Power system carbon emission metering method and device, computer equipment and storage medium

Abstract

The embodiment of the invention provides a power system carbon emission metering method and device, computer equipment and a storage medium. The power system comprises a transformer area, the transformer area comprises at least one user node, and the method comprises the following steps: acquiring the line loss rate of the transformer area; obtaining a dynamic carbon emission factor of each user node in the transformer area; the product of the dynamic carbon emission factor of any user node and the electricity utilization power of the user node is used as the electricity utilization indirect carbon emission of the user node; according to the line loss power of the transformer area and the dynamic carbon emission factor of each user node, the line loss indirect carbon emission of the transformer area is determined, and the line loss power of the transformer area is determined through the average power of the user nodes and the line loss rate of the transformer area; and according to the electricity utilization indirect carbon emission of each user node and the line loss indirect carbon emission of the transformer area, the transformer area carbon emission of the transformer area is determined, so that the comprehensiveness and the accuracy of carbon emission metering of an electric power system can be improved during carbon emission analysis.

Description

Technical Field

[0001] The embodiments of the present specification relate to the field of computer technology, and specifically to a method, apparatus, computer equipment and storage medium for measuring carbon emissions in a power system. Background Art

[0002] In the power system, carbon emission analysis can usually be combined with power system flow calculation to more comprehensively reveal the characteristics and laws of carbon emissions in the power system. Carbon emission flow is a virtual flow that exists in dependence on the power system flow. It is used to characterize the virtual network flow formed by the carbon emissions of maintaining any branch flow in the power system. Intuitively, it is equivalent to adding a carbon emission label to each branch flow, so as to study the impact of the difference in electricity consumption of users on each branch on carbon emissions.

[0003] However, when conducting carbon emission analysis in related technologies, it is often difficult to reflect the carbon emissions that change with the load of user nodes in the power system. Therefore, there is an urgent need to provide a power system carbon emission measurement method to improve the comprehensiveness and accuracy of power system carbon emission measurement. Summary of the invention

[0004] In view of this, multiple embodiments of this specification are dedicated to providing a method, apparatus, computer equipment and storage medium for measuring carbon emissions from a power system to improve the comprehensiveness and accuracy of measuring carbon emissions from a power system.

[0005] An embodiment of the present specification provides a method for measuring carbon emissions in an electric power system, wherein the electric power system includes a substation, and the substation includes at least one user node. The method includes: obtaining a line loss rate of the substation at a target time; obtaining a dynamic carbon emission factor of each user node in the substation at the target time, wherein the dynamic carbon emission factor is determined based on the carbon emission measurement parameters at the target time; for any user node, taking the product of the dynamic carbon emission factor of the user node at the target time and the power consumption of the user node at the target time as the indirect carbon emissions from power consumption of the user node at the target time; determining the line loss indirect carbon emissions of the substation according to the line loss power of the substation at the target time and the dynamic carbon emission factor of each user node, wherein the line loss power of the substation at the target time is determined by the average power of the user nodes and the line loss rate of the substation at the target time; determining the substation carbon emissions at the target time according to the indirect carbon emissions from power consumption of each user node and the line loss indirect carbon emissions of the substation.

[0006] In some embodiments, obtaining the line loss rate of the substation at the target time includes: obtaining the total power consumption of the substation at the target time; obtaining the user node power consumption of each user node in the substation at the target time; and determining the line loss rate of the substation at the target time based on the total power consumption and the power consumption of each user node.

[0007] In some embodiments, obtaining the dynamic carbon emission factor of each user node in the substation at the target time includes: obtaining the carbon emission metering parameters, wherein the carbon emission metering parameters include a preset static carbon emission factor of each user node, an electricity trading volume influence weight, the total electricity trading volume of the substation at the target time, the node electricity trading volume of each user node at the target time, and the power factor of each user node; determining the dynamic carbon emission factor of each user node at the target time based on the static carbon emission factor, the electricity trading volume influence weight, the total electricity trading volume, the node electricity trading volume of each user node, and the power factor of each user node.

