, as well as market clearing results and market settlement information. Disclosed information is categorized into public and private information based on confidentiality levels; private information is released to relevant market participants only.

[0089] Market Announcement Module: Used by market operators to publish transaction notices, policies, regulations, and other announcements online. Announcements are transmitted across systems via message file push, supporting attachment uploads and push notifications.

[0090] Market Entity Approval Module: This module is used by market operators to manage market members online and approve applications from provincial dispatching agencies related to market participation, exit, and parameter maintenance. The provincial power grid dispatching agency initiates applications to the market operator through an approval process. Once approved, the market operator updates the entity's information synchronously.

[0091] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0092] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0093] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0094] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0095] The above description is only a preferred embodiment of the present invention. It should be noted that for those skilled in the art, several improvements and modifications can be made without departing from the technical principles of the present invention, and these improvements and modifications should also be considered within the scope of protection of the present invention.

Claims

1. A method for trading regional backup ancillary services, characterized in that, Applied to regional power grid control agencies, including: Based on the pre-completed day-ahead plan for interconnection lines, calculate the reference value for the reserve capacity margin of the provincial power grid for the next day, and distribute it to the dispatching agencies of each provincial power grid. Based on the day-ahead reserve demand and available capacity declared by the provincial power grid dispatching agency, and combined with the day-ahead reserve capacity seller quotations declared by power generation enterprises, the reserve market is cleared, the day-ahead plan of the interconnection line is updated and issued, and the day-ahead reserve market clearing results are released to market participants; After verifying the rationality and safety of the daytime available capacity of generating units, a sequence of generating units available for intraday adjustment across the entire network for the next day is formed, and the intraday standby price index and the sequence of generating units available for intraday adjustment across the entire network for the next day are released to market participants. Receive rolling reports of the initial daily power generation plan cycle of the provincial power grid; Based on the daily reserve demand and available capacity declared by the provincial power grid dispatching agency, and combined with the daily reserve capacity seller quotations declared by power generation enterprises, the reserve market is cleared, the daily plan for interconnection lines is updated and issued, and the results of the daily reserve market clearing are released to market participants. Among them, the provincial power grid dispatching agency is used for: Select the day-ahead reserve market buyer and seller based on the next-day reserve capacity margin reference value of the provincial power grid, and declare the day-ahead reserve ancillary service demand capacity and the available capacity of the grid units for sale; Select the buyer and seller in the intraday standby market based on the standby capacity situation during the intraday trading session of this network, and declare the intraday standby ancillary service demand capacity and the available capacity of the network's generating units for sale; After the daytime reserve market closes, the intraday reserve market enters the overnight preparation phase. This overnight preparation phase generates the next day's nationwide intraday available capacity sequence and the next day's intraday reserve price index, including: The available capacity sequence for the entire network within a day is as follows: The capacity of each tier declared by the generator sets that can participate in the market unit combination is determined by deducting the capacity blocked due to the generator set's own reasons, the capacity blocked due to reasons other than the generator set, the planned output, and the reserve capacity reserved by the dispatching agency. The capacity sequence is formed by sorting the seller's intraday landing price from low to high. Intraday Reserve Price Index: This refers to the intraday price quoted by the seller of the last tier of generating unit capacity in the intraday reserve market sequence that meets the calculated reserve demand of the entire network for the next day. It is used to reflect the tightness of supply and demand for intraday reserve capacity for the next day. The estimated reserve demand for the entire network is the sum of the maximum and minimum values ​​of the spinning reserve capacity of each provincial power grid in the monthly power production and maintenance plan issued by the regional power grid, and shall not exceed the total daily capacity of the entire network's upgraded generating units. The clearing of the reserve market adopts a segmented marginal price clearing principle, including: The sellers are ranked from lowest to highest based on their bid price to form a seller sequence. The seller's bid price = seller's bid price + seller's provincial power grid company transmission price + regional power grid company electricity transmission price. The seller sequence is segmented based on the buyer's quotation. The seller's reserve capacity within each segment is allocated according to the proportion of each buyer's demand capacity, provided that the seller's final quotation does not exceed the quotation of each buyer. The marginal clearing price for each segment is the seller's bid for the capacity of the last winning unit in each segment. If the sellers' bids are the same, the last winning unit will be determined in the following order: hydropower units, electrochemical energy storage power stations, gas turbine units, ultra-low emission large-capacity coal-fired units, ultra-low emission small-capacity coal-fired units, non-ultra-low emission large-capacity coal-fired units, and non-ultra-low emission small-capacity coal-fired units. For units with the same bid and priority, the winning bid will be allocated according to the proportion of the declared power. If a seller's unit cannot be sold due to constraints such as grid safety conditions or unit load change rate, the unit will be replaced by the next ranked unit. This also includes: adjusting the generation plans of each provincial power grid interconnection point within the region based on the reserve market clearing results and conducting safety verification; if the safety verification fails, the reserve market clearing will be carried out again; if the safety verification passes, the adjusted interconnection point generation plans will be issued to each provincial power grid dispatching agency, and the clearing results will be published to each market participant; the safety verification includes initial plan safety verification, safety verification considering reserve market transaction results, and unit output optimization; the optimization objectives include minimizing deviation costs and minimizing the cost of changes in provincial interconnection points, as shown below: In the formula: Δ i，t The cost of the output deviation of unit i at time t; These represent the incremental input and output of the provincial power grid during time period t, respectively; M is the penalty coefficient. In the formula: p i，t The output of unit i after adjustment at time t; Let be the initial output of unit i at time t; This represents the positive adjustment of unit i at time t; This represents the negative adjustment of unit i at time t.

