CN116701815A - Real-time carbon emission flow tracking method and device for electric power system - Google Patents
Real-time carbon emission flow tracking method and device for electric power system Download PDFInfo
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Abstract
The application relates to a method and a device for tracking real-time carbon emission flow of an electric power system, wherein the method comprises the steps of acquiring input data for carbon flow calculation so as to calculate the carbon emission intensity of each unit; calculating node carbon potential of a current node based on the carbon row intensity of each unit, obtaining full-network node carbon potential based on the node carbon potential of the current node, and calculating branch carbon flow density of each branch based on the full-network node carbon potential; calculating the carbon flow rate of the unit injection and the load consumption of each corresponding node by using the node carbon potential of each node, and calculating the branch carbon flow rate of each corresponding branch by using the branch carbon flow density of each branch; and storing the carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of each node. The application adopts a dynamic carbon emission intensity mode, is favorable for reflecting the actual carbon emission condition and improves the reliability of carbon emission flow calculation.
Description
Technical Field
The application belongs to the technical field of electric power markets, and particularly relates to a method and a device for tracking real-time carbon emission flow of an electric power system.
Background
At present, the carbon emission measuring and calculating mode in the power industry is mainly divided into two modes, namely direct carbon emission measurement and indirect carbon emission measurement, wherein the direct carbon emission measurement and the indirect carbon emission measurement are modes which are relatively widely applied at present. The indirect carbon emission metering mode of carbon emission flow tracking based on tide data describes the distribution state of carbon emission flow in the processes of power production, consumption and transfer in detail. The carbon emission flow method is based on the carbon emission intensity of the unit and the system active power flow, and the related indexes of the carbon emission quantity of the unit and the load carbon emission quantity are calculated, so that the accuracy of the carbon emission intensity of the unit and the accuracy of the system power flow are directly related to the accuracy of the carbon emission quantity calculation. The method is characterized in that the proportion of bad tidal current data is reduced to a great extent due to the introduction of a power system state estimation program, and the data precision and the data quality of the tidal current of the system can be effectively improved, so that the carbon emission intensity of each unit of the system becomes a key factor affecting the accuracy of measuring and calculating the carbon emission under the carbon emission flow theory.
In the prior art, regarding the determination of the carbon emission intensity of the unit, a mode of fixing the carbon emission intensity of the unit according to different unit types is generally adopted, namely, the whole-network system unit is divided into a coal-fired unit, a gas unit, a hydroelectric unit, a new energy unit and the like, further, based on historical experience or existing measurement references, the fixed carbon emission intensity experience values of various unit types are respectively obtained, and the carbon emission amount of the unit can be considered as a linear function of the unit power. Considering that the carbon emission of the hydroelectric generating set and the new energy is relatively low, and the relation between the carbon emission and the operation condition is relatively simple, the adoption of the fixed carbon emission intensity has certain rationality; however, for the thermal power generating unit, as the carbon emission of the thermal power generating unit is relatively high, and the thermal power operation is relatively complex, the linear relation is not completely followed, and the real-time carbon emission intensity of the unit cannot be completely and objectively reflected by adopting a mode of fixing the carbon emission intensity, so that the accuracy of tracking and measuring and calculating the carbon emission of the system is affected.
In the related art, the scheme needs to be optimized in consideration of the existing defects of carbon emission measurement based on fixed thermal power carbon emission intensity. The greenhouse gas on-line monitoring system is generally installed on the tail flue of the thermal power plant unit to acquire real-time carbon emission data of the unit, and the method has the advantages that the carbon emission of the unit or the power plant can be updated in real time, the real-time power generation power of the unit is combined, the carbon emission intensity of the unit is obtained through conversion, and then the carbon flow calculation is carried out.
Disclosure of Invention
In view of the above, the application aims to overcome the defects of the prior art, and provides a method and a device for tracking the real-time carbon emission flow of an electric power system, so as to solve the problems that the accuracy of tracking and measuring the carbon emission of the system is affected by adopting fixed carbon emission intensity, but the existing optimization method has high cost and long implementation period.