[0008] In some embodiments, the dynamic carbon emission factor of the user node at the target time is determined by the following formula:

[0009] in, represents the dynamic carbon emission factor of any user node, represents the static carbon emission factor of any user node, E n represents the node power transaction volume of any user node, E total Indicates the total power transaction volume in the area, PF n Represents the power factor of any user node.

[0010] In some embodiments, the carbon emission measurement parameter further includes a renewable energy ratio, and the dynamic carbon emission factor of the user node at the target time is determined by the following formula:

[0011] in, represents the dynamic carbon emission factor of any user node, represents the static carbon emission factor of any user node, E n represents the node power transaction volume of any user node, E total represents the total electricity trading volume in the area, f n Indicates the proportion of renewable energy in the power source of the station area, PF n Represents the power factor of any user node.

[0012] In some embodiments, the line loss indirect carbon emissions are determined by the following formula:

[0013]

[0014] Among them, F L represents the indirect carbon emissions of line loss in the area, N represents the total number of user nodes in the area, and n represents any user node in the area. represents the dynamic carbon emission factor of any user node; L represents the line loss rate of the station area, P L Indicates the line loss power in the substation area, A user node representing any user node in the station area.

[0015] In some embodiments, the carbon emissions of the station area are determined by the following formula:

[0016] Among them, F total represents the carbon emissions of the region, F L represents the indirect carbon emissions from line losses in the area, N is the total number of user nodes in the area, and F n Represents the indirect carbon emissions from electricity consumption of any user node.

[0017] The embodiment of the present specification provides a carbon emission metering device for an electric power system, wherein the electric power system includes a substation, and the substation includes at least one user node. The device includes: a substation line loss rate acquisition module, which is used to acquire the line loss rate of the substation at a target time; a carbon emission factor acquisition module, which is used to acquire the dynamic carbon emission factor of each user node in the substation at the target time, wherein the dynamic carbon emission factor is determined based on the carbon emission metering parameters at the target time; a first carbon emission amount determination module, which is used to determine, for any of the user nodes, the dynamic carbon emission factor of the user node at the target time and the carbon emission factor of the user node at the target time. The product of the power consumption at the target moment is used as the indirect carbon emissions from electricity consumption of the user node at the target moment; a second carbon emissions determination module is used to determine the line loss indirect carbon emissions of the substation according to the line loss power of the substation at the target moment and the dynamic carbon emission factor of each of the user nodes, wherein the line loss power of the substation at the target moment is determined by the average power of the user nodes and the line loss rate of the substation at the target moment; the substation carbon emissions determination module is used to determine the substation carbon emissions at the target moment according to the indirect carbon emissions from electricity consumption of each of the user nodes and the line loss indirect carbon emissions of the substation.

[0018] An embodiment of the present specification provides a computer device, including a memory and a processor, wherein the memory stores a computer program, and when the processor executes the computer program, the carbon emission measurement method described in any of the above embodiments is implemented.

[0019] An embodiment of the present specification provides a computer-readable storage medium having a computer program stored thereon. When the computer program is executed by a processor, the carbon emission measurement method described in any of the above embodiments is implemented.

[0020] The multiple implementation methods provided in this specification obtain the line loss rate of the substation at the target time, and the dynamic carbon emission factor determined by each user node in the substation based on the carbon emission measurement parameters at the target time. Then, for any user node, the product of the dynamic carbon emission factor of the user node at the target time and the power consumption of the user node at the target time is used as the indirect carbon emissions of electricity consumption of the user node at the target time. Then, the line loss power of the substation at the target time is determined by the average power of the user node and the line loss rate of the substation at the target time, and the line loss indirect carbon emissions of the substation are determined according to the line loss power of the substation at the target time and the dynamic carbon emission factor of each user node. Then, the carbon emissions of the substation at the target time are determined according to the indirect carbon emissions of electricity consumption of each user node and the line loss indirect carbon emissions of the substation. In this way, when conducting carbon emission analysis, the carbon emissions in the power system that change with the load of the user node can be effectively reflected, thereby improving the comprehensiveness and accuracy of carbon emission measurement of the power system. BRIEF DESCRIPTION OF THE DRAWINGS

