CN111767274A

CN111767274A - Photovoltaic power station power generation time calculation method and system

Info

Publication number: CN111767274A
Application number: CN202010582444.6A
Authority: CN
Inventors: 陈朋朋; 王�忠; 王涛; 张彦虎
Original assignee: Hefei Sungrow New Energy Technology Co Ltd
Current assignee: Hefei Sungrow New Energy Technology Co Ltd
Priority date: 2020-06-23
Filing date: 2020-06-23
Publication date: 2020-10-13

Abstract

The invention discloses a method and a system for calculating the power generation time of a photovoltaic power station. The method for calculating the power generation time of the photovoltaic power station comprises the steps of obtaining power generation time data of original power stations around a power station to be evaluated; determining a first correction coefficient according to the operation data and the environment data of the power station to be evaluated and the original power station; determining a second correction coefficient according to the operation data and the environment data of the prediction period and the typical period of the power station to be evaluated; and calculating the power generation time of the power station to be evaluated in a typical period based on the first correction coefficient, the second correction coefficient and the power generation time data of the original power station. According to the technical scheme, the actual power generation time length data of the power stations established around the power station to be evaluated is introduced to calculate the typical power generation time length data of the power station to be evaluated, and the accuracy of calculating the power generation time length of the photovoltaic power station is effectively improved, so that investment loss is reduced for investment and financing mechanisms and photovoltaic power station construction enterprises.

Description

Photovoltaic power station power generation time calculation method and system

Technical Field

The embodiment of the invention relates to the technical field of photovoltaic power generation, in particular to a method and a system for calculating the power generation time of a photovoltaic power station.

Background

The evaluation of the photovoltaic power station power generation time is concerned about the investment and financing transaction price and the selling price of the photovoltaic power station, and the enterprise loss can be caused if the evaluation is improper. At present, two methods for evaluating the power generation time of a photovoltaic power station are mainly used: (1) determining typical annual irradiation equivalent duration data and typical annual system efficiency data of the power station to be evaluated based on the typical annual meteorological data of the power station to be evaluated by using simulation software, and calculating annual power generation equivalent duration of the power station to be evaluated according to the typical annual irradiation equivalent duration data and the typical annual system efficiency data of the power station to be evaluated; (2) and collecting actual power generation time data of the peripheral photovoltaic power stations of the power station to be evaluated, and replacing the power generation time data of the power station to be evaluated with the actual power generation time data of the peripheral power stations.

However, in the method (1), the difference between the typical annual irradiation equivalent duration data and the typical annual system efficiency data of the power station to be evaluated, which are obtained through simulation software, and the real data is large, so that the annual power generation equivalent duration of the power station to be evaluated is not accurately calculated; in the method (2), the actual power generation duration data of the peripheral power stations is used for replacing the power generation duration data of the power station to be evaluated, and the actual difference between the peripheral power stations and the power station to be evaluated is not considered, so that the power generation duration evaluation of the power station to be evaluated has a large error.

Disclosure of Invention

The embodiment of the invention provides a method and a system for calculating the power generation time of a photovoltaic power station, which aim to improve the accuracy of calculating the power generation time of the photovoltaic power station and reduce investment loss for investment and financing mechanisms and photovoltaic power station construction enterprises.

In a first aspect, an embodiment of the present invention provides a method for calculating a power generation time of a photovoltaic power station, including:

acquiring power generation time length data of original power stations around a power station to be evaluated;

determining a first correction coefficient according to the operating data and the environmental data of the power station to be evaluated and the original power station, wherein the first correction coefficient is used for correcting the power generation duration data of the original power station to obtain the power generation duration data of the power station to be evaluated in a prediction period;

determining a second correction coefficient according to the operation data and the environment data of the prediction period and the typical period of the power station to be evaluated, wherein the second correction coefficient is used for correcting the power generation time length data of the power station to be evaluated in the prediction period so as to obtain the power generation time length data of the power station to be evaluated in the typical period;

and calculating the power generation time of the power station to be evaluated in a typical period based on the first correction coefficient, the second correction coefficient and the power generation time data of the original power station.

