CN116646918A - Electric-hydrogen combined low-carbon scheduling method and system for electric power system - Google Patents
Electric-hydrogen combined low-carbon scheduling method and system for electric power system Download PDFInfo
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- 229910052739 hydrogen Inorganic materials 0.000 title claims abstract description 160
- 239000001257 hydrogen Substances 0.000 title claims abstract description 160
- 238000000034 method Methods 0.000 title claims abstract description 49
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- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 92
- 238000005868 electrolysis reaction Methods 0.000 claims description 29
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 22
- 238000009792 diffusion process Methods 0.000 claims description 20
- 150000002431 hydrogen Chemical class 0.000 claims description 20
- 230000004907 flux Effects 0.000 claims description 19
- 230000009919 sequestration Effects 0.000 claims description 11
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 6
- 238000010977 unit operation Methods 0.000 claims description 5
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- 239000000446 fuel Substances 0.000 claims description 3
- 238000005315 distribution function Methods 0.000 claims description 2
- GVVPGTZRZFNKDS-JXMROGBWSA-N geranyl diphosphate Chemical compound CC(C)=CCC\C(C)=C\CO[P@](O)(=O)OP(O)(O)=O GVVPGTZRZFNKDS-JXMROGBWSA-N 0.000 claims description 2
- 230000005611 electricity Effects 0.000 claims 2
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- 230000009467 reduction Effects 0.000 abstract description 6
- 241000196324 Embryophyta Species 0.000 description 27
- 238000006243 chemical reaction Methods 0.000 description 13
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Classifications
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
- G06Q10/00—Administration; Management
- G06Q10/06—Resources, workflows, human or project management; Enterprise or organisation planning; Enterprise or organisation modelling
- G06Q10/063—Operations research, analysis or management
- G06Q10/0631—Resource planning, allocation, distributing or scheduling for enterprises or organisations
- G06Q10/06312—Adjustment or analysis of established resource schedule, e.g. resource or task levelling, or dynamic rescheduling
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
- G06Q10/00—Administration; Management
- G06Q10/06—Resources, workflows, human or project management; Enterprise or organisation planning; Enterprise or organisation modelling
- G06Q10/063—Operations research, analysis or management
- G06Q10/0631—Resource planning, allocation, distributing or scheduling for enterprises or organisations
- G06Q10/06313—Resource planning in a project environment
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
- G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
- G06Q50/06—Electricity, gas or water supply
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/008—Circuit arrangements for ac mains or ac distribution networks involving trading of energy or energy transmission rights
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/28—Arrangements for balancing of the load in a network by storage of energy
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- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J3/00—Circuit arrangements for ac mains or ac distribution networks
- H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
- H02J3/46—Controlling of the sharing of output between the generators, converters, or transformers
- H02J3/466—Scheduling the operation of the generators, e.g. connecting or disconnecting generators to meet a given demand
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
- H02J2203/10—Power transmission or distribution systems management focussing at grid-level, e.g. load flow analysis, node profile computation, meshed network optimisation, active network management or spinning reserve management
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
- H02J2203/20—Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
-
- H—ELECTRICITY
- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H02J2300/00—Systems for supplying or distributing electric power characterised by decentralized, dispersed, or local generation
- H02J2300/20—The dispersed energy generation being of renewable origin
- H02J2300/28—The renewable source being wind energy
Abstract
The invention provides an electric-hydrogen combined low-carbon scheduling method and system for an electric power system, which belong to the field of low-carbon scheduling of the electric power system, and the method comprises the following steps: establishing a model of each link in the low-carbon scheduling process; acquiring carbon emission space-time data of each carbon capture power plant in a scheduling period in a setting area, and determining CO of each carbon capture power plant at each moment in the setting area 2 Concentration contribution; obtaining normalized air temperature dependence factor, normalized vegetation index and total solar incident radiation fluxThe daily average temperature is determined, the net photosynthetic carbon fixation amount of the vegetation unit all the day is determined, and then the free CO at each moment in the set area is determined 2 Concentration; model and free CO based on each link in low-carbon scheduling 2 And (3) regional concentration constraint, namely, taking the total operation cost of the electric power system as a target, establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain a scheduling result. The invention can effectively improve the wind power consumption rate and promote the low-carbon emission reduction effect of the power system.
Description
Technical Field
The invention relates to the field of low-carbon scheduling of power systems, in particular to a method for considering CO 2 Concentration space-time distribution constraint electric power system electricity-hydrogen combined low-carbon scheduling method and system.
Background
The construction of a high-efficiency, clean and low-carbon energy system taking new energy as a main body is an effective measure for energy conservation and emission reduction in the power industry. However, the large-scale access of new energy brings challenges to the operation of the power grid, the fluctuation and intermittence of the new energy cause the new energy to be not fully absorbed by the power grid, and the wind and light discarding phenomenon is increasingly serious. The surplus wind power is utilized to electrolyze water to produce hydrogen, and meanwhile, the hydrogen and the carbon dioxide are utilized to carry out methanation reaction, so that the carbon emission of an electric power system can be reduced, and an effective way is provided for the efficient consumption of new energy. Compared with the traditional fossil energy hydrogen production, the hydrogen production cost can be reduced by one third by utilizing the abandoned wind power to electrolyze water for preparing green hydrogen. Meanwhile, the electric hydrogen conversion, carbon capture and methanation are jointly scheduled, and the hydrogen prepared by electrolysis of renewable energy and the carbon dioxide captured by the carbon capture device are used as methanation raw materials, so that the problem of carbon dioxide utilization can be effectively solved.