[0021] Figure 1 A schematic diagram of a power system provided for an embodiment of this specification;

[0022] Figure 2 A flow chart of a method for measuring carbon emissions in a power system provided in the embodiments of this specification;

[0023] Figure 3 A schematic diagram of a carbon emission metering device for a power system provided for an embodiment of this specification;

[0024] Figure 4 A schematic diagram of a computer device provided for embodiments of the present specification. DETAILED DESCRIPTION

[0025] In order to enable those skilled in the art to better understand the solution of this specification, the technical solution in the implementation of this specification will be clearly and completely described below in conjunction with the drawings in the implementation of this specification. Obviously, the described implementation is only a part of the implementation of this specification, not all of the implementations. Based on the implementation in this specification, all other implementations obtained by ordinary technicians in this field without creative work are within the scope of protection of this specification.

[0026] This specification provides an example scenario for measuring carbon emissions in a power system. Figure 1 , Figure 1Schematic diagram of the power system provided for the implementation of this specification. In this scenario example, the power system 100 may include a power generation side, a distribution side, and a user side. Among them, the power generation side refers to the side where the power generation grid or power plant is located, and the distribution side may refer to the side where the distribution transformer 110 is located. The distribution transformer 110 can reduce the high-voltage transmission on the power generation side to a distribution voltage and transmit it to the user side. The user side, that is, the load side, the user side may include at least one substation 120, any substation 120 may correspond to one or more distribution transformers 110, and any substation 120 may include at least one user node 130.

[0027] In this scenario example, the power system 100 may also include a master station management platform 140, any substation 120 on the user side may be provided with a substation master table 150 and a substation collection terminal 160, and any user node 130 of the substation 120 may be provided with a user table 170. The substation collection terminal 160 may be connected to the master station management platform 140 and the substation master table 150, and the substation collection terminal 160 may be connected to the user table 170 through the substation master table 150, so that the substation collection terminal 160 may interact, upload and send data with the master station management platform 140, the substation master table 150 and the user table 170. Exemplarily, the substation collection terminal 160 may be connected to the master station management platform 140 by wire or wirelessly, for example, a wireless public network connection or a wireless private network connection may be performed. As an example, the station area master table 150 may be disposed in the station area collection terminal 160 , that is, the station area collection terminal 160 may be integrated with the function of the station area master table 150 .

[0028] Specifically, the substation collection terminal 160 of any substation 120 can be set at the gateway of the substation, and the substation collection terminal 160 can measure carbon emissions by obtaining data issued by the master station management platform 140, as well as data collected by the substation master meter 150 and the user meter 170. In this way, in the process of carbon emission measurement, only the parameters of the substation collection terminal 160 can be updated without replacing the substation master meter 150, the user meter 170 and other electricity metering equipment in the substation 120, so that the indirect carbon emissions of electricity consumption of the user nodes 130 on each branch flow in the substation 120, the indirect carbon emissions of line losses, and the substation carbon emissions of the substation 120 can be measured, thereby realizing real-time monitoring, data collection and analysis of the operating status and energy flow of the power generation side, the distribution side and the load side, and being able to comprehensively and accurately measure and evaluate the carbon emissions in the power system.

[0029] Exemplarily, any substation 120 on the load side may include at least one branch, and the user meter 170 may be set on the branch, and the user meter 170 on the branch may collect data from the user node 130 on the branch. As an example, the user node 130 may be an energy storage device, a photovoltaic inverter, a charging pile, and other electrical equipment. Currently, it may also be a lighting user, a power user, a smart home, and the like.

[0030] Exemplarily, the area collection terminal 160 can detect in real time the power usage, energy or energy flow, power load and other data of the area 120 or any user node 130 in the area 120. As an example, the area collection terminal 160 also stores the area topology information of the area 120 to determine the line loss indirect carbon emissions of the area 120.

