A method and system for identifying and analyzing greenhouse gas emission sources in power grids

Abstract

The present invention discloses a method for identifying and analyzing greenhouse gas emission sources in a power grid. By drawing an emission source information distribution map for the power grid indoors and estimating the emission value for each emission source, the monitoring area is divided by ensuring that the cumulative emission value does not exceed a preset upper limit, thereby ensuring that the detection equipment, computing power, and staff workload are within an appropriate range. By drawing an emission curve within the monitoring area and comparing the emission curve with the planned curve, an error is obtained, thereby determining whether the emission meets the requirements. Importantly, real-time monitoring of greenhouse gas emissions from the power grid is achieved, providing data support for the management and control of greenhouse gas emissions, and adopting a block monitoring method in the analysis process, which facilitates regional management and analysis, and facilitates the division of the responsible areas of corresponding staff.

Description

Technical Field

[0001] The present invention relates to the field of power grid detection technology, and in particular to a method and system for identifying and analyzing greenhouse gas emission sources in a power grid. Background Art

[0002] The power industry is a vital sector for economic development. As core enterprises within the power industry, power grid companies are actively responding to climate change, promoting energy conservation and emission reduction efforts within the grid, and fostering the development of a low-carbon economy. Greenhouse gas emissions from power grid companies include carbon dioxide emissions caused by transmission and distribution losses, as well as emissions generated during the repair and decommissioning of sulfur hexafluoride equipment. To scientifically implement energy conservation and emission reduction measures for the power grid, a timely and comprehensive understanding of the corresponding emission information is necessary. Only by understanding the corresponding emission data can appropriate management measures be formulated. Therefore, to address this issue, the present invention provides a power grid greenhouse gas emission source identification and analysis system.

[0003] For example, publication number CN114062759A discloses a carbon emission monitoring and verification system and method, including an electric power data acquisition device, a positioning device, an edge computing gateway, and a cloud metering platform. The data acquisition device is respectively connected to the positioning device and the edge computing gateway in communication, and the edge computing gateway is connected to the cloud metering platform in communication. The present invention combines an electric power data acquisition terminal device with a carbon emission algorithm, and automatically collects the current value, voltage value, and power factor value in the electric variable parameters of the power circuit through the electric power data acquisition device, calculates the active power value and the electric power carbon emission value, and realizes the online real-time dynamic monitoring, diagnosis, and prediction and accounting capabilities of electric power data and electric power carbon emission management, providing a digital solution for the comprehensive demand for low-carbonization of electricity. This solution combines the electric power acquisition terminal device with the carbon emission algorithm. This method has a large amount of calculation and poor positioning capability. Summary of the Invention

[0004] The technical problem to be solved by the present invention is how to quickly identify emission sources.

[0005] The present invention solves the above technical problems through the following technical means:

[0006] A method for identifying and analyzing greenhouse gas emission sources in a power grid comprises the following steps:

[0007] S01. Draw a grid distribution information map; obtain a grid greenhouse gas emission list, identify the grid distribution information map based on the emission source list, remove non-emission sources, and obtain an emission source information distribution map;

[0008] S02. Estimating the emission amounts of the emission sources in the emission source information distribution map and marking them;

[0009] S03. The emission sources in the emission source information distribution map are merged according to the following method to obtain multiple monitoring areas;

[0010] S031. Dynamically number each emission source in the emission source information distribution map; and set the regional emission limit value SVP;

[0011] S032. Obtain the numbering sequence of the emission source information distribution map to obtain the first sequence;

[0012] S033. Obtain the emission amount corresponding to the first number in the first sequence as the initial merge value HB0. Obtain the emission amount corresponding to the second number in the first sequence P1 and calculate the first merged value HB1 = HB0 + P1. If HB1 > SVP, do not merge the emission source corresponding to P1, terminate the merge process, and obtain a merged area containing the emission source corresponding to the first number. If HB1 ≤ SVP, update the numbering sequence of the remaining emission sources to obtain a second sequence, and proceed to step S034.