At present, low-carbon scheduling research of a power system mostly uses CO 2 The total amount of emissions is not fully taken into account as an optimization objective 2 The effect of the space-time diffusion,at the same time, the land plant can absorb 55 hundred million tons of CO cleanly through photosynthesis for one year 2 Corresponding to 24% of industrial carbon emissions per year, and therefore its CO 2 The influence of concentration distribution is not negligible, and the current research does not consider the carbon sink of plants in natural environment to CO 2 The influence of diffusion causes lower wind power consumption rate and the effect of low-carbon scheduling of the power system is not ideal.
Disclosure of Invention
The invention aims to provide an electricity-hydrogen combined low-carbon scheduling method and system for an electric power system, which can improve the wind power consumption rate and promote the low-carbon emission reduction effect of the electric power system.
In order to achieve the above object, the present invention provides the following solutions:
an electric-hydrogen combined low-carbon dispatching method of an electric power system, wherein the electric power system comprises an electrolytic tank, a carbon capture power plant, a hydrogen storage station, a carbon storage device, a wind farm and a methanation device, the carbon capture power plant comprises a carbon capture device and a thermal power unit, and the electric-hydrogen combined low-carbon dispatching method of the electric power system comprises the following steps:
obtaining electrolysis parameters of an electrolysis cell, a wind power output predicted value, capture parameters of a carbon capture power plant, a topological structure of a hydrogen storage station, transportation parameters, hydrogen storage parameters of the hydrogen storage station, carbon storage parameters of a carbon storage device and methanation parameters;
establishing a model of each link in the low-carbon scheduling process according to the electrolysis parameters of the electrolysis cell, the wind power output predicted value, the capture parameters of the carbon capture power plant, the topological structure of the hydrogen storage station, the transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of the carbon storage device and the methanation parameters of the methanation device;
acquiring carbon emission space-time data of each carbon capture power plant in a scheduling period in a set area;
determining the CO of the carbon capture power plant at each moment in the set area according to the carbon emission space-time data 2 Concentration contribution;
acquiring a normalized air temperature dependence factor, a normalized vegetation index, total solar incident radiation flux and daily average temperature;
determining the total photosynthetic carbon fixation amount of the vegetation in the whole day according to the normalized air temperature dependency factor, the normalized vegetation index, the total solar incident radiation flux and the daily average temperature;
capturing CO of a power plant according to each moment in a set area 2 Concentration contribution quantity and total-day unit vegetation net photosynthetic carbon fixation quantity, and determining free CO at each moment in a set area 2 Concentration;
according to the free CO at each moment in the set area 2 Concentration and CO in a set region 2 Concentration tolerance, determination of free CO 2 Regional concentration constraints;
model based on each link in low-carbon scheduling and free CO 2 Regional concentration constraint, namely, taking the total running cost of the electric power system as a target, establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain a scheduling result; the dispatching result comprises the output of a thermal power unit, the output of a wind power plant, the running path of a mobile hydrogen storage vehicle, the hydrogen transportation quantity, the hydrogen generation rate of an electrolytic tank and the CO of a carbon capture device 2 The capture amount and methane generation rate of the methanation device.
In order to achieve the above purpose, the present invention also provides the following solutions:
an electric-hydrogen combined low-carbon dispatching system of an electric system, wherein the electric system comprises an electrolytic tank, a carbon capture power plant, a hydrogen storage station, a carbon storage device, a wind farm and a methanation device, the carbon capture power plant comprises a carbon capture device and a thermal power unit, and the electric-hydrogen combined low-carbon dispatching system of the electric system comprises:
the parameter acquisition unit is used for acquiring electrolysis parameters of the electrolysis cell, wind power output predicted values, capture parameters of a carbon capture power plant, a topological structure of a hydrogen storage station, transportation parameters, hydrogen storage parameters of the hydrogen storage station, carbon storage parameters of a carbon storage device and methanation parameters;
the link model building unit is connected with the parameter acquisition unit and used for building a model of each link in the low-carbon scheduling process according to the electrolysis parameters of the electrolysis tank, the wind power output predicted value, the capture parameters of the carbon capture power plant, the topological structure of the hydrogen storage station, the transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of the carbon storage device and the methanation parameters of the methanation device;
the space-time data acquisition unit is used for acquiring carbon emission space-time data of each carbon capture power plant in the set area in a dispatching period;
CO 2 a concentration determining unit connected with the space-time data obtaining unit for determining CO of the carbon capture power plant at each moment in the set area according to the carbon emission space-time data 2 Concentration contribution;
the meteorological data acquisition unit is used for acquiring a normalized air temperature dependence factor, a normalized vegetation index, total solar incident radiation flux and daily average temperature;
the carbon sequestration amount determining unit is connected with the meteorological data acquisition unit and is used for determining the total photosynthetic carbon sequestration amount of the vegetation unit in the whole day according to the normalized air temperature dependence factor, the normalized vegetation index, the total solar incident radiation flux and the daily average temperature;
free CO 2 Determination units respectively associated with the CO 2 The concentration determination unit is connected with the carbon fixation amount determination unit and is used for capturing CO of the power plant according to the carbon at each moment in the set area 2 Concentration contribution quantity and total-day unit vegetation net photosynthetic carbon fixation quantity, and determining free CO at each moment in a set area 2 Concentration;
constraint determination unit, associated with the free CO 2 A determining unit connected with the setting area for determining the free CO at each moment 2 Concentration and CO in a set region 2 Concentration tolerance, determination of free CO 2 Regional concentration constraints;
the scheduling unit is respectively connected with the link model establishing unit and the constraint determining unit and is used for based on the model of each link in low-carbon scheduling and the free CO 2 Regional concentration constraint, namely, taking the total running cost of the electric power system as a target, establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain a scheduling result; the dispatching result comprises the output of a thermal power unit, the output of a wind power plant, the running path of a mobile hydrogen storage vehicle, the hydrogen transportation quantity, the hydrogen generation rate of an electrolytic tank and the CO of a carbon capture device 2 Methane generator of collection amount and methanation deviceForming a rate.