[0031] This specification provides a method for measuring carbon emissions in a power system. Figure 2 , Figure 2 It is a flowchart of a method for measuring carbon emissions in a power system provided by this embodiment. This embodiment provides method operation steps as shown in the flowchart, but may include more or fewer operation steps based on conventional or non-creative labor. The order of steps listed in the embodiment is only one execution method among many step execution sequences, and does not represent the only execution order. When the actual system or server product is executed, it can be executed in sequence or in parallel according to the method shown in the embodiment (for example, in a parallel processor or multi-threaded processing environment). This carbon emission measurement method can be applied to the substation collection terminal of the power system, specifically Figure 2 As shown, the carbon emission measurement method may include the following steps.

[0032] Step S210: Obtain the line loss rate of the substation at the target time.

[0033] The line loss rate may refer to the percentage of the line loss electricity in the substation at the target time to the total electricity supplied to the substation, wherein the line loss electricity may refer to the lost electricity or energy, and the line loss rate may characterize the degree of energy loss in the substation.

[0034] Step S220: Obtain a dynamic carbon emission factor of each user node in the station area at the target time, wherein the dynamic carbon emission factor is determined based on the carbon emission measurement parameters at the target time.

[0035] The carbon emission measurement parameters may be relevant index parameters that need to be met for carbon emission measurement, or may be the current real-time relevant data of the substation.

[0036] In some cases, the carbon emission factor may refer to the unit carbon emission amount, or in other words, the dynamic carbon emission factor of any user node may refer to the real-time unit carbon emission amount of the user node.

[0037] Step S230: For any user node, the product of the dynamic carbon emission factor of the user node at the target time and the power consumption of the user node at the target time is used as the indirect carbon emission of the user node at the target time.

[0038] Among them, the indirect carbon emissions from electricity consumption at the user node do not occur at the user node, but are the carbon emissions generated by burning fossil energy in the process of producing electricity indirectly due to the needs of the user node.

[0039] Exemplarily, the indirect carbon emissions from electricity consumption can be determined by Formula 1.

[0040]

[0041] Where n represents any user node in the area, F n represents the indirect carbon emissions of electricity consumption of any user node, represents the dynamic carbon emission factor of any user node, P n Indicates the power consumption of any user.

[0042] Step S240: Determine the indirect carbon emissions of the line loss of the area according to the line loss power of the area at the target time and the dynamic carbon emission factor of each user node, wherein the line loss power of the area at the target time is determined by the average power of the user nodes and the line loss rate of the area at the target time.

[0043] Specifically, the average power of user nodes in the substation area can be determined, and then the line loss power of the substation area can be determined based on the line loss rate of the substation area at the target time and the average power of user nodes in the substation area. Then, the line loss indirect carbon emissions of the substation area can be determined based on the line loss power of the substation area and the dynamic carbon emission factor of each user node.

[0044] Step S250: Determine the carbon emissions of the substation at the target time according to the indirect carbon emissions of electricity consumption of each user node and the indirect carbon emissions of line losses in the substation.

[0045] Exemplarily, after determining at least one of the indirect carbon emissions from electricity consumption, the indirect carbon emissions from line losses in the substation, and the substation carbon emissions in the substation, the substation collection terminal may upload it to the main station management platform, so that the main station management platform can promptly understand the carbon emissions such as the indirect carbon emissions from electricity consumption, the indirect carbon emissions from line losses in the substation, or the substation carbon emissions in the substation, and formulate relevant emission reduction strategies in a timely manner.

[0046] Exemplarily, the substation collection terminal can monitor the carbon emissions on the distribution side or the power generation side in real time based on at least one of the indirect carbon emissions from electricity consumption, the indirect carbon emissions from line losses in the substation, and the substation carbon emissions in the substation. At the same time, the substation collection terminal can perform carbon emissions analysis based on at least one of the indirect carbon emissions from electricity consumption, the indirect carbon emissions from line losses in the substation, and the substation carbon emissions in the substation, generate data such as the cumulative indirect carbon emissions of the substation, the average carbon emission intensity, and the 24-hour carbon emission curve, and upload them to the master station management platform. In addition, it is also possible to receive carbon metering-related parameters and evaluation indicators adjusted by the master station management platform according to actual conditions, so as to update parameters and further improve the comprehensiveness and accuracy of carbon emission metering in the power system.