In order to achieve the above purpose, the application adopts the following technical scheme: a method for real-time carbon emission flow tracking of an electrical power system, comprising:
acquiring input data for carbon flow calculation, and calculating the carbon emission intensity of each unit based on the input data; the unit comprises a coal-fired unit, a gas unit and a non-coal-fired gas unit;
calculating node carbon potential of a current node based on carbon row intensity of each unit, obtaining full-network node carbon potential based on the node carbon potential of the current node, and calculating branch carbon flow density of each branch based on the full-network node carbon potential;
calculating the carbon flow rate of the unit injection and the load consumption of each corresponding node by using the node carbon potential of each node, and calculating the branch carbon flow rate of each corresponding branch by using the branch carbon flow density of each branch;
and storing the carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of each node.
Further, the input data includes:
a coal consumption curve table of the coal-fired unit, a gas consumption curve table of the gas-fired unit and a non-coal-fired gas carbon emission intensity table;
wherein, coal-fired unit coal consumption curve table includes: unit ID, unit name, operation age, unit load rate, coal type and coal consumption;
the gas consumption curve table of the gas unit comprises: unit ID, unit name, operation age, unit load rate and air consumption;
the non-coal-fired gas carbon emission intensity table comprises: unit ID, unit name, unit type, and non-coal gas carbon emission intensity.
Further, the input data further includes:
a unit information table, a load information table, a line information table, a transformer information table, a winding information table, a series compensation information table, a switch information table and a disconnecting link information table;
analyzing a unit information table, a load information table, a line information table, a transformer information table, a winding information table, a series compensation information table, a switch information table and a disconnecting link information table to obtain a system topology node information table, a topology branch information table and a device and node association relation information table;
the input data further includes: injecting active power and branch active power flow into each node;
and injecting active power and branch active power flows into each node, storing the active power flows and branch active power flows into a data table, and establishing a mapping relation between active power flow data and topology.
Further, calculating the carbon emission intensity of the coal-fired unit based on the input data includes:
adopting a quadratic curve fitting mode to simplify the acquired coal consumption curve, namely establishing the relation of the coal consumption y to the unit load rate R aiming at different units, coal types and operation years P Is a cluster of functions of:
wherein i represents an ith unit, j represents a coal type, k represents a unit operation period, and a is as follows i,j,k 、b i,j,k and ci,j,k The method comprises the steps of respectively obtaining a quadratic term coefficient, a first term coefficient and a constant term of a fitting curve;
the amount of carbon emissions per unit time is calculated based on the amount of coal consumption in the following manner,
wherein F is the carbon emission amount in unit time, eta 1 Is the carbon content of the fire coal, eta 2 44 is carbon dioxide molar mass, 12 is carbon molar mass;
calculating the carbon emission intensity corresponding to the coal-fired unit at the current moment according to the carbon emission amount,
wherein ,Pi rate Is the rated power of the unit i.
Further, calculating the carbon emission intensity of the gas turbine unit based on the input data includes:
establishing a gas consumption y relative to a unit load rate R according to a gas consumption curve table of the gas unit P Is a cluster of functions of:
wherein i represents an ith unit, k represents the running years of the unit, and a i,k 、b i,k and ci,k The method comprises the steps of respectively obtaining a quadratic term coefficient, a first term coefficient and a constant term of a fitting curve;
the amount of carbon emissions per unit time is calculated based on the gas consumption in the following manner,
wherein F is the carbon emission in unit time, beta 1 Is natural gas purity, beta 2 For the full combustion oxidation rate of fuel gas, M CO2 Corresponding to the carbon dioxide molar mass, M CH4 Corresponding to the molar mass of methane,
M CH4 (22.4) x 10 is a conversion formula between gas consumption and mass;
the carbon emission intensity of the corresponding gas turbine set at the current moment is calculated according to the carbon emission amount in unit time in the following way,
further, the node carbon potential of the current node is calculated based on the input data in such a manner that,
wherein ,Pg Active power of a unit connected with the node i; e (E) g Dynamic carbon emission intensity for the corresponding unit; p (P) ji For injecting a power flow from node j to node i into branch l ij E j The node carbon potential of node j.