According to the specific embodiment provided by the invention, the invention discloses the following technical effects:
the invention determines the CO of the carbon capture power plant at each moment in the set area according to the carbon emission space-time data 2 The concentration contribution quantity is used for determining the net photosynthetic carbon fixation quantity of the vegetation in the whole day unit according to the normalized air temperature dependence factor, the normalized vegetation index, the total solar incident radiation flux and the daily average temperature, and the CO of the carbon capture power plant at each moment in the set area 2 Concentration contribution quantity and total-day unit vegetation net photosynthetic carbon fixation quantity, and determining free CO at each moment in a set area 2 Concentration, then based on model and free CO of each link in low-carbon dispatch 2 And (3) regional concentration constraint, namely, taking the total operation cost of the electric power system as a target, establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain an electric-hydrogen combined low-carbon scheduling result. The invention uses surplus power of the wind power plant to produce hydrogen and captures CO captured by the power plant with carbon 2 Methanation reaction is carried out, and simultaneously, the emission of a thermal power plant and CO generated by plant carbon sink are considered 2 The influence of concentration distribution improves the wind power absorption rate and promotes the low-carbon emission reduction of the power system.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions of the prior art, the drawings that are needed in the embodiments will be briefly described below, it being obvious that the drawings in the following description are only some embodiments of the present invention, 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 flow chart of an electricity-hydrogen combined low-carbon scheduling method of an electric power system of the invention;
FIG. 2 is a schematic block diagram of an electrical-hydrogen combined low-carbon dispatch system for an electrical power system of the present invention.
Symbol description:
parameter acquisition unit-1, link model establishment unit-2, space-time data acquisition unit-3, CO 2 Concentration determining unit-4, meteorological data obtaining unit-5, carbon fixation amount determining unit-6, free CO 2 A determining unit-7, a constraint determining unit-8, and a scheduling unit-9.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
The invention aims to provide an electric-hydrogen combined low-carbon scheduling method and system for an electric power system, which are used for producing hydrogen by surplus electric power of a wind power plant and capturing CO captured by the electric power plant with carbon 2 Methanation reaction is carried out, and simultaneously, the emission of a thermal power plant and plant carbon sink are considered to carry out CO 2 The influence of concentration distribution, the free CO is proposed 2 Concentration index, build up with CO 2 And the regional concentration is a constraint condition, and the total running cost of the system is the minimum electric-hydrogen combined low-carbon scheduling model of the power system of the optimization target, so that the wind power consumption rate is improved, and the low-carbon emission reduction of the power system is promoted.
In order that the above-recited objects, features and advantages of the present invention will become more readily apparent, a more particular description of the invention will be rendered by reference to the appended drawings and appended detailed description.
Example 1
As shown in fig. 1, the embodiment provides an electricity-hydrogen combined low-carbon scheduling method of an electric power system, which includes:
s1: and obtaining electrolysis parameters of the electrolysis tank, wind power output predicted values, capture parameters of a carbon capture power plant, a topological structure of a hydrogen storage station, transportation parameters, hydrogen storage parameters of the hydrogen storage station, carbon storage parameters of a carbon storage device and methanation parameters.
S2: and establishing a model of each link in the low-carbon scheduling process according to the electrolysis parameters of the electrolysis cell, the wind power output predicted value, the capture parameters of the carbon capture power plant, the topological structure of the hydrogen storage station, the transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of the carbon storage device and the methanation parameters of the methanation device. Specifically, models of each link in the low-carbon scheduling process comprise an electrolyzed water process model, a carbon capture power plant model, a mobile hydrogen transportation model, a hydrogen storage model, a carbon storage model and a methanation process model.
In this embodiment, S2 specifically includes:
(21) Establishing an electrolyzed water process model according to the electrolysis parameters of the electrolytic tank and the wind power output predicted value:
wherein ,for the hydrogen generation rate of the electrolytic tank at the time t, eta ERW For the electrolytic efficiency of the electrolyzer, < > for>For the input of electric power to the electrolyzer at time t, < >>For the power-to-volume conversion coefficient of hydrogen, +.>And the predicted value of the wind power output at the time t is obtained.
(22) Establishing a carbon capture power plant model according to the capture parameters of the carbon capture power plant:
wherein ,for the original output of the carbon capture plant u at time t,/>Net output of the carbon capture plant u at time t, < >>For carbon captureCO of power plant u at time t 2 The trapping amount, alpha is the trapping unit CO 2 Energy consumption of->For the basic energy consumption of the carbon capture plant u at time t, < >, of the carbon capture plant u>Capturing CO of a power plant u at time t for carbon 2 The yield, e, is the unit power CO of the carbon capture power plant 2 Emission intensity, gamma is CO of carbon capture power plant 2 Is>Capturing CO of a power plant u at time t for carbon 2 Net emissions.
(23) Establishing a mobile hydrogen transportation model according to the topological structure of the hydrogen storage station and the transportation parameters:
where mn represents the network arcs from hydrogen storage station m to hydrogen storage station n, A is the set of network arcs,for the set of arcs starting from hydrogen storage station m, +.>For the set of arcs ending at hydrogen station m, +.>For the connection state of transport vehicle o to network arc mn during period s +.>Indicating that period s transport vehicle o is on network arc mn,/->Indicating that period s transport vehicle o is not on network arc mn, +.>For the initial state of transport vehicle o +.>For the final state of transporter o, +.>For the connection state of period 1 transport vehicle o to network arc mn, < >>For the connection state of the transport vehicle o and the network arc mn in the final period, NS is the final period.