[0047] In the above implementation, the line loss rate of the substation at the target time and the dynamic carbon emission factor determined by each user node in the substation based on the carbon emission metering parameters at the target time are obtained. Then, for any user node, the product of the dynamic carbon emission factor of the user node at the target time and the power consumption of the user node at the target time is used as the indirect carbon emissions of electricity consumption of the user node at the target time. Then, the line loss power of the substation at the target time is determined by the average power of the user node and the line loss rate of the substation at the target time, and the line loss indirect carbon emissions of the substation are determined according to the line loss power of the substation at the target time and the dynamic carbon emission factor of each user node. Then, the carbon emissions of the substation at the target time are determined according to the indirect carbon emissions of electricity consumption of each user node and the line loss indirect carbon emissions of the substation. In this way, when conducting carbon emission analysis, the carbon emissions in the power system that change with the load of the user node can be effectively reflected, thereby improving the comprehensiveness and accuracy of carbon emission metering of the power system.

[0048] In some implementations, obtaining the line loss rate of the substation at the target time may include the following steps S310-S330.

[0049] Step S310: Obtain the total power consumption of the substation at the target time.

[0050] Step S320: Obtain the power consumption of each user node in the substation at the target time.

[0051] Step S330: Based on the total power consumption and the power consumption of each user node, determine the line loss rate of the substation at the target time.

[0052] Exemplarily, the line loss rate of the station area can be determined by Formula 2.

[0053]

[0054] Where L represents the line loss rate of the area, N represents the total number of user nodes in the area, n represents any user node in the area, P nrepresents the power consumption of any user node, P total Indicates the total power consumption of the area.

[0055] In some implementations, obtaining the dynamic carbon emission factor of each user node in the station area at the target time may include the following steps S410-S420.

[0056] Step S410: Obtain carbon emission metering parameters, wherein the carbon emission metering parameters include a preset static carbon emission factor for each user node, an electricity trading volume impact weight, a total electricity trading volume of the area at the target time, a node electricity trading volume of each user node at the target time, and a power factor of each user node.

[0057] Among them, the static carbon emission factor can be a pre-set carbon emission factor, which can be the annual average value of unit carbon emissions announced by relevant organizations, or it can be the average value of unit carbon emissions issued by the master station management platform as a dispatching center or updated in real time.

[0058] Step S420: Determine the dynamic carbon emission factor of each user node at the target time according to the static carbon emission factor, the power trading volume impact weight, the total power trading volume, the power trading volume of each node and the power factor of each user node.

[0059] In some embodiments, the dynamic carbon emission factor of the user node at the target time can be obtained by

[0060] Determined by formula 3.

[0061]

[0062] Where n represents any user node in the area. represents the dynamic carbon emission factor of any user node, represents the static carbon emission factor of any user node, E n represents the node power transaction volume of any user node, E total Indicates the total power transaction volume in the area, PF n Represents the power factor of any user node.

[0063] In some implementations, the carbon emission measurement parameter also includes a renewable energy ratio. In this implementation, the dynamic carbon emission factor of the user node at the target time can also be determined by Formula 4.

[0064]

[0065] in, represents the dynamic carbon emission factor of any user node, represents the static carbon emission factor of any user node, En represents the node power transaction volume of any user node, E total represents the total electricity trading volume in the area, f n Indicates the proportion of renewable energy in the power source of the station area, PF n Represents the power factor of any user node.

[0066] In some embodiments, the line loss indirect carbon emissions may be determined by Equation 5 and Equation 6.

[0067]

[0068]

[0069] Among them, F L represents the indirect carbon emissions of line loss in the area, N represents the total number of user nodes in the area, and n represents any user node in the area. Represents the dynamic carbon emission factor of any user node;

[0070] L represents the line loss rate of the substation area, P L Indicates the line loss power in the substation area, P n A user node representing any user node in the station area.

[0071] In some embodiments, the carbon emissions of a station area can be determined by Formula 7.