[0013] S034. Identify the emission amount P2 corresponding to the first number in the second sequence, and calculate the second merged value HB2 = HB1 + P2. When HB2 > SVP, do not merge the emission sources corresponding to P2, end the merging process, and obtain a merged area containing the emission sources corresponding to the first and second numbers in the first sequence; when HB2 ≤ SVP, update the numbering order of the emission sources to obtain the third sequence, and so on, until the Nth merged value HB is calculated. N =HB N-1 +P N >SVP, no P N The corresponding emission sources are merged, the merging process is completed, and the merged area is obtained; each merged area is a monitoring area;

[0014] S04. Identify the emission sources in each monitoring area, match the corresponding emission value calculation formula for each emission source, and calculate the emission value corresponding to each emission source in the monitoring area in real time according to the matched emission value calculation formula. The emission source is marked as Fi, where i = 1, 2, ..., n, and n is a positive integer. The emission value of the monitoring area is

[0015] S05. Establish a corresponding regional monitoring curve based on the calculated emission value of the monitoring area, identify the planned difference in the regional monitoring curve, and compare the identified planned difference with the threshold interval in real time to obtain a detection result.

[0016] The present invention maps the distribution of emission sources within the power grid, estimates the emission values ​​for each source, and divides the monitoring area by ensuring that the cumulative emission values ​​do not exceed a preset upper limit. This ensures that the detection equipment, computing power, and staff workload are within an appropriate range. By drawing an emission curve within the monitoring area and comparing the emission curve with the planned curve, the error is obtained, thereby determining whether the emissions meet the requirements. Importantly, this achieves real-time monitoring of greenhouse gas emissions from the power grid, providing data support for greenhouse gas emission control. The use of a block-based monitoring approach during the analysis process facilitates regional management and analysis, and facilitates the division of the responsible areas of corresponding staff.

[0017] Furthermore, the estimated emissions in step S02 are evaluated based on historical statistical information.

[0018] Furthermore, the emission value calculation formula in step S04 includes:

[0019] The first formula is: PF = (SBr - SBh) × GWP × β, where SBr is the sulfur hexafluoride capacity of the retired equipment, SBh is the actual sulfur hexafluoride recovery amount of the retired equipment, GWP is the greenhouse gas potential of sulfur hexafluoride, and β is the regional dynamic conversion coefficient;

[0020] The first formula is used to calculate the decommissioning process of equipment using hexafluoride;

[0021] The second formula is: PF = (TYr - TYh) × GWP × β, where TYr is the sulfur hexafluoride capacity of the repair equipment and TYh is the actual sulfur hexafluoride recovered by the repair equipment;

[0022] The second formula is used to calculate the repair process of equipment using hexafluoride;

[0023] The third formula is: PF = SL × EF × β, where SL is the amount of electricity lost in transmission and distribution, and EF is the annual average power supply emission factor of the regional power grid;

[0024] The third formula is used to calculate the transmission loss process.

[0025] Furthermore, the method for drawing the monitoring curve in step S05 is:

[0026] A first curve is drawn according to the calculated emission value of the monitoring area, a corresponding planned curve is generated according to the drawn first curve, the first curve and the planned curve are integrated into a regional monitoring curve, and the difference between the first curve and the planned curve is dynamically calculated and displayed, marked as the planned difference.

[0027] Corresponding to the above method, the present invention further provides a system for identifying and analyzing greenhouse gas emission sources in a power grid, comprising:

[0028] An emission source information distribution map drawing module is used to draw a power grid distribution information map; obtain a power grid greenhouse gas emission list, identify the power grid distribution information map based on the emission source list, remove non-emission sources, and obtain an emission source information distribution map;

[0029] a marking module, configured to estimate the emission amount of the emission sources in the emission source information distribution map and mark them;

[0030] A monitoring area division module is used to merge the emission sources in the emission source information distribution map according to the following method to obtain multiple monitoring areas;

[0031] S031. Dynamically number each emission source in the emission source information distribution map; and set the regional emission limit value SVP;

[0032] S032. Obtain the numbering sequence of the emission source information distribution map to obtain the first sequence;

[0033] S033. Obtain the emission amount corresponding to the first number in the first sequence as the initial merge value HB0. Obtain the emission amount corresponding to the second number in the first sequence P1 and calculate the first merged value HB1 = HB0 + P1. If HB1 > SVP, do not merge the emission source corresponding to P1, terminate the merge process, and obtain a merged area containing the emission source corresponding to the first number. If HB1 ≤ SVP, update the numbering sequence of the remaining emission sources to obtain a second sequence, and proceed to step S034.