2. The regional backup ancillary service transaction method according to claim 1, characterized in that: The reference value for the reserve capacity margin of the provincial power grid for the next day is calculated based on the pre-completed day-ahead plan for the interconnection lines. The calculation formula is as follows: Reference value for the reserve capacity margin of the provincial power grid the next day = the maximum adjustable capacity of the provincial power grid according to the dispatching caliber the next day + the planned interconnection line of the provincial power grid the next day – the predicted load of the provincial power grid according to the dispatching caliber the next day.

3. A regional backup ancillary service transaction system, employing the regional backup ancillary service transaction method as described in claim 1, characterized in that, include: Market Management: This is used for centralized management and maintenance of various input data required for market clearing calculations, providing accurate and reliable input data and market models for subsequent backup auxiliary service market clearing calculations, including market model management, market parameter management, and market data management; The reporting and publishing module is used to complete the reporting and publishing of basic data and transaction data to market participants. Transaction Management Module: Used to manage various processes and related input / output data in the day-ahead and intraday standby markets; Safety verification module: Used for day-ahead and intraday power generation plan safety verification considering the results of standby market transactions; Market settlement module: Used for settlement of standby capacity purchasers, sellers, and transmission parties in the standby market, providing comprehensive settlement display and various settlement analysis reports; Data interaction module: used to realize data interaction with horizontal systems, as well as vertical data interaction with upper and lower level schedulers.

4. The regional backup ancillary service transaction system according to claim 3, characterized in that, The system also includes a transaction statistics and analysis module: used to perform statistical analysis on each clearing period from a price perspective, taking into account constraints such as ramp-up and slide-down, and to analyze the rationality of the clearing results.

5. The regional backup ancillary service transaction system according to claim 3, characterized in that, The system also includes an information disclosure module, which is used to release to market participants the standby supply and demand situation of the previous day's market and the intraday market of the previous day, market clearing results and market settlement information.

6. The regional backup ancillary service transaction system according to claim 3, characterized in that, The system also includes a market announcement module, which is used by market operators to publish transaction notices, policy and regulatory announcements, and other information online.

7. The regional backup ancillary service transaction system according to claim 3, characterized in that, The system also includes a market entity approval module: used by market operators to manage market members online and approve applications from provincial dispatch agencies related to market entities' participation in the market, exit from the market, and maintenance parameters.

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