Optionally, the operating data includes system efficiency data, and the environmental data includes irradiation duration data;

determining a first correction coefficient according to the operation data and the environment data of the power station to be evaluated and the original power station, wherein the first correction coefficient comprises the following steps:

determining the relationship between the irradiation duration and the power generation duration of the power station to be evaluated in the prediction period and the system efficiency;

determining the relationship between the irradiation duration and the power generation duration of the original power station in a set period and the system efficiency;

and establishing a proportional relation of the power generation time of the power station to be evaluated and the power generation time of the original power station, wherein a proportional coefficient of the power generation time of the power station to be evaluated and the power generation time of the original power station comprises a ratio of the irradiation time and a ratio of the system efficiency, and the proportional coefficient of the power generation time of the power station to be evaluated and the power generation time of the original power station is a first correction coefficient.

Optionally, replacing the ratio of the system efficiency in the proportionality coefficient by the ratio of the simulated value of the system efficiency of the power station to be evaluated and the original power station;

replacing the ratio of the irradiation duration in the proportional coefficient by the ratio of the estimated value of the irradiation duration of the power station to be evaluated and the original power station;

wherein the first correction coefficient includes a ratio of an estimated value of the irradiation time of the power station to be evaluated and the original power station and a ratio of a simulated value of the system efficiency.

Optionally, the relationship between the irradiation duration, the power generation duration and the system efficiency of the power station to be evaluated in the prediction period is represented as:

T_{to-be-estimated-true-T1}＝G_{to-be-estimated-true-T1}·PR_{to-be-estimated-true-T1}；

The relationship between the irradiation duration, the power generation duration and the system efficiency of the original power station in a set period is expressed as follows:

T_{original building-true-T2}＝G_{Original building-true-T2}·PR_{Original building-true-T2}；

The proportional relation of the power generation time of the power station to be evaluated and the power station of the original building is expressed as follows:

replacing the ratio of the system efficiency in the proportionality coefficient by the ratio of the simulated value of the system efficiency of the power station to be evaluated and the original power station; after the ratio of the estimated value of the irradiation duration of the power station to be evaluated to the original power station is adopted to replace the ratio of the irradiation duration in the proportional coefficient, the proportional relation of the power generation duration of the power station to be evaluated to the original power station is expressed as follows:

wherein the first correction coefficient is expressed as:

wherein, T_{to-be-estimated-true-T1}For the generating time length G of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the irradiation duration, PR, of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the system efficiency, G, of the power station to be evaluated in the prediction period_{To be estimated-X-T1}Is to be ratedEstimate of the irradiation duration, PR, of the plant in the prediction period_{To be estimated-X-T1}Is a simulated value, T, of the system efficiency of the power station to be evaluated in a prediction period_{Original building-true-T2}For the power generation duration G of the original power station in a set period_{Original building-true-T2}The irradiation duration, PR, of the original power station in a set period_{Original building-true-T2}For the system efficiency, G, of the original power station in a set period_{Original building-X-T2}For estimating the irradiation duration of the power station in a set period, PR_{Original building-X-T2}And the simulation value is the simulation value of the system efficiency of the original power station in a set period.

Optionally, the simulated values of the system efficiency comprise determined losses and uncertain losses of the photovoltaic power station;

the determining loss comprises at least: shadow irradiation loss, relative transmittance loss, weak light loss, temperature loss, shadow electrical loss, light-induced attenuation loss, component mismatch loss, direct current cable loss, inverter system efficiency loss, alternating current cable loss and transformer loss;

the uncertainty loss includes at least: dust losses and system unavailability losses.

determining a second correction coefficient according to the operation data and the environment data of the prediction period and the typical period of the power station to be evaluated, wherein the second correction coefficient comprises the following steps:

determining the relationship among the irradiation duration, the power generation duration and the system efficiency of the power station to be evaluated in a typical period;

and establishing a proportional relation between the prediction period of the power station to be evaluated and the power generation time of the typical period, wherein a proportional coefficient between the prediction period of the power station to be evaluated and the power generation time of the typical period comprises a ratio of the irradiation time and a ratio of the system efficiency, and the proportional coefficient between the prediction period of the power station to be evaluated and the power generation time of the typical period is a second correction coefficient.