[0034] S034. Identify the emission amount P2 corresponding to the first number in the second sequence, and calculate the second merged value HB2 = HB1 + P2. When HB2 > SVP, do not merge the emission sources corresponding to P2, end the merging process, and obtain a merged area containing the emission sources corresponding to the first and second numbers in the first sequence; when HB2 ≤ SVP, update the numbering order of the emission sources to obtain the third sequence, and so on, until the Nth merged value HB is calculated. N =HB N-1 +P N >SVP, no P N The corresponding emission sources are merged, the merging process is completed, and the merged area is obtained; each merged area is a monitoring area;

[0035] The emission value calculation module identifies the emission sources in each monitoring area, matches the corresponding emission value calculation formula for each emission source, and calculates the emission value corresponding to each emission source in the monitoring area in real time according to the matched emission value calculation formula. The emission source is marked as Fi, where i = 1, 2, ..., n, and n is a positive integer. The emission value of the monitoring area is

[0036] The monitoring result calculation module establishes a corresponding regional monitoring curve based on the calculated emission value of the monitoring area, identifies the planned difference in the regional monitoring curve, compares the identified planned difference with the threshold interval in real time, and obtains the detection result.

[0037] Furthermore, the estimated emissions in the marking module are evaluated based on historical statistical information.

[0038] Furthermore, the emission value calculation formula in step S04 includes:

[0039] The first formula is: PF = (SBr - SBh) × GWP × β, where SBr is the sulfur hexafluoride capacity of the retired equipment, SBh is the actual sulfur hexafluoride recovery amount of the retired equipment, GWP is the greenhouse gas potential of sulfur hexafluoride, and β is the regional dynamic conversion coefficient;

[0040] The first formula is used to calculate the decommissioning process of equipment using hexafluoride;

[0041] The second formula is: PF = (TYr - TYh) × GWP × β, where TYr is the sulfur hexafluoride capacity of the repair equipment and TYh is the actual sulfur hexafluoride recovered by the repair equipment;

[0042] The second formula is used to calculate the repair process of equipment using hexafluoride;

[0043] The third formula is: PF = SL × EF × β, where SL is the amount of electricity lost in transmission and distribution, and EF is the annual average power supply emission factor of the regional power grid;

[0044] The third formula is used to calculate the transmission loss process.

[0045] Furthermore, the method for drawing the monitoring curve in the emission value calculation module is:

[0046] A first curve is drawn according to the calculated emission value of the monitoring area, a corresponding planned curve is generated according to the drawn first curve, the first curve and the planned curve are integrated into a regional monitoring curve, and the difference between the first curve and the planned curve is dynamically calculated and displayed, marked as the planned difference.

[0047] The present invention also provides a processing device, comprising at least one processor and at least one memory communicatively connected to the processor, wherein: the memory stores program instructions that can be executed by the processor, and the processor can execute the above method by calling the program instructions.

[0048] The present invention also provides a computer-readable storage medium, characterized in that the computer-readable storage medium stores computer instructions, and the computer instructions enable the computer to execute the above method.

[0049] The advantages of the present invention are:

[0050] The present invention draws an emission source information distribution map for the power grid indoors, estimates the emission value for each emission source, and divides the monitoring area by ensuring that the cumulative emission values ​​do not exceed a preset upper limit, thereby ensuring that the detection equipment, computing power, staff workload, etc. are within an appropriate range. More importantly, it realizes real-time monitoring of greenhouse gas emissions from the power grid, provides data support for the management and control of greenhouse gas emissions, and adopts a block monitoring method in the analysis process, which facilitates area management and analysis, and is also convenient for dividing the responsible areas of corresponding staff. BRIEF DESCRIPTION OF THE DRAWINGS

[0051] Figure 1 4 is a flowchart of a method for identifying and analyzing greenhouse gas emission sources in a power grid according to an embodiment of the present invention. DETAILED DESCRIPTION

[0052] To make the objectives, technical solutions, and advantages of the embodiments of the present invention more clear, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. All other embodiments obtained by ordinary technicians in this field based on the embodiments of the present invention without making any creative efforts shall fall within the scope of protection of the present invention.