[0072]

[0073] Among them, F total represents the carbon emissions of the region, F L represents the indirect carbon emissions from line losses in the area, N is the total number of user nodes in the area, and F n Represents the indirect carbon emissions from electricity consumption of any user node.

[0074] The embodiments of this specification provide a carbon emission metering device for a power system. The carbon emission metering device can be applied to a collection terminal in a power system. Figure 3 The carbon emission metering device may include a station line loss rate acquisition module 310, a carbon emission factor acquisition module 320, a first carbon emission amount determination module 330, a second carbon emission amount determination module 340 and a station carbon emission amount determination module 350.

[0075] The substation line loss rate acquisition module 310 is used to obtain the line loss rate of the substation at the target time;

[0076] The carbon emission factor acquisition module 320 is used to acquire the dynamic carbon emission factor of each user node in the station area at the target time, wherein the dynamic carbon emission factor is determined based on the carbon emission measurement parameters at the target time;

[0077] The first carbon emission determination module 330 is used to determine, for any user node, the product of the dynamic carbon emission factor of the user node at the target time and the power consumption of the user node at the target time as the indirect carbon emission of electricity consumption of the user node at the target time;

[0078] The second carbon emission determination module 340 is used to determine the line loss indirect carbon emission of the station area according to the line loss power of the station area at the target time and the dynamic carbon emission factor of each user node, wherein the line loss power of the station area at the target time is determined by the average power of the user node and the line loss rate of the station area at the target time;

[0079] The substation carbon emission determination module 350 is used to determine the substation carbon emission at the target time according to the indirect carbon emission of electricity consumption of each user node and the indirect carbon emission of line loss in the substation.

[0080] In some embodiments, the substation line loss rate acquisition module 310 is also used to: obtain the total power consumption of the substation at the target time; obtain the user node power consumption of each user node in the substation at the target time; and determine the line loss rate of the substation at the target time based on the total power consumption and the power consumption of each user node.

[0081] In some embodiments, the carbon emission factor acquisition module 320 is also used to: obtain carbon emission metering parameters, wherein the carbon emission metering parameters include a preset static carbon emission factor for each user node, an electricity trading volume influence weight, a total electricity trading volume of the area at the target time, a node electricity trading volume of each user node at the target time, and a power factor of each user node; determine the dynamic carbon emission factor of each user node at the target time based on the static carbon emission factor, the electricity trading volume influence weight, the total electricity trading volume, the electricity trading volume of each node, and the power factor of each user node.

[0082] The specific functions and effects achieved by the carbon emission metering device can be explained in reference to other embodiments of this specification, and will not be repeated here. Each module in the carbon emission metering device can be implemented in whole or in part by software, hardware, and a combination thereof. Each module can be embedded in or independent of a processor in a computer device in the form of hardware, or can be stored in a memory in a computer device in the form of software, so that the processor can call and execute the operations corresponding to the above modules.

[0083] The embodiments of this specification also provide a computer-readable storage medium having a computer program stored thereon. When the computer program is executed by a computer, the computer executes the carbon emission measurement method in any of the above embodiments.

[0084] The embodiments of this specification also provide a computer program product including instructions, which, when executed by a computer, enables the computer to execute the carbon emission measurement method in any of the above embodiments.

[0085] The embodiments of the present specification also provide a computer device, including a memory and a processor, wherein a computer program is stored in the memory, and when the processor executes the computer program, the carbon emission measurement method in the above embodiments is implemented.

[0086] In some embodiments, see Figure 4 The computer device may be a terminal, and its internal structure diagram may be as follows: Figure 4 As shown. The computer device includes a processor, a memory, and a communication interface connected through a system bus. Among them, the processor of the computer device is used to provide computing and control capabilities. The memory of the computer device includes a non-volatile storage medium and an internal memory. The non-volatile storage medium stores an operating system and a computer program. The internal memory provides an environment for the operation of the operating system and the computer program in the non-volatile storage medium. The communication interface of the computer device is used to communicate with an external terminal in a wired or wireless manner, and the wireless manner can be implemented through WIFI, an operator network, NFC (near field communication) or other technologies. When the computer program is executed by the processor, a carbon emission measurement method is implemented.