Optionally, replacing the ratio of the system efficiency in the proportionality coefficient by the ratio of the simulated value of the system efficiency of the prediction period and the typical period of the power station to be evaluated;

replacing the ratio of the irradiation duration in the proportional coefficient by the ratio of the estimated value of the irradiation duration of the prediction period and the typical period of the power station to be evaluated;

wherein the second correction coefficient includes a ratio of a predicted period of the power station to be evaluated to an estimated value of the irradiation time period of a typical period and a ratio of a simulated value of the system efficiency.

The relationship among the irradiation duration, the power generation duration and the system efficiency of the power station to be evaluated in the typical period is represented as follows:

T_{to estimate-true-T}＝G_{To estimate-true-T}·PR_{To estimate-true-T}；

The proportional relation between the prediction period of the power station to be evaluated and the power generation time of the typical period is expressed as follows:

replacing the ratio of the system efficiency in the proportionality coefficient by the ratio of the simulated value of the system efficiency of the prediction period and the typical period of the power station to be evaluated; after the ratio of the irradiation duration of the prediction period and the typical period of the power station to be evaluated is adopted to replace the ratio of the irradiation duration in the proportionality coefficient, the proportional relation of the power generation duration of the power station to be evaluated and the power generation duration of the original power station is expressed as follows:

wherein the second correction coefficient is:

wherein, T_{to-be-estimated-true-T1}For the generating time length G of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the irradiation duration, PR, of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the system efficiency, G, of the power station to be evaluated in the prediction period_{To be estimated-X-T1}For the estimation of the irradiation duration of the power station to be evaluated in the prediction period, PR_{To be estimated-X-T1}Is a simulated value, T, of the system efficiency of the power station to be evaluated in a prediction period_{To estimate-true-T}For the generation duration, G, of the power station to be evaluated in a typical period_{To estimate-true-T}For the irradiation duration, PR, of the power station to be evaluated in a typical cycle_{To estimate-true-T}For the system efficiency of the power station to be evaluated in a typical period, G_{To estimate-X-T}For the evaluation of the irradiation duration of the power station to be evaluated in a typical cycle, PR_{To estimate-X-T}Is a simulated value of the system efficiency of the power station to be evaluated in a typical period.

Optionally, the power generation time of the power station to be evaluated in the typical period is calculated as:

wherein, T_{To estimate-true-T}For the generation duration, G, of the power station to be evaluated in a typical period_{To estimate-X-T}For the evaluation of the irradiation duration of the power station to be evaluated in a typical cycle, PR_{To estimate-X-T}Is a simulated value of the system efficiency of the power station to be evaluated in a typical period, T_{Original building-true-T2}For the power generation duration G of the original power station in a set period_{Original building-X-T2}For the irradiation duration of the original power station in a set periodIs estimated, PR_{Original building-X-T2}And the simulation value is the simulation value of the system efficiency of the original power station in a set period.

In a second aspect, an embodiment of the present invention further provides a system for calculating a power generation time of a photovoltaic power station, including:

the first power generation duration data acquisition module is used for acquiring power generation duration data of original power stations around the power station to be evaluated;

the first correction coefficient determining module is used for determining a first correction coefficient according to the operating data and the environmental data of the power station to be evaluated and the original power station, wherein the first correction coefficient is used for correcting the power generation duration data of the original power station to obtain the power generation duration data of the power station to be evaluated in a prediction period;

the second correction coefficient determining module is used for determining a second correction coefficient according to the operation data and the environment data of the prediction period and the typical period of the power station to be evaluated, wherein the second correction coefficient is used for correcting the power generation duration data of the power station to be evaluated in the prediction period so as to obtain the power generation duration data of the power station to be evaluated in the typical period;

and the second generating time length data calculating module is used for calculating the generating time length of the power station to be evaluated in a typical period based on the first correction coefficient, the second correction coefficient and the generating time length data of the original power station.