[0053] like Figure 1 As shown, a method for identifying and analyzing greenhouse gas emission sources in a power grid includes the following steps:

[0054] Step 1. Draw a power grid distribution information map. The power grid distribution information map includes corresponding power grid distribution information, various equipment information, node information, and other information that can be obtained through existing methods. Obtain a power grid greenhouse gas emission list, that is, a published list of sources that can generate greenhouse gases in the existing power grid, such as sulfur hexafluoride emissions generated during the repair and decommissioning of sulfur hexafluoride equipment, transmission losses, etc.; establish a corresponding target recognition model based on the power grid greenhouse gas emission list, identify and mark the greenhouse gas emission sources of the power grid distribution information map through the target recognition model, organize the greenhouse gas emission sources of the power grid distribution information map, and obtain an emission source information distribution map.

[0055] Step 2: Identify the greenhouse gas emission sources in the power grid distribution information map, mark them accordingly, and mark the corresponding estimated emissions. The estimated emissions are estimated based on the specific information of the corresponding greenhouse gas emission sources. The corresponding emissions can be evaluated through various existing historical statistical information. For example, for a section of transmission line, its transmission loss can be calculated based on its historical collection data, and then its corresponding emissions can be evaluated. Specifically, the target recognition model is set up based on the CNN network or the DNN network, and the corresponding training set is established manually for training. The target recognition model after successful training is used for identification and marking.

[0056] To organize the greenhouse gas emission sources in the power grid distribution information map, we need to treat the transmission line as a single greenhouse gas emission source according to the node, calculate the emissions of this section of the transmission line, and mark them accordingly, because the transmission line needs to be analyzed as a whole to facilitate the subsequent collection of power losses.

[0057] Step 3: Specific methods for power grid monitoring planning include:

[0058] Obtain an emission source information distribution map, identify each emission source in the emission source information distribution map, dynamically number the identified emission sources, merge them according to the numbering sequence, obtain a merged area, and mark the obtained merged area as a monitoring area.

[0059] Dynamic numbering of identified emission sources refers to determining the corresponding merging order based on the location and type of each emission source to avoid missing or confusing emission sources during the merging process. For example, there may be emission sources in other monitoring areas within a monitoring area, and due to the characteristics of the transmission lines, there may be multiple emission sources with the same number. In this case, they need to be merged at the same time. Specifically, a corresponding numbering model is established based on the CNN network or DNN network, and the corresponding training set is set manually for training. After successful training, the numbering model is used for real-time numbering and updating, because after the merger, the merging order of the remaining emission sources may change.

[0060] For example, after the emission source numbered 10 is merged, the emissions of the remaining emission sources are obtained, which refers to the total emissions of all emission sources that can be listed with the same number. The numbers of the remaining emission sources are determined based on the positional relationship and the total emissions in the merged area.

[0061] Methods for merging based on number sequence include:

[0062] Step SA1: Setting the regional emission upper limit value SVP, which is set manually based on actual conditions, such as monitoring capabilities; obtaining the numbering sequence of emission sources to obtain a first sequence;

[0063] Step SA2: Identify the initial merge value HB0, which is the emission corresponding to the first number in the first sequence; obtain the emission corresponding to the second number P1 in the first sequence, and calculate the first merge value HB1 = HB0 + P1; when HB1 > SVP, do not merge the emission source corresponding to P1, end the merge process, and obtain the merged area; when HB1 ≤ SVP, update the emission source number sequence, obtain the second sequence, and proceed to step SA3;

[0064] Step SA3: Identify the emission amount P2 corresponding to the first number in the second sequence, calculate the second merged value HB2 = HB1 + P2, when HB2>SVP, do not merge the emission source corresponding to P2, end the merging process, and obtain the merged area; when HB2≤SVP, update the numbering order of the emission source to obtain the third sequence, and so on, until the Nth merged value HB is calculated N =HB N-1 +P N >SVP, no P N The corresponding emission sources are merged, the merging process is ended, and the merged area is obtained.