[0087] It should be understood that the specific examples herein are only intended to help those skilled in the art to better understand the embodiments of the present specification, rather than to limit the scope of the present invention.

[0088] It can be understood that in the various implementations of this specification, the size of the sequence number of each process does not mean the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the implementation methods of this specification.

[0089] It can be understood that the various embodiments described in this specification can be implemented individually or in combination, and the embodiments of this specification are not limited to this.

[0090] Unless otherwise specified, all technical and scientific terms used in the embodiments of this specification have the same meaning as those generally understood by those skilled in the art of the technical field of this specification. The terms used in this specification are only for the purpose of describing specific embodiments and are not intended to limit the scope of this specification. The term "and / or" used in this specification includes any and all combinations of one or more related listed items. The singular forms of "a", "above", and "the" used in the embodiments of this specification and the appended claims are also intended to include plural forms, unless the context clearly indicates other meanings.

[0091] It can be understood that the processor of the embodiment of this specification can be an integrated circuit chip with signal processing capabilities. In the implementation process, each step of the above method implementation can be completed by the hardware integrated logic circuit or software instructions in the processor. The above processor can be a general processor, a digital signal processor (Digital Signal Processor, DSP), an application-specific integrated circuit (Application Specific Integrated Circuit, ASIC), a field programmable gate array (Field Programmable Gate Array, FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components. The methods, steps and logic block diagrams disclosed in the embodiment of this specification can be implemented or executed. The general processor can be a microprocessor or the processor can also be any conventional processor, etc. The steps of the method disclosed in the embodiment of this specification can be directly embodied as a hardware decoding processor to perform, or the hardware and software modules in the decoding processor are combined and executed. The software module can be located in a mature storage medium in the field such as a random access memory, a flash memory, a read-only memory, a programmable read-only memory or an electrically erasable programmable memory, a register, etc. The storage medium is located in the memory, and the processor reads the information in the memory and completes the steps of the above method in combination with its hardware.

[0092] It is understood that the memory in the embodiments of this specification may be a volatile memory or a non-volatile memory, or may include both volatile and non-volatile memory. Among them, the non-volatile memory may be a read-only memory (ROM), a programmable read-only memory (programmable ROM, PROM), an erasable programmable read-only memory (erasablePROM, EPROM), an electrically erasable programmable read-only memory (EEPROM) or a flash memory. The volatile memory may be a random access memory (RAM). It should be noted that the memory of the systems and methods described herein is intended to include, but is not limited to, these and any other suitable types of memory.

[0093] Those skilled in the art will appreciate that the units and algorithm steps of each example described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are performed in hardware or software depends on the specific application and design constraints of the technical solution. Professional and technical personnel can use different methods to implement the described functions for each specific application, but such implementation should not be considered to be beyond the scope of this specification.

[0094] Those skilled in the art can clearly understand that, for the convenience and brevity of description, the specific working processes of the systems, devices and units described above can refer to the corresponding processes in the aforementioned method implementation methods and will not be repeated here.

[0095] The above is only a specific implementation of this specification, but the protection scope of the present invention is not limited thereto. Any person skilled in the art who is familiar with the technical field can easily think of changes or substitutions within the technical scope disclosed in this specification, which should be included in the protection scope of this specification. Therefore, the protection scope of the present invention should be based on the protection scope of the claims.

Claims

1. A method for measuring carbon emissions in a power system, characterized in that: The power system includes a station area, the station area includes at least one user node, and the method includes: Obtaining the line loss rate of the substation at the target time; Obtaining a dynamic carbon emission factor of each user node in the station area at the target time, wherein the dynamic carbon emission factor is determined based on the carbon emission measurement parameter at the target time; For any of the user nodes, the product of the dynamic carbon emission factor of the user node at the target time and the power consumption of the user node at the target time is used as the indirect carbon emission of electricity consumption of the user node at the target time; Determine the line loss indirect carbon emissions of the area according to the line loss power of the area at the target time and the dynamic carbon emission factor of each user node, wherein the line loss power of the area at the target time is determined by the average power of the user nodes and the line loss rate of the area at the target time; The carbon emissions of the substation at the target time are determined according to the indirect carbon emissions of electricity consumption of each user node and the indirect carbon emissions of line losses in the substation.