Further, according to the proportion contribution principle, calculating the branch carbon flow density e of each branch ij ；
The carbon flow rate of the unit injection and the carbon flow rate of the load consumption of each corresponding node are calculated by using the node carbon potential of each node in the following way, and the branch carbon flow rate of each corresponding branch is calculated by using the branch carbon flow density of each branch,
wherein ,carbon flow rate for each node unit injection, +.>Carbon flow rate for load consumption of each node,Branch carbon flow rate for each branch.
Further, the storing the carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of the unit of each node includes:
generating a node carbon potential table, a branch carbon flow density table, a unit carbon injection flow table, a load consumption carbon flow table and a branch carbon flow table series original data table according to the unit carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each node.
The embodiment of the application provides a real-time carbon emission flow tracking device of an electric power system, which comprises the following components:
the acquisition module is used for acquiring input data for carbon flow calculation and calculating the carbon emission intensity of each unit based on the input data; the unit comprises a coal-fired unit, a gas unit and a non-coal-fired gas unit;
the first calculation module is used for calculating the node carbon potential of the current node based on the carbon row intensity of each unit, obtaining the full-network node carbon potential based on the node carbon potential of the current node, and calculating the branch carbon flow density of each branch based on the full-network node carbon potential;
the second calculation module is used for calculating the carbon flow rate of the unit injection and the load consumption of each corresponding node by using the node carbon potential of each node, and calculating the branch carbon flow rate of each corresponding branch by using the branch carbon flow density of each branch;
and the storage module is used for storing the unit injection carbon flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of each node.
By adopting the technical scheme, the application has the following beneficial effects:
the application provides a method and a device for tracking real-time carbon emission flow of an electric power system, which are characterized in that firstly, input data for carbon flow calculation is obtained, then the dynamic carbon emission intensity of a coal-fired unit, a gas unit and a non-coal-fired gas unit can be obtained through the input data, then the carbon flow calculation is carried out according to the dynamic carbon emission intensity, and then a carbon flow result is stored; the application adopts a dynamic carbon emission intensity mode, is favorable for reflecting the actual carbon emission condition and improves the reliability of carbon emission flow calculation.
Drawings
In order to more clearly illustrate the embodiments of the application or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, it being obvious that the drawings in the following description are only some embodiments of the application, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a schematic diagram illustrating steps of a real-time carbon emission flow tracking method for an electric power system according to the present application;
FIG. 2 is a graph showing a fitted curve of coal consumption;
FIG. 3 is a schematic diagram of a gas consumption fitting curve provided by the application;
fig. 4 is a schematic structural diagram of a real-time carbon emission flow tracking device of an electric power system according to the present application.
Detailed Description
In order to make the objects, technical solutions and advantages of the present application more apparent, the technical solutions of the present application will be described in detail below. It will be apparent that the described embodiments are only some, but not all, embodiments of the application. All other embodiments, based on the examples herein, which are within the scope of the application as defined by the claims, will be within the scope of the application as defined by the claims.
The following describes a specific method and device for tracking real-time carbon emission flow of an electric power system according to an embodiment of the present application with reference to the accompanying drawings.
As shown in fig. 1, the method for tracking the real-time carbon emission flow of the power system provided in the embodiment of the application includes:
s101, acquiring input data for carbon flow calculation; calculating the carbon emission intensity of each unit based on the input data; the unit comprises a coal-fired unit, a gas unit and a non-coal-fired gas unit;
in some embodiments, the input data comprises:
a coal consumption curve table of the coal-fired unit, a gas consumption curve table of the gas-fired unit and a non-coal-fired gas carbon emission intensity table;
wherein, coal-fired unit coal consumption curve table includes: unit ID, unit name, operation age, unit load rate, coal type and coal consumption;
the gas consumption curve table of the gas unit comprises: unit ID, unit name, operation age, unit load rate and air consumption;
the non-coal-fired gas carbon emission intensity table comprises: unit ID, unit name, unit type, and non-coal gas carbon emission intensity.
The input data further includes:
a unit information table, a load information table, a line information table, a transformer information table, a winding information table, a series compensation information table, a switch information table and a disconnecting link information table; wherein each device information table comprises device basic information and located physical node information.
Analyzing a unit information table, a load information table, a line information table, a transformer information table, a winding information table, a series compensation information table, a switch information table and a disconnecting link information table to obtain a system topology node information table, a topology branch information table and a device and node association relation information table; specifically, the application completes topology analysis based on the node association relationship, and acquires a system topology node information table, a topology branch information table and a device and node association relationship information table.