[0065] Step 4: The specific methods for data monitoring in the monitoring area include:

[0066] Identify each emission source in the monitoring area, match the corresponding emission value calculation formula for each emission source, and calculate the emission value corresponding to each emission source in the monitoring area in real time according to the matched emission value calculation formula. Mark the emission source as Fi, where i = 1, 2, ..., n, and n is a positive integer. The emission value of the monitoring area is According to the calculated emission values ​​of the monitoring area, a corresponding regional monitoring curve is established, the planned difference in the regional monitoring curve is identified, and the identified planned difference is compared with the threshold interval in real time. The threshold interval is set manually. When the planned difference is within the threshold interval, the corresponding data summary statistics are performed, and the data items that need to be counted are set manually according to the actual situation; when the planned difference is not within the threshold interval, a corresponding mark is made in the regional monitoring curve, the cause analysis is performed, and the corresponding data summary statistics are performed.

[0067] The emission value calculation formula includes a first formula, a second formula, and a third formula;

[0068] The first formula is: PF = (SBr - SBh) × GWP × β, where SBr is the sulfur hexafluoride capacity of the retired equipment, SBh is the actual sulfur hexafluoride recovery amount of the retired equipment, GWP is the greenhouse gas potential of sulfur hexafluoride, and β is the regional dynamic conversion coefficient;

[0069] The first formula is used to calculate the decommissioning process of equipment using hexafluoride.

[0070] The second formula is: PF = (TYr - TYh) × GWP × β, where TYr is the sulfur hexafluoride capacity of the repair equipment and TYh is the actual sulfur hexafluoride recovered by the repair equipment;

[0071] The second formula is used to calculate the repair process of equipment using hexafluoride.

[0072] The third formula is: PF = SL × EF × β, where SL is the amount of electricity lost in transmission and distribution, and EF is the annual average power supply emission factor of the regional power grid.

[0073] The third formula is used to calculate the transmission loss process.

[0074] The method for determining the regional dynamic conversion coefficient β is to dynamically set it according to the planned goals and historical exceeding standard data of the corresponding area. Specifically, a corresponding coefficient model is established based on the CNN network or the DNN network, and a corresponding training set is established manually for training. The current planned goals and the regional monitoring curves within a period of time are input into the coefficient model after successful training for analysis to obtain the corresponding regional dynamic conversion coefficient β.

[0075] Step 5: The method of establishing a corresponding regional monitoring curve based on the calculated emission value of the monitoring area includes:

[0076] A first curve is drawn according to the calculated emission value of the monitoring area, a corresponding planned curve is generated according to the drawn first curve, the first curve and the planned curve are integrated into a regional monitoring curve, and the difference between the first curve and the planned curve is dynamically calculated and displayed, marked as the planned difference.

[0077] The planned curve is generated based on the first curve. For example, when the hexafluoride dredging equipment is not repaired and retired, the corresponding planned monitoring area emission value is calculated according to the transmission line target plan. When the hexafluoride dredging equipment is repaired and retired, the emission value under the target plan is added to generate the corresponding planned curve. The target plan is set manually according to the actual situation.

[0078] Methods for conducting cause analysis include:

[0079] The first curve segment marked in the identification area monitoring curve is marked as a problem curve, target analysis data corresponding to the problem curve is obtained, and the obtained target analysis data is analyzed to obtain corresponding analysis reasons.

[0080] The target analysis data is composed of multiple data items, and the specific data items are set manually, such as the emission amount of each emission source, the emission value of the monitoring area, the emission value of each emission source, and the corresponding data under the plan.

[0081] The method for analyzing the obtained target analysis data is: establishing a corresponding cause analysis model based on the CNN network or the DNN network, manually establishing a corresponding training set for training, and performing analysis through the cause analysis model after successful training.

[0082] The above formulas are all calculated by removing dimensions and taking their numerical values. The formula is a formula that is closest to the actual situation obtained by collecting a large amount of data and performing software simulation. The preset parameters and preset thresholds in the formula are set by technicians in this field according to actual conditions or obtained by simulating a large amount of data.