(24) Establishing a hydrogen storage model according to the hydrogen storage parameters of the hydrogen storage station:
wherein ,for the volume of hydrogen stored in the hydrogen storage station m at time t,/>For the rate of hydrogen production by the electrolyzer in the hydrogen storage station m at time t +.>For the transport of the hydrogen truck at time t, the volume of hydrogen in the hydrogen storage station m is varied,/->Maximum value of the volume of hydrogen which can be accommodated for the hydrogen storage station m, < >>Minimum value of the volume of hydrogen which can be accommodated for the hydrogen storage station m, +.>For the connection of the transport vehicle o to the hydrogen storage station m over the period s, +.>The upper limit value of single transportation of the hydrogen transportation vehicle at the time t is set.
(25) Establishing a carbon storage model according to carbon storage parameters of the carbon storage device:
wherein ,CO in carbon storage device at t moment 2 Storage volume,/->CO is provided for the carbon capture device at the moment t to the carbon storage device 2 Rate of->Supplying CO of methanation reaction for t-moment carbon storage device 2 Rate of->For CO in carbon storage units 2 Maximum memory->For CO in carbon storage units 2 Minimum storage volume, +.>Supplying methanation CO to a carbon storage device 2 Maximum rate.
(26) Establishing a methanation process model according to methanation parameters of the methanation device:
wherein ,CO consumed for methanation reaction at time t 2 ，/>For methanation of hydrogen and CO 2 Reaction coefficient ratio,/>Hydrogen consumed for methanation at time t +.>For the rate of methane formation at time t, η ME For the conversion efficiency of the methane generator, +.>For the methane power volume conversion factor, < >>CO captured from the atmosphere for a methanation process at time t 2 Quantity (S)>Is the maximum hydrogen input rate to the methanation unit.
The time t is any time in the scheduling period.
S3: and acquiring carbon emission space-time data of each carbon capture power plant in the set area in a dispatching period. Specifically, the carbon emission spatiotemporal data includes CO of the carbon capture plant at each time 2 Emission and carbon capture of CO emitted by a power plant 2 Diffusion parameters in horizontal direction and carbon capture plant-emitted CO 2 Diffusion parameters in vertical direction and CO discharged by carbon capture power plant 2 Is defined by the center coordinates of the lens.
S4: determining the CO of the carbon capture power plant at each moment in the set area according to the carbon emission space-time data 2 Concentration contribution. In the present embodiment, by establishing CO 2 Space-time diffusion model for calculating CO 2 Concentration contribution.
Specifically, t in the region (x, y) is determined using the following formula k CO of a time-of-day carbon capture plant 2 Concentration contribution:
wherein ,C(tk X, y) is t in the region (x, y) k CO of a time-of-day carbon capture plant 2 Concentration contribution, N is the number of carbon capture plants in the power system, k is t k Sequence number of time, V u,net (i+1) is the carbon capture plant u at t i CO at the moment of time 2 Emission, G (t) i ,t k X, y) is a distribution function, sigma y (t i ,t k ) At t for a carbon capture plant i CO emitted at a moment 2 At t k Diffusion parameter, sigma, in the horizontal direction of the moment y (t i ,t k-1 ) At t for a carbon capture plant i CO emitted at a moment 2 At t k-1 Diffusion parameter, sigma, in the horizontal direction of the moment z (t i ,t k ) At t for a carbon capture plant i CO emitted at a moment 2 At t k Diffusion parameter, sigma, in the vertical direction of the moment z (t i ,t k-1 ) At t for a carbon capture plant i CO emitted at a moment 2 At t k-1 Diffusion parameter in the vertical direction of time, (x) u (t i ,t k ),y u (t i ,t k ),z u (t i ,t k ) At t) for a carbon capture plant u i CO emitted at a moment 2 At t k Center coordinates of time, (x) u0 ,y u0 ,z u0 ) For the discharge position, u (k ') is an east-west wind speed vector, v (k ') is a north-south wind speed vector, w (k ') is a vertical wind speed vector, Δt is a time interval, α (k) is a first constant, β (k) is a second constant, a (k) is a third constant, b (k) is a fourth constant, and α (k), β (k), a (k), and b (k) are constants related to the atmospheric stability level.
Because of CO 2 Space-time diffusion model is required to distinguish CO discharged by carbon capture power plant 2 Time t of (2) i And the CO 2 The effect of emissions on the later moments, therefore by t i and tk Distinguishing two moments, t i <t k 。
Due to variations of meteorological elements during periodsCO is converted into 2 The diffusion capacities of two adjacent time periods are different, and the diffusion parameters of two adjacent time periods meet the continuity of the smoke mass diffusion profile, so that the calculation formula of the diffusion parameters is improved:
s5: and obtaining a normalized air temperature dependence factor, a normalized vegetation index, total solar incident radiation flux and daily average temperature.
S6: and determining the total photosynthetic carbon fixation amount of the vegetation in the whole day according to the normalized air temperature dependency factor, the normalized vegetation index, the total solar incident radiation flux and the daily average temperature. In this example, the net photosynthetic carbon sequestration amount per unit of vegetation throughout the day is determined by building a ground plant carbon sequestration model.