The input data further includes: injecting active power and branch active power flow into each node;
and injecting active power and branch active power flows into each node, storing the active power flows and branch active power flows into a data table, and establishing a mapping relation between active power flow data and topology.
The acquisition of the input data completes the acquisition of the input data of the real-time carbon flow calculation, and prepares for the carbon flow calculation.
Specifically, the coal consumption curves of all units of all coal-fired power plants are firstly obtained, for coal-fired units, the design coal consumption of the units is mainly determined by design parameters, design levels and the like, and the design coal consumption of the units can be determined when the equipment leaves the factory, but the actual operation coal consumption is different from the design coal consumption due to the influences of factors such as unit load rate, used coal types, aging state of the units and the like, and the power plants are generally required to be combined with actual operation data to correct the design coal consumption. The unit load rate and the coal types can be quantized or classified, and the thermal power plant can acquire the coal consumption under different unit load rates and coal types so as to draw a unit coal consumption curve; the unit aging state is unquantifiable, but can be regarded as a function of time, so that a manufacturer is required to update a drawn unit coal consumption curve according to a certain time frequency, such as in units of years, and store the unit coal consumption curve into a unit coal consumption curve table of a database, wherein the table comprises a unit ID, a unit name, an operation period, a unit load rate (%), "coal type" and "coal consumption (t/h)".
The method is similar to a coal-fired unit, under actual operation conditions, a gas consumption characteristic curve is firstly obtained, and the gas consumption characteristic curve under basic design load is corrected and converted, but because the natural gas type is relatively single, the drawn coal consumption curve of the gas-fired unit is mainly a function of the operation period and the load factor, and the unit gas consumption curve list stored in the database comprises a unit ID, a unit name, the operation period, a unit load factor (%) and a gas consumption (ten thousand m 3/h).
Some embodimentsIn the method, the unit coal consumption curve is related to a plurality of factors such as the unit design coal consumption, the unit load rate, the coal type, the operation life and the like, and when one unit is added, the storage data volume is greatly increased, so that the time consumption for acquiring the coal consumption data is increased. In order to give consideration to the accuracy of the index efficiency of the database and the real-time carbon emission intensity of the unit, the acquired coal consumption curve is simplified by adopting a quadratic curve fitting mode in combination with the actual characteristic of the coal consumption, namely, the coal consumption y is established relative to the unit load rate R aiming at different units, coal types and operation years P Is a cluster of functions of:
wherein i represents an ith unit, j represents a coal type, k represents a unit operation period, and a is as follows i,j,k 、b i,j,k and ci,j,k The method comprises the steps of respectively obtaining a quadratic term coefficient, a first term coefficient and a constant term of a fitting curve;
as shown in fig. 2, a graph corresponding to the quadratic fit of the coal consumption function of different units under different coal types and operation years is shown.
Based on the coal consumption fitting curve, when the coal types and the operation years are determined, the coal consumption of each unit under the current load rate can be obtained, and then the carbon emission F in unit time can be calculated according to the coal consumption:
wherein F is the carbon emission amount in unit time, eta 1 Is the carbon content of the fire coal, eta 2 For the coal oxidation rate, 44 is the carbon dioxide molar mass and 12 is the carbon molar mass.
Further, the carbon emission intensity E of the coal-fired unit corresponding to the current moment can be calculated g (Unit: tCO) 2 /MW·h)：
in the formula ,Pi rate Is the rated power of the unit i.
Similar to a coal-fired unit, the gas consumption of the gas unit can also be modeled in a curve fitting mode, and the gas consumption of the gas unit is mainly related to factors such as the gas consumption, the unit load rate, the operation life and the like of the unit design, so that the gas consumption y can be established relative to the unit load rate R P Is a cluster of functions of:
wherein i represents an ith unit, k represents the running years of the unit, and a i,k 、b i,k and ci,k The coefficients are the quadratic term coefficient, the first term coefficient and the constant term of the fitting curve respectively. Referring to fig. 3, a graph of the gas consumption function versus quadratic fit for different units at different operating years is shown.