[0083] Corresponding to the above method, the present invention further provides a system for identifying and analyzing greenhouse gas emission sources in a power grid, comprising:

[0084] An emission source information distribution map drawing module is used to draw a power grid distribution information map; obtain a power grid greenhouse gas emission list, identify the power grid distribution information map based on the emission source list, remove non-emission sources, and obtain an emission source information distribution map;

[0085] a marking module, configured to estimate the emission amount of the emission sources in the emission source information distribution map and mark them;

[0086] A monitoring area division module is used to merge the emission sources in the emission source information distribution map according to the following method to obtain multiple monitoring areas;

[0087] S031. Dynamically number each emission source in the emission source information distribution map; and set the regional emission limit value SVP;

[0088] S032. Obtain the numbering sequence of the emission source information distribution map to obtain the first sequence;

[0089] S033. Obtain the emission amount corresponding to the first number in the first sequence as the initial merge value HB0. Obtain the emission amount corresponding to the second number in the first sequence P1 and calculate the first merged value HB1 = HB0 + P1. If HB1 > SVP, do not merge the emission source corresponding to P1, terminate the merge process, and obtain a merged area containing the emission source corresponding to the first number. If HB1 ≤ SVP, update the numbering sequence of the remaining emission sources to obtain a second sequence, and proceed to step S034.

[0090] S034. Identify the emission amount P2 corresponding to the first number in the second sequence, and calculate the second merged value HB2 = HB1 + P2. When HB2 > SVP, do not merge the emission sources corresponding to P2, end the merging process, and obtain a merged area containing the emission sources corresponding to the first and second numbers in the first sequence; when HB2 ≤ SVP, update the numbering order of the emission sources to obtain the third sequence, and so on, until the Nth merged value HB is calculated.N =HB N-1 +P N >SVP, no P N The corresponding emission sources are merged, the merging process is completed, and the merged area is obtained; each merged area is a monitoring area;

[0091] The emission value calculation module identifies the emission sources in each monitoring area, matches the corresponding emission value calculation formula for each emission source, and calculates the emission value corresponding to each emission source in the monitoring area in real time according to the matched emission value calculation formula. The emission source is marked as Fi, where i = 1, 2, ..., n, and n is a positive integer. The emission value of the monitoring area is

[0092] The monitoring result calculation module establishes a corresponding regional monitoring curve based on the calculated emission value of the monitoring area, identifies the planned difference in the regional monitoring curve, compares the identified planned difference with the threshold interval in real time, and obtains the detection result.

[0093] Furthermore, the estimated emissions in the marking module are evaluated based on historical statistical information.

[0094] Furthermore, the emission value calculation formula in step S04 includes:

[0095] The first formula is: PF = (SBr - SBh) × GWP × β, where SBr is the sulfur hexafluoride capacity of the retired equipment, SBh is the actual sulfur hexafluoride recovery amount of the retired equipment, GWP is the greenhouse gas potential of sulfur hexafluoride, and β is the regional dynamic conversion coefficient;

[0096] The first formula is used to calculate the decommissioning process of equipment using hexafluoride;

[0097] The second formula is: PF = (TYr - TYh) × GWP × β, where TYr is the sulfur hexafluoride capacity of the repair equipment and TYh is the actual sulfur hexafluoride recovered by the repair equipment;

[0098] The second formula is used to calculate the repair process of equipment using hexafluoride;

[0099] The third formula is: PF = SL × EF × β, where SL is the amount of electricity lost in transmission and distribution, and EF is the annual average power supply emission factor of the regional power grid;

[0100] The third formula is used to calculate the transmission loss process.

[0101] Furthermore, the method for drawing the monitoring curve in the emission value calculation module is:

[0102] A first curve is drawn according to the calculated emission value of the monitoring area, a corresponding planned curve is generated according to the drawn first curve, the first curve and the planned curve are integrated into a regional monitoring curve, and the difference between the first curve and the planned curve is dynamically calculated and displayed, marked as the planned difference.

[0103] This embodiment also provides a processing device, including at least one processor and at least one memory communicatively connected to the processor, wherein: the memory stores program instructions that can be executed by the processor, and the processor calls the program instructions to execute the above method.