In this embodiment, S6 specifically includes:
(61) Calculating the total amount of organic carbon fixed by the vegetation of the whole day unit according to the normalized air temperature dependence factor, the normalized vegetation index and the total solar incident radiation flux:
C GPP,d ＝0.539p(T atm )(1.1638NDVI-0.1426)B g,d ；
wherein ,CGPP,d Total organic carbon amount, p (T atm ) In order to normalize the air temperature dependence factor,ΔH a,P the molecular energy is 52750 and delta H d,p Is inert molecular energy, has a value of 211000, T is Kelvin temperature, NDVI is normalized vegetation index, (1.1638 NDVI-0.1426) is effective photosynthesis radiation proportion absorbable by vegetation, and B g,d The total radiant flux is incident for the sun.
(62) Calculating the net photosynthetic carbon fixation amount of the whole-day unit vegetation according to the total organic carbon amount fixed by the whole-day unit vegetation and the daily average temperature:
wherein ,CNPP,d The net photosynthetic carbon fixation amount of the vegetation is the whole day unit, C GPPd Total organic carbon amount, T, fixed for vegetation of whole day unit a Is the average temperature of day (7.825+1.145T) a ) Is the vegetation autotrophic respiration rate.
S7: capturing CO of a power plant according to each moment in a set area 2 Concentration contribution quantity and total-day unit vegetation net photosynthetic carbon fixation quantity, and determining free CO at each moment in a set area 2 Concentration.
Specifically, t in the region (x, y) is determined using the following formula k Free CO at time 2 Concentration:
wherein C' (t) k X, y) is t after plant carbon fixation in the region (x, y) k Free CO at time 2 Concentration, land ecosystem actual CO 2 Conversion of capture into net absorption of CO by land ecosystem 2 The amount was 1:3.667, and the conversion ratio was C (t k X, y) is t in the region (x, y) k CO of a time-of-day carbon capture plant 2 Concentration contribution, k is t k The sequence number of the moment, deltat is the time interval, Γ is the total period in the scheduling period, C NPP,d The net photosynthetic carbon fixation amount of the vegetation is the unit of whole day.
S8: according to the free CO at each moment in the set area 2 Concentration and CO in a set region 2 Concentration tolerance, determination of free CO 2 Regional concentration constraints: wherein ,/>CO as region (x, y) 2 Concentration tolerance.
S9: model based on each link in low-carbon scheduling and free CO 2 Regional concentration constraints, at the total operating cost of the power systemAnd (3) establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain a scheduling result. In the embodiment, a solver is adopted to solve an electric-hydrogen combined low-carbon scheduling model of the electric power system.
In practical application, the input data of the electric-hydrogen combined low-carbon dispatching model of the electric power system comprises electric power-traffic coupling network topology, wind power predicted output, load predicted power, daily average air temperature, total solar radiation flux, normalized ground vegetation index and other configuration parameters.
The dispatching result comprises the output of a thermal power unit, the output of a wind power plant, the running path of a mobile hydrogen storage vehicle, the hydrogen transportation quantity, the hydrogen generation rate of an electrolytic tank and the CO of a carbon capture device 2 Capture amount, methane generation rate of methanation device and atmospheric CO at monitoring point 2 Concentration, etc.
Specifically, the objective function of the electric-hydrogen combined low-carbon scheduling model of the electric power system is as follows:
MinimizeC Σ ＝C u +C me +C curt +C tran ；
wherein ,CΣ C is the total running cost of the power system u For the cost of thermal power fuel, a u 、b u 、c u 、d u Is the fuel cost coefficient of the thermal power unit, C me For methanation process cost, c air To capture a unit volume of CO from the atmosphere 2 Cost required, c g In order to sell the benefit of methane per unit volume,CO captured from the atmosphere at time t for methanation unit m 2 Quantity (S)>C, the rate of generating methane by methanation reaction of methanation device m at t moment curt The wind discarding cost of the power system is c e Cost per unit electric quantity of abandoned wind->Predicted wind power output (obtained according to historical data) at time t for the w-th wind farm,/->For the actual supply power of the w-th wind farm at time t, < >>For inputting electric power of the electrolyzer at time t in the w-th wind power station, C tran For hydrogen transportation cost, c k,mn Is the cost of single transportation between hydrogen storage station m and hydrogen storage station n.
Constraint conditions of the electric-hydrogen combined low-carbon scheduling model of the electric power system comprise models of all links in low-carbon scheduling and free CO 2 Regional concentration constraints, unit operation constraints, and supply-demand balance constraints.
The unit operation constraint comprises a thermal power unit operation power constraint P u min ≤P u t ≤P u max Climbing constraint of thermal power generating unit:and wind-electricity output constraint->
wherein ,for the original output of the carbon capture plant u at time t,/>For the original output power of the carbon capture power plant u at the time t-1, P u min For minimum output power of carbon capture plant u, P u max Maximum output power for carbon capture plant u, RU u For the climbing rate, RD, of the carbon capture power plant u per unit time u For the downhill speed per unit time of the carbon capture plant u +.>For the actual supply power of the w-th wind farm at time t, < >>Predicting wind power output of a w-th wind power plant at the time t;
the supply and demand balance constraint is as follows.
wherein ,net output of the carbon capture plant u at time t, < >>The load power required by the load node d at time t.
The invention uses surplus power of the wind power plant to produce hydrogen and captures CO captured by the power plant with carbon 2 Methanation reaction is carried out, and simultaneously, the emission of a thermal power plant and plant carbon sink are considered to carry out CO 2 The influence of concentration distribution, the free CO is proposed 2 Concentration index, taking environmental bearing capacity difference into consideration, and constructing CO 2 Concentration differentiation constraint conditions are established by CO 2 The regional concentration is a constraint condition, and the total running cost of the system is minimum to consider CO of an optimization target 2 Concentration space-time distribution constraint electric-hydrogen combined low-carbon scheduling model of electric power system, which can effectively improve wind power consumption rate and promote electric power systemThe system runs at low carbon, and can provide a direction for energy conservation and emission reduction in key areas of the power system.