Based on the fitting curve of the gas consumption, when the operation age limit is determined, the gas consumption of each unit under the current load rate can be obtained, and then the carbon emission F in unit time can be calculated according to the gas consumption:
wherein F is the carbon emission per unit time (unit: tco) 2 /h)，β 1 Is natural gas purity, beta 2 For the full combustion oxidation rate of fuel gas, M CO2 Corresponding to the carbon dioxide molar mass, M CH4 Corresponding to the molar mass of methane, M CH4 And/(22.4) 10 is the gas consumption (unit: ten thousand m) 3 ) And mass (unit: t) a conversion formula between; the carbon emission intensity of the corresponding gas turbine set at the current moment is calculated according to the carbon emission amount in unit time in the following way,
s102, calculating node carbon potential of a current node based on the input data, obtaining full-network node carbon potential based on the node carbon potential of the current node, and calculating branch carbon flow density of each branch based on the full-network node carbon potential;
according to the real-time carbon emission intensity of the unit, the real-time power of the unit and the real-time active power flow of the branch, the node carbon potential of the current node is calculated based on the input data in the following way,
wherein ,Pg Active power of a unit connected with the node i; e (E) g Dynamic carbon emission intensity for the corresponding unit; p (P) ji For injecting a power flow from node j to node i into branch l ij E j The node carbon potential of node j.
As a specific example, assuming that there are 3 units connected to node i, the connected unit 1 type is a coal-fired unit, the unit E g Adopting the carbon emission intensity of the coal-fired coal unit, and if the connected unit 2 is a gas unit, the unit E g Adopting the carbon emission intensity of a gas unit; if the connected unit 3 is a non-coal-fired and gas-fired unit, correspondingly selecting the corresponding E according to the carbon emission intensity table of the non-coal-fired and gas-fired unit g 。
S103, calculating the carbon flow rate of the unit injection and the load consumption of each corresponding node by using the node carbon potential of each node, and calculating the branch carbon flow rate of each corresponding branch by using the branch carbon flow density of each branch;
according to the proportion contribution principle, calculating the branch carbon flow density e of each branch ij ；
The carbon flow rate of the unit injection and the carbon flow rate of the load consumption of each corresponding node are calculated by using the node carbon potential of each node in the following way, and the branch carbon flow rate of each corresponding branch is calculated by using the branch carbon flow density of each branch,
wherein ,carbon flow rate for each node unit injection, +.>Carbon flow rate for load consumption of each node,Branch carbon flow rate for each branch.
And S104, storing the unit injection carbon flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of each node.
In some embodiments, storing the unit injection carbon flow rate, the load consumption carbon flow rate, and the branch carbon flow rate of each branch for each node includes:
generating a node carbon potential table, a branch carbon flow density table, a unit carbon injection flow table, a load consumption carbon flow table and a branch carbon flow table series original data table according to the unit carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each node.
Specifically, the unit carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of each node are used for forming a node carbon potential table, a branch carbon flow density table, a unit carbon injection flow rate table, a load consumption carbon flow rate table and a branch carbon flow rate table series original data table for subsequent data comparison analysis to assist in clearing the carbon emission flow condition of the system.
The application combines the actual running condition of the power plant and the consumption characteristic of the li-qing machine set, provides a mode of adopting dynamic carbon emission intensity, is favorable for reflecting the actual carbon emission condition and improves the reliability of carbon emission flow calculation. Besides, in the process of calculating the carbon emission amount, the application provides a simplified consumption fitting curve mode, the coal consumption curve under certain conditions is extracted into a fitting model under corresponding conditions, the database index time is shortened, and note that the fitting model does not adopt the same fitting curve for all coal (gas) fired units, but combines the initial design consumption characteristics of each unit to fit each unit under different running environments, so that a cluster of curve families related to unit load rates is formed, and the reliability of data is also considered; in addition, the method for calculating and disassembling the carbon emission flow into the calculation of each light-weight subsystem improves the flexibility of the emission flow metering system and is beneficial to the secondary utilization of each subsystem.