[0104] This embodiment further provides a computer-readable storage medium, characterized in that the computer-readable storage medium stores computer instructions, and the computer instructions enable the computer to execute the above method.

[0105] The above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit the same. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the various embodiments of the present invention.

Claims

1. A method for identifying and analyzing greenhouse gas emission sources in a power grid, characterized in that: The following steps are involved: S01. Draw a grid distribution information map; obtain a grid greenhouse gas emission list, identify the grid distribution information map based on the emission source list, remove non-emission sources, and obtain an emission source information distribution map; S02. Estimating the emission amounts of the emission sources in the emission source information distribution map and marking them; S03. The emission sources in the emission source information distribution map are merged according to the following method to obtain multiple monitoring areas; S031. Dynamically number each emission source in the emission source information distribution map; and set the regional emission limit value SVP; S032. Obtain the numbering sequence of the emission source information distribution map to obtain the first sequence; S033. Obtain the emission amount corresponding to the first number in the first sequence as the initial merge value HB0. Obtain the emission amount corresponding to the second number in the first sequence P1 and calculate the first merged value HB1 = HB0 + P1. If HB1 > SVP, do not merge the emission source corresponding to P1, terminate the merge process, and obtain a merged area containing the emission source corresponding to the first number. If HB1 ≤ SVP, update the numbering sequence of the remaining emission sources to obtain a second sequence, and proceed to step S034. S034. Identify the emission amount P2 corresponding to the first number in the second sequence, and calculate the second merged value HB2 = HB1 + P2. When HB2 > SVP, do not merge the emission sources corresponding to P2, end the merging process, and obtain a merged area containing the emission sources corresponding to the first and second numbers in the first sequence; when HB2 ≤ SVP, update the numbering order of the emission sources to obtain the third sequence, and so on, until the Nth merged value HB is calculated. N =HB N-1 +P N >SVP, no P N The corresponding emission sources are merged, the merging process is completed, and the merged area is obtained; each merged area is a monitoring area; S04. Identify the emission sources in each monitoring area, match the corresponding emission value calculation formula for each emission source, and calculate the emission value corresponding to each emission source in the monitoring area in real time according to the matched emission value calculation formula. The emission source is marked as Fi, where i = 1, 2, ..., n, and n is a positive integer. The emission value of the monitoring area is PFi represents the emission value of the i-th emission source; the emission value calculation formula in step S04 is include: The first formula is: PF = (SBr - SBh) × GWP × β, where SBr is the sulfur hexafluoride capacity of the retired equipment, SBh is the actual sulfur hexafluoride recovery amount of the retired equipment, GWP is the greenhouse gas potential of sulfur hexafluoride, and β is the regional dynamic conversion coefficient; The first formula is used to calculate the decommissioning process of equipment using hexafluoride; The second formula is: PF = (TYr - TYh) × GWP × β, where TYr is the sulfur hexafluoride capacity of the repair equipment and TYh is the actual sulfur hexafluoride recovered by the repair equipment; The second formula is used to calculate the repair process of equipment using hexafluoride; The third formula is: PF = SL × EF × β, where SL is the amount of electricity lost in transmission and distribution, and EF is the annual average power supply emission factor of the regional power grid; The third formula is used to calculate the transmission loss process; S05. Establish a corresponding regional monitoring curve based on the calculated emission value of the monitoring area, identify the planned difference in the regional monitoring curve, and compare the identified planned difference with the threshold interval in real time to obtain a detection result.

2. A method for identifying and analyzing greenhouse gas emission sources in a power grid according to claim 1, characterized in that: In step S02, the estimated emission amount is evaluated based on historical statistical information.

3. The method for identifying and analyzing greenhouse gas emission sources in a power grid according to claim 1, characterized in that: The method for drawing the monitoring curve in step S05 is: A first curve is drawn according to the calculated emission value of the monitoring area, a corresponding planned curve is generated according to the drawn first curve, the first curve and the planned curve are integrated into a regional monitoring curve, and the difference between the first curve and the planned curve is dynamically calculated and displayed, marked as the planned difference.