Example two
In order to execute the corresponding method of the above embodiment to achieve the corresponding functions and technical effects, an electric-hydrogen combined low-carbon dispatching system of an electric power system is provided below.
The electric power system comprises an electrolytic tank, a carbon capture power plant, a hydrogen storage station, a carbon storage device, a wind power plant and a methanation device, wherein the carbon capture power plant comprises a carbon capture device and a thermal power unit.
As shown in fig. 2, the electric-hydrogen combined low-carbon dispatching system of the electric power system provided in the embodiment includes: parameter acquisition unit 1, link model establishment unit 2, spatio-temporal data acquisition unit 3, CO 2 Concentration determination unit 4, meteorological data acquisition unit 5, carbon sequestration amount determination unit 6, free CO 2 Determination unit 7, constraint determination unit 8 and scheduling unit 9.
The parameter acquisition unit 1 is used for acquiring electrolysis parameters of the electrolytic tank, wind power output predicted values, capture parameters of a carbon capture power plant, a topological structure of a hydrogen storage station, transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of a carbon storage device and methanation parameters.
The link model building unit 2 is connected with the parameter obtaining unit 1, and the link model building unit 2 is used for building a model of each link in the low-carbon scheduling process according to the electrolysis parameters of the electrolytic tank, the wind power output predicted value, the trapping parameters of the carbon trapping power plant, the topological structure of the hydrogen storage station, the transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of the carbon storage device and the methanation parameters of the methanation device.
The space-time data acquisition unit 3 is used for acquiring carbon emission space-time data of each carbon capture power plant in the set area in a dispatching cycle.
CO 2 The concentration determining unit 4 is connected with the space-time data acquiring unit 3, and CO 2 The concentration determination unit 4 is used for determining the CO of the carbon capture power plant at each moment in the set area according to the carbon emission space-time data 2 Concentration contribution.
The meteorological data acquisition unit 5 is used for acquiring a normalized air temperature dependence factor, a normalized vegetation index, a total solar incident radiation flux and a daily average temperature.
The carbon sequestration amount determining unit 6 is connected with the meteorological data obtaining unit 5, and the carbon sequestration amount determining unit 6 is used for determining the total photosynthetic carbon sequestration amount of the unit vegetation in the whole day according to the normalized air temperature dependence factor, the normalized vegetation index, the total solar incident radiation flux and the daily average temperature.
Free CO 2 The determination unit 7 is respectively connected with the CO 2 The concentration determination unit 4 and the carbon fixation amount determination unit 6 are connected with each other to form free CO 2 The determination unit 7 is used for capturing CO of the power plant according to each moment in the set area 2 Concentration contribution quantity and total-day unit vegetation net photosynthetic carbon fixation quantity, and determining free CO at each moment in a set area 2 Concentration.
Constraint determination unit 8 and the free CO 2 The determination unit 7 is connected with the constraint determination unit 8 for determining the free CO according to each moment in the set area 2 Concentration and CO in a set region 2 Concentration tolerance, determination of free CO 2 Regional concentration constraints.
The scheduling unit 9 is respectively connected with the link model establishing unit 2 and the constraint determining unit 8, and the scheduling unit 9 is used for based on the model of each link in low-carbon scheduling and the free CO 2 And (3) regional concentration constraint, namely, taking the total operation cost of the electric power system as a target, establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain a scheduling result. The dispatching result comprises the output of a thermal power unit, the output of a wind power plant, the running path of a mobile hydrogen storage vehicle, the hydrogen transportation quantity, the hydrogen generation rate of an electrolytic tank and the CO of a carbon capture device 2 The capture amount and methane generation rate of the methanation device.
Compared with the prior art, the electric-hydrogen combined low-carbon dispatching system of the electric power system provided by the embodiment has the same beneficial effects as the electric-hydrogen combined low-carbon dispatching method of the electric power system provided by the embodiment, and is not repeated here.
Example III
The embodiment provides an electronic device, including a memory and a processor, where the memory is configured to store a computer program, and the processor is configured to run the computer program to cause the electronic device to execute the electric power system electricity-hydrogen combined low-carbon scheduling method of the first embodiment.
Alternatively, the electronic device may be a server.
In addition, the embodiment of the invention also provides a computer readable storage medium, which stores a computer program, and the computer program realizes the electric-hydrogen combined low-carbon scheduling method of the electric power system of the first embodiment when being executed by a processor.
In the present specification, each embodiment is described in a progressive manner, and each embodiment is mainly described in a different point from other embodiments, and identical and similar parts between the embodiments are all enough to refer to each other.
The principles and embodiments of the present invention have been described herein with reference to specific examples, the description of which is intended only to assist in understanding the methods of the present invention and the core ideas thereof; also, it is within the scope of the present invention to be modified by those of ordinary skill in the art in light of the present teachings. In view of the foregoing, this description should not be construed as limiting the invention.