As shown in fig. 4, an embodiment of the present application provides a real-time carbon emission flow tracking device for an electric power system, including:
an acquisition module 201, configured to acquire input data for carbon flow calculation, and calculate carbon emission intensity of each unit based on the input data; the unit comprises a coal-fired unit, a gas unit and a non-coal-fired gas unit;
a first calculation module 202, configured to calculate a node carbon potential of a current node based on a carbon row strength of each unit, obtain a full-network node carbon potential based on the node carbon potential of the current node, and calculate a branch carbon flow density of each branch based on the full-network node carbon potential;
a second calculation module 203, configured to calculate a unit injection carbon flow rate and a load consumption carbon flow rate of each corresponding node using a node carbon potential of each node, and calculate a branch carbon flow rate of each corresponding branch using a branch carbon flow density of each branch;
the storage module 204 is configured to store a unit injection carbon flow rate, a load consumption carbon flow rate, and a branch carbon flow rate of each branch for each node.
The working principle of the real-time carbon emission flow tracking device of the electric power system provided by the embodiment of the application is that an acquisition module 201 acquires input data for carbon flow calculation, a first calculation module 202 calculates node carbon potential of a current node based on the input data, obtains full-network node carbon potential based on the node carbon potential of the current node, and calculates branch carbon flow density of each branch based on the full-network node carbon potential; the second calculation module 203 calculates a unit injection carbon flow rate and a load consumption carbon flow rate of each corresponding node by using the node carbon potential of each node, and calculates a branch carbon flow rate of each corresponding branch by using the branch carbon flow density of each branch; the storage module 204 stores the crew carbon injection flow rate, the load consumption carbon flow rate, and the branch carbon flow rate for each branch for each node.
In summary, the application provides a method and a device for tracking a real-time carbon emission flow of an electric power system, which firstly acquire input data for carbon flow calculation, then calculate the carbon flow through the input data, and then store a carbon flow result; the application adopts a dynamic carbon emission intensity mode, is favorable for reflecting the actual carbon emission condition and improves the reliability of carbon emission flow calculation.
It can be understood that the above-provided method embodiments correspond to the above-described apparatus embodiments, and corresponding specific details may be referred to each other and will not be described herein.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, magnetic disk storage, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may 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, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The foregoing is merely illustrative of the present application, and the present application is not limited thereto, and any person skilled in the art will readily recognize that variations or substitutions are within the scope of the present application. Therefore, the protection scope of the present application shall be subject to the protection scope of the claims.
Claims (9)
1. A method for tracking real-time carbon emission flow of an electric power system, comprising:
acquiring input data for carbon flow calculation, and calculating the carbon emission intensity of each unit based on the input data; the unit comprises a coal-fired unit, a gas unit and a non-coal-fired gas unit;
calculating node carbon potential of a current node based on carbon row intensity of each unit, obtaining full-network node carbon potential based on the node carbon potential of the current node, and calculating branch carbon flow density of each branch based on the full-network node carbon potential;
calculating the carbon flow rate of the unit injection and the load consumption of each corresponding node by using the node carbon potential of each node, and calculating the branch carbon flow rate of each corresponding branch by using the branch carbon flow density of each branch;
and storing the carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of each node.
2. The method of claim 1, wherein the input data comprises:
a coal consumption curve table of the coal-fired unit, a gas consumption curve table of the gas-fired unit and a non-coal-fired gas carbon emission intensity table;
wherein, coal-fired unit coal consumption curve table includes: unit ID, unit name, operation age, unit load rate, coal type and coal consumption;
the gas consumption curve table of the gas unit comprises: unit ID, unit name, operation age, unit load rate and air consumption;
the non-coal-fired gas carbon emission intensity table comprises: unit ID, unit name, unit type, and non-coal gas carbon emission intensity.
3. The method of claim 2, wherein the input data further comprises:
a unit information table, a load information table, a line information table, a transformer information table, a winding information table, a series compensation information table, a switch information table and a disconnecting link information table;
analyzing a unit information table, a load information table, a line information table, a transformer information table, a winding information table, a series compensation information table, a switch information table and a disconnecting link information table to obtain a system topology node information table, a topology branch information table and a device and node association relation information table;
the input data further includes: injecting active power and branch active power flow into each node;
and injecting active power and branch active power flows into each node, storing the active power flows and branch active power flows into a data table, and establishing a mapping relation between active power flow data and topology.