4. A power grid greenhouse gas emission source identification and analysis system, characterized in that: include: An emission source information distribution map drawing module is used to draw a power grid distribution information map; obtain a power grid greenhouse gas emission list, identify the power grid distribution information map based on the emission source list, remove non-emission sources, and obtain an emission source information distribution map; a marking module, configured to estimate the emission amount of the emission sources in the emission source information distribution map and mark them; A monitoring area division module is used to merge the emission sources in the emission source information distribution map according to the following method to obtain multiple monitoring areas; S031. Dynamically number each emission source in the emission source information distribution map; and set the regional emission limit value SVP; S032. Obtain the numbering sequence of the emission source information distribution map to obtain the first sequence; S033. Obtain the emission amount corresponding to the first number in the first sequence as the initial merge value HB0. Obtain the emission amount corresponding to the second number in the first sequence P1 and calculate the first merged value HB1 = HB0 + P1. If HB1 > SVP, do not merge the emission source corresponding to P1, terminate the merge process, and obtain a merged area containing the emission source corresponding to the first number. If HB1 ≤ SVP, update the numbering sequence of the remaining emission sources to obtain a second sequence, and proceed to step S034. S034. Identify the emission amount P2 corresponding to the first number in the second sequence, and calculate the second merged value HB2 = HB1 + P2. When HB2 > SVP, do not merge the emission sources corresponding to P2, end the merging process, and obtain a merged area containing the emission sources corresponding to the first and second numbers in the first sequence; when HB2 ≤ SVP, update the numbering order of the emission sources to obtain the third sequence, and so on, until the Nth merged value HB is calculated. N =HB N-1 +P N >SVP, no P N The corresponding emission sources are merged, the merging process is completed, and the merged area is obtained; each merged area is a monitoring area; The emission value calculation module identifies the emission sources in each monitoring area, matches the corresponding emission value calculation formula for each emission source, and calculates the emission value corresponding to each emission source in the monitoring area in real time according to the matched emission value calculation formula. The emission source is marked as Fi, where i = 1, 2, ..., n, and n is a positive integer. The emission value of the monitoring area is PFi represents the emission value of the i-th emission source; Emission value calculation formula include: The first formula is: PF = (SBr - SBh) × GWP × β, where SBr is the sulfur hexafluoride capacity of the retired equipment, SBh is the actual sulfur hexafluoride recovery amount of the retired equipment, GWP is the greenhouse gas potential of sulfur hexafluoride, and β is the regional dynamic conversion coefficient; The first formula is used to calculate the decommissioning process of equipment using hexafluoride; The second formula is: PF = (TYr - TYh) × GWP × β, where TYr is the sulfur hexafluoride capacity of the repair equipment and TYh is the actual sulfur hexafluoride recovered by the repair equipment; The second formula is used to calculate the repair process of equipment using hexafluoride; The third formula is: PF = SL × EF × β, where SL is the amount of electricity lost in transmission and distribution, and EF is the annual average power supply emission factor of the regional power grid; The third formula is used to calculate the transmission loss process; The monitoring result calculation module establishes a corresponding regional monitoring curve based on the calculated emission value of the monitoring area, identifies the planned difference in the regional monitoring curve, compares the identified planned difference with the threshold interval in real time, and obtains the detection result.

5. A power grid greenhouse gas emission source identification and analysis system according to claim 4, characterized in that: The estimated emissions in the marking module are evaluated based on historical statistical information.

6. A power grid greenhouse gas emission source identification and analysis system according to claim 4, characterized in that: The method for drawing the monitoring curve in the emission value calculation module is: A first curve is drawn according to the calculated emission value of the monitoring area, a corresponding planned curve is generated according to the drawn first curve, the first curve and the planned curve are integrated into a regional monitoring curve, and the difference between the first curve and the planned curve is dynamically calculated and displayed, marked as the planned difference.

7. A processing device, characterized in that: The method comprises at least one processor and at least one memory in communication with the processor, wherein the memory stores program instructions executable by the processor, and the processor calls the program instructions to execute the method according to any one of claims 1 to 3.

8. A computer-readable storage medium, characterized in that The computer-readable storage medium stores computer instructions, and the computer instructions enable the computer to execute the method according to any one of claims 1 to 3.

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