Claims (10)
1. The utility model provides a power system electricity-hydrogen allies oneself with low carbon dispatch method, including electrolysis trough, carbon capture power plant, hydrogen storage station, carbon storage device, wind-powered electricity generation field and methanation device in the power system, carbon capture power plant includes carbon capture device and thermal power unit, its characterized in that, power system electricity-hydrogen allies oneself with low carbon dispatch method includes:
obtaining electrolysis parameters of an electrolysis cell, a wind power output predicted value, capture parameters of a carbon capture power plant, a topological structure of a hydrogen storage station, transportation parameters, hydrogen storage parameters of the hydrogen storage station, carbon storage parameters of a carbon storage device and methanation parameters;
establishing a model of each link in the low-carbon scheduling process according to the electrolysis parameters of the electrolysis cell, the wind power output predicted value, the capture parameters of the carbon capture power plant, the topological structure of the hydrogen storage station, the transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of the carbon storage device and the methanation parameters of the methanation device;
acquiring carbon emission space-time data of each carbon capture power plant in a scheduling period in a set area;
determining the CO of the carbon capture power plant at each moment in the set area according to the carbon emission space-time data 2 Concentration contribution;
acquiring a normalized air temperature dependence factor, a normalized vegetation index, total solar incident radiation flux and daily average temperature;
determining the total photosynthetic carbon fixation amount of the vegetation in the whole day according to the normalized air temperature dependency factor, the normalized vegetation index, the total solar incident radiation flux and the daily average temperature;
capturing CO of a power plant according to each moment in a set area 2 Concentration contribution quantity and total-day unit vegetation net photosynthetic carbon fixation quantity, and determining free CO at each moment in a set area 2 Concentration;
according to the free CO at each moment in the set area 2 Concentration and CO in a set region 2 Concentration tolerance, determination of free CO 2 Regional concentration constraints;
model based on each link in low-carbon scheduling and free CO 2 Regional concentration constraint, namely, taking the total running cost of the electric power system as a target, establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain a scheduling result; the dispatching result comprises the output of a thermal power unit, the output of a wind power plant, the running path of a mobile hydrogen storage vehicle, the hydrogen transportation quantity, the hydrogen generation rate of an electrolytic tank and the CO of a carbon capture device 2 The capture amount and methane generation rate of the methanation device.
2. The electric-hydrogen combined low-carbon dispatching method of the electric power system according to claim 1, wherein the models of all links in the low-carbon dispatching process comprise an electrolytic water process model, a carbon capture power plant model, a mobile hydrogen transportation model, a hydrogen storage model, a carbon storage model and a methanation process model;
according to the electrolysis parameters of the electrolysis cell, the wind power output predicted value, the capture parameters of the carbon capture power plant, the topological structure of the hydrogen storage station, the transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of the carbon storage device and the methanation parameters of the methanation device, a model of each link in the low-carbon scheduling process is established, and the method specifically comprises the following steps:
establishing an electrolytic water process model according to the electrolysis parameters of the electrolytic tank and the wind power output predicted value;
establishing a carbon capture power plant model according to the capture parameters of the carbon capture power plant;
establishing a mobile hydrogen transportation model according to the topological structure of the hydrogen storage station and the transportation parameters;
establishing a hydrogen storage model according to the hydrogen storage parameters of the hydrogen storage station;
establishing a carbon storage model according to carbon storage parameters of the carbon storage device;
and establishing a methanation process model according to the methanation parameters of the methanation device.
3. The power system electricity-hydrogen combined low-carbon dispatch method of claim 1, wherein the carbon emission spatiotemporal data comprises CO of a carbon capture plant at each moment in time 2 Emission and carbon capture of CO emitted by a power plant 2 Diffusion parameters in horizontal direction and carbon capture plant-emitted CO 2 Diffusion parameters in vertical direction and CO discharged by carbon capture power plant 2 Is defined by the center coordinates of (a);
the following formula is used to determine t in the region (x, y) k CO of a time-of-day carbon capture plant 2 Concentration contribution:
wherein ,C(tk X, y) is t in the region (x, y) k CO of a time-of-day carbon capture plant 2 Concentration contribution, N is the number of carbon capture plants in the power system, k is t k Sequence number of time, V u,net (i+1) is the carbon capture plant u at t i CO at the moment of time 2 Emission, G (t) i ,t k X, y) is a distribution function, sigma y (t i ,t k ) At t for a carbon capture plant i CO emitted at a moment 2 At t k Diffusion parameter, sigma, in the horizontal direction of the moment y (t i ,t k-1 ) At t for a carbon capture plant i CO emitted at a moment 2 At t k-1 Diffusion parameter, sigma, in the horizontal direction of the moment z (t i ,t k ) At t for a carbon capture plant i CO emitted at a moment 2 At t k Diffusion parameter, sigma, in the vertical direction of the moment z (t i ,t k-1 ) At t for a carbon capture plant i CO emitted at a moment 2 At t k-1 Diffusion parameter in the vertical direction of time, (x) u (t i ,t k ),y u (t i ,t k ),z u (t i ,t k ) At t) for a carbon capture plant u i CO emitted at a moment 2 At t k Center coordinates of time, (x) u0 ,y u0 ,z u0 ) For the discharge position, u (k ') is an east-west wind speed vector, v (k ') is a north-south wind speed vector, w (k ') is a vertical wind speed vector, Δt is a time interval, α (k) is a first constant, β (k) is a second constant, a (k) is a third constant, and b (k) is a fourth constant.
4. The electrical-hydrogen combined low-carbon scheduling method of the electrical power system of claim 1, wherein determining a total daily unit vegetation net photosynthetic carbon fixation amount according to the normalized air temperature dependence factor, the normalized vegetation index, the solar incident total radiant flux and the daily average temperature specifically comprises:
calculating the total amount of organic carbon fixed by the vegetation of the whole day unit according to the normalized air temperature dependence factor, the normalized vegetation index and the total solar incident radiation flux;
and calculating the net photosynthetic carbon fixation amount of the whole-day unit vegetation according to the total organic carbon fixed by the whole-day unit vegetation and the daily average temperature.