2. The method according to claim 1, characterized in that The obtaining of the line loss rate of the station area at the target time includes: Obtaining the total power consumption of the substation at the target time; Obtaining the user node power consumption of each user node in the station area at the target time; The line loss rate of the substation at the target time is determined based on the total power consumption and the power consumption of each user node.

3. The method according to claim 1, characterized in that The obtaining of the dynamic carbon emission factor of each user node in the station area at the target time includes: Obtain the carbon emission measurement parameters, wherein the carbon emission measurement parameters include a preset static carbon emission factor of each user node, an influence weight of the power trading volume, a total power trading volume of the area at the target time, a node power trading volume of each user node at the target time, and a power factor of each user node; The dynamic carbon emission factor of each of the user nodes at the target moment is determined based on the static carbon emission factor, the electricity trading volume impact weight, the total electricity trading volume, the electricity trading volume of each of the nodes and the power factor of each of the user nodes.

4. The method according to claim 3, characterized in that The dynamic carbon emission factor of the user node at the target time is determined by the following formula: in, represents the dynamic carbon emission factor of any user node, represents the static carbon emission factor of any user node, E n represents the node power transaction volume of any user node, E total Indicates the total power transaction volume in the area, PF n Represents the power factor of any user node.

5. The method according to claim 3, characterized in that: The carbon emission measurement parameters also include the proportion of renewable energy. The dynamic carbon emission factor of the user node at the target time is determined by the following formula: in, represents the dynamic carbon emission factor of any user node, represents the static carbon emission factor of any user node, E n represents the node power transaction volume of any user node, E total represents the total electricity trading volume in the area, f n Indicates the proportion of renewable energy in the power source of the station area, PF n Represents the power factor of any user node.

6. The method according to claim 1, characterized in that The indirect carbon emissions from line losses are determined by the following formula: Among them, F L represents the indirect carbon emissions of line loss in the area, N represents the total number of user nodes in the area, and n represents any user node in the area. Represents the dynamic carbon emission factor of any user node; L represents the line loss rate of the substation area, P L Indicates the line loss power in the substation area, A user node representing any user node in the station area.

7. The method according to claim 1, characterized in that The carbon emissions of the station area are determined by the following formula: Among them, F total represents the carbon emissions of the region, F L represents the indirect carbon emissions from line losses in the area, N is the total number of user nodes in the area, and F n Represents the indirect carbon emissions from electricity consumption of any user node.

8. A carbon emission metering device for a power system, characterized in that: The power system includes a station area, the station area includes at least one user node, and the device includes: A substation line loss rate acquisition module, used to acquire the line loss rate of the substation at the target time; A carbon emission factor acquisition module, used to acquire a dynamic carbon emission factor of each user node in the station area at the target time, wherein the dynamic carbon emission factor is determined based on the carbon emission measurement parameter at the target time; A first carbon emission determination module is used to, for any of the user nodes, use the product of the dynamic carbon emission factor of the user node at the target time and the power consumption of the user node at the target time as the indirect carbon emission of electricity consumption of the user node at the target time; A second carbon emission determination module is used to determine the line loss indirect carbon emissions of the substation according to the line loss power of the substation at the target time and the dynamic carbon emission factor of each user node, wherein the line loss power of the substation at the target time is determined by the average power of the user node and the line loss rate of the substation at the target time; The substation carbon emission determination module is used to determine the substation carbon emission of the substation at the target time according to the indirect carbon emission of electricity consumption of each user node and the indirect carbon emission of line loss in the substation.

9. A computer device comprising a memory and a processor, wherein the memory stores a computer program, wherein: When the processor executes the computer program, the carbon emission measurement method according to any one of claims 1 to 7 is implemented.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the carbon emission measurement method according to any one of claims 1 to 7 is implemented.

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