4. The method of claim 2, wherein calculating the carbon emission intensity of the coal-fired unit based on the input data comprises:
adopting a quadratic curve fitting mode to obtain the combustionThe coal consumption curve table of the coal unit is simplified, namely, the coal consumption y is established relative to the unit load rate R aiming at different units, coal types and operation years P Is a cluster of functions of:
wherein i represents an ith unit, j represents a coal type, k represents a unit operation period, and a is as follows i,j,k 、b i,j,k and ci,j,k The method comprises the steps of respectively obtaining a quadratic term coefficient, a first term coefficient and a constant term of a fitting curve;
the amount of carbon emissions per unit time is calculated based on the amount of coal consumption in the following manner,
wherein F is the carbon emission amount in unit time, eta 1 Is the carbon content of the fire coal, eta 2 44 is carbon dioxide molar mass, 12 is carbon molar mass;
calculating the carbon emission intensity Eg corresponding to the coal-fired unit at the current moment according to the carbon emission amount,
wherein ,Pi rate Is the rated power of the unit i.
5. The method of claim 2, wherein calculating a carbon emission intensity of a gas turbine unit based on the input data comprises:
establishing a gas consumption y relative to a unit load rate R according to a gas consumption curve table of the gas unit P Is a cluster of functions of:
wherein i represents an ith unit, k represents the running years of the unit, and a i,k 、b i,k and ci,k The method comprises the steps of respectively obtaining a quadratic term coefficient, a first term coefficient and a constant term of a fitting curve;
the amount of carbon emissions per unit time is calculated based on the gas consumption in the following manner,
wherein F is the carbon emission in unit time, beta 1 Is natural gas purity, beta 2 For the full combustion oxidation rate of fuel gas, M CO2 Corresponding to the carbon dioxide molar mass, M CH4 Corresponding to the molar mass of methane,
M CH4 (22.4) x 10 is a conversion formula between gas consumption and mass;
the carbon emission intensity Eg of the corresponding gas turbine set at the current moment is calculated according to the carbon emission amount in unit time in the following way,
6. the method of claim 5, wherein the node carbon potential of the current node is calculated based on the input data,
wherein ,Pg Active power of a unit connected with the node i; e (E) g Dynamic carbon emission intensity for the corresponding unit; p (P) ji For injecting a power flow from node j to node i into branch l ij E j The node carbon potential of node j.
7. The method of claim 6, wherein the step of providing the first layer comprises,
according to the proportion contribution principle, calculating the branch carbon flow density e of each branch ij ；
The carbon flow rate of the unit injection and the carbon flow rate of the load consumption of each corresponding node are calculated by using the node carbon potential of each node in the following way, and the branch carbon flow rate of each corresponding branch is calculated by using the branch carbon flow density of each branch,
wherein ,carbon flow rate for each node unit injection, +.>Carbon flow rate for load consumption of the individual nodes, +.>Branch carbon flow rate for each branch.
8. The method of claim 1, wherein storing the unit injection carbon flow rate, the load consumption carbon flow rate, and the branch carbon flow rate for each branch for each node comprises:
generating a node carbon potential table, a branch carbon flow density table, a unit carbon injection flow table, a load consumption carbon flow table and a branch carbon flow table series original data table according to the unit carbon injection flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each node.
9. A real-time carbon emission flow tracking device for an electric power system, comprising:
the acquisition module is used for acquiring input data for carbon flow calculation and calculating the carbon emission intensity of each unit based on the input data; the unit comprises a coal-fired unit, a gas unit and a non-coal-fired gas unit;
the first calculation module is used for calculating the node carbon potential of the current node based on the carbon row intensity of each unit, obtaining the full-network node carbon potential based on the node carbon potential of the current node, and calculating the branch carbon flow density of each branch based on the full-network node carbon potential;
the second calculation module is used for calculating the carbon flow rate of the unit injection and the load consumption of each corresponding node by using the node carbon potential of each node, and calculating the branch carbon flow rate of each corresponding branch by using the branch carbon flow density of each branch;
and the storage module is used for storing the unit injection carbon flow rate, the load consumption carbon flow rate and the branch carbon flow rate of each branch of each node.
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