5. The electrical-hydrogen joint low-carbon scheduling method of an electrical power system of claim 4, wherein the total amount of organic carbon fixed per unit of vegetation throughout the day is calculated using the formula:
C GPP,d ＝0.539p(T atm )(1.1638NDVI-0.1426)B g,d ；
wherein ,CGPP,d Total organic carbon amount, p (T atm ) For normalizing the air temperature dependence factor, NDVI is normalized vegetation index, B g,d The total radiant flux is incident for the sun.
6. The electrical-hydrogen joint low-carbon scheduling method of an electrical system of claim 4, wherein the net photosynthetic carbon sequestration amount per unit of vegetation throughout the day is calculated using the formula:
wherein ,CNPP,d The net photosynthetic carbon fixation amount of the vegetation is the whole day unit, C GPPd Total organic carbon amount, T, fixed for vegetation of whole day unit a Is the daily average temperature.
7. The power system electricity-hydrogen combined low-carbon dispatch method of claim 1, wherein t in the region (x, y) is determined using the following formula k Free CO at time 2 Concentration:
wherein C' (t) k X, y) is t in the region (x, y) k Free CO at time 2 Concentration, C (t) k X, y) is t in the region (x, y) k CO of a time-of-day carbon capture plant 2 Concentration contribution, k is t k The sequence number of the moment, deltat is the time interval, Γ is the total period in the scheduling period, C NPP,d The net photosynthetic carbon fixation amount of the vegetation is the unit of whole day.
8. The electrical power system electricity-hydrogen joint low carbon dispatch method of claim 1, wherein the electrical power system electricity-hydrogen joint low carbon dispatch model has an objective function of:
Minimize C Σ ＝C u +C me +C curt +C tran ；
wherein ,CΣ C is the total running cost of the power system u For the cost of thermal power fuel, C me For methanation process cost, C curt C, the wind discarding cost of the power system is C tran Is the cost of hydrogen transportation.
9. The electric power system electricity-hydrogen combined low-carbon scheduling method according to claim 1, wherein constraint conditions of the electric power system electricity-hydrogen combined low-carbon scheduling model further comprise unit operation constraint and supply-demand balance constraint;
the unit operation constraint is as follows:
wherein ,Pu t For the original output power of the carbon capture power plant u at the time t, P u t-1 For the original output power of the carbon capture power plant u at the time t-1, P u min For minimum output power of carbon capture plant u, P u max Maximum output power for carbon capture plant u, RU u For the climbing rate, RD, of the carbon capture power plant u per unit time u For the downhill rate per unit time of the carbon capture plant u,for the actual supply power of the w-th wind farm at time t, < >>Predicting wind power output of a w-th wind power plant at the time t;
the supply and demand balance constraint is as follows:
wherein ,net output of the carbon capture plant u at time t, < >>The load power required by the load node d at time t.
10. Electric power system electricity-hydrogen unites low carbon dispatch system, including electrolysis trough, carbon entrapment power plant, hydrogen storage station, carbon storage device, wind-powered electricity generation field and methanation device in the electric power system, the carbon entrapment power plant includes carbon entrapment device and thermal power generating unit, its characterized in that, electric power system electricity-hydrogen unites low carbon dispatch system includes:
the parameter acquisition unit is used for acquiring electrolysis parameters of the electrolysis cell, wind power output predicted values, capture parameters of a carbon capture power plant, a topological structure of a hydrogen storage station, transportation parameters, hydrogen storage parameters of the hydrogen storage station, carbon storage parameters of a carbon storage device and methanation parameters;
the link model building unit is connected with the parameter acquisition unit and used for building a model of each link in the low-carbon scheduling process according to the electrolysis parameters of the electrolysis tank, the wind power output predicted value, the capture parameters of the carbon capture power plant, the topological structure of the hydrogen storage station, the transportation parameters, the hydrogen storage parameters of the hydrogen storage station, the carbon storage parameters of the carbon storage device and the methanation parameters of the methanation device;
the space-time data acquisition unit is used for acquiring carbon emission space-time data of each carbon capture power plant in the set area in a dispatching period;
CO 2 a concentration determining unit connected with the space-time data obtaining unit for determining CO of the carbon capture power plant at each moment in the set area according to the carbon emission space-time data 2 Concentration contribution;
the meteorological data acquisition unit is used for acquiring a normalized air temperature dependence factor, a normalized vegetation index, total solar incident radiation flux and daily average temperature;
the carbon sequestration amount determining unit is connected with the meteorological data acquisition unit and is used for determining the total photosynthetic carbon sequestration amount of the vegetation unit in the whole day according to the normalized air temperature dependence factor, the normalized vegetation index, the total solar incident radiation flux and the daily average temperature;
free CO 2 Determination units respectively associated with the CO 2 The concentration determination unit is connected with the carbon fixation amount determination unit and is used for capturing CO of the power plant according to the carbon at each moment in the set area 2 Concentration contribution quantity and total-day unit vegetation net photosynthetic carbon fixation quantity, and determining free CO at each moment in a set area 2 Concentration;
constraint determination unit, associated with the free CO 2 A determining unit connected with the setting area for determining the free CO at each moment 2 Concentration and CO in a set region 2 Concentration tolerance, determination of free CO 2 Regional concentration constraints;
the scheduling unit is respectively connected with the link model establishing unit and the constraint determining unit and is used for based on the model of each link in low-carbon scheduling and the free CO 2 Regional concentration constraint, namely, taking the total running cost of the electric power system as a target, establishing an electric-hydrogen combined low-carbon scheduling model of the electric power system, and solving to obtain a scheduling result; the dispatching result comprises the output of a thermal power unit, the output of a wind power plant, the running path of a mobile hydrogen storage vehicle, the hydrogen transportation quantity, the hydrogen generation rate of an electrolytic tank and the CO of a carbon capture device 2 The capture amount and methane generation rate of the methanation device.
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