According to the technical scheme of the embodiment, the difference of different photovoltaic power stations in the same area in operating conditions and environmental conditions is considered, and the power generation duration data of the original power stations around the power station to be evaluated in the set period is corrected by using the first correction coefficient, so that the power generation duration data of the power station to be evaluated in the prediction period is obtained. And in consideration of the difference of different power generation periods of the same photovoltaic power station in operating conditions and environmental conditions, correcting the power generation duration data of the power station to be evaluated in the prediction period by using the second correction coefficient to obtain the power generation duration data of the power station to be evaluated in a typical period, namely the power generation duration data of the power station to be evaluated, which needs to be calculated finally. According to the technical scheme, the actual power generation time length data of the power stations established around the power station to be evaluated is introduced to calculate the typical power generation time length data of the power station to be evaluated, and the problem that the power generation time length evaluation of the photovoltaic power station is inaccurate due to the fact that the adopted typical annual meteorological data and the calculated system efficiency data are unreasonable in the conventional power generation time length calculation method of the photovoltaic power station is solved. According to the technical scheme, the accuracy of calculating the power generation time of the photovoltaic power station is effectively improved, so that investment loss is reduced for investment and financing mechanisms and photovoltaic power station construction enterprises.

Drawings

Fig. 1 is a schematic flow chart of a method for calculating a power generation time of a photovoltaic power station according to an embodiment of the present invention;

FIG. 2 is a schematic flow chart of another method for calculating a power generation time of a photovoltaic power plant according to an embodiment of the present invention;

FIG. 3 is a schematic flow chart of another method for calculating a power generation time of a photovoltaic power plant according to an embodiment of the present invention;

FIG. 4 is a schematic structural diagram of a photovoltaic power station power generation duration calculation system according to an embodiment of the present invention;

fig. 5 is a schematic structural diagram of a terminal according to an embodiment of the present invention.

Detailed Description

The present invention will be described in further detail with reference to the accompanying drawings and examples. It is to be understood that the specific embodiments described herein are merely illustrative of the invention and are not limiting of the invention. It should be further noted that, for the convenience of description, only some of the structures related to the present invention are shown in the drawings, not all of the structures.

Fig. 1 is a schematic flow chart of a method for calculating power generation time of a photovoltaic power station according to an embodiment of the present invention, where the method is applicable to calculating power generation time of a photovoltaic power station to be evaluated, and the method can be executed by a system for calculating power generation time of a photovoltaic power station, where the system can be implemented in a software and/or hardware manner, and the system can be configured in an electronic device, such as a server or a terminal device, where a typical terminal device includes a mobile terminal, specifically includes a mobile phone, a computer, or a tablet computer. As shown in fig. 1, the method for calculating the power generation time of the photovoltaic power station may specifically include:

and S110, acquiring power generation time data of original power stations around the power station to be evaluated.

Specifically, the power station to be evaluated can be a proposed photovoltaic power station, and the proposed photovoltaic power station refers to a photovoltaic power station planned to be built in a certain area. And when the power station to be evaluated is the planned photovoltaic power station, the original power station is the original photovoltaic power station around the site of the power station to be evaluated. The original power station and the power station to be evaluated are close in geographic position, so that the meteorological conditions are similar, the power generation time length data of the original power station are obtained, and a series of correction calculation is carried out on the power generation time length data of the original power station in the subsequent steps to obtain the power generation time length of the power station to be evaluated. The power station to be evaluated can also be an original power station, and when the power station to be evaluated is the original power station, the power generation duration data of another original power station around the site of the power station to be evaluated is obtained to assist in calculating the power generation duration of the power station to be evaluated. The obtained power generation duration data of the original power station refers to power generation duration data of the original power station in a set power generation period, the set power generation period can be a year period, a quarter period or a month period, and the like, and the power generation duration data can be power generation equivalent hour data of a photovoltaic power station and the like.

And S120, determining a first correction coefficient according to the operation data and the environment data of the power station to be evaluated and the original power station.

The first correction coefficient is used for correcting the power generation duration data of the original power station to obtain the power generation duration data of the power station to be evaluated in the prediction period. The power generation time length data of the power station to be evaluated in the prediction period refers to the real power generation time length data of the power station to be evaluated in a certain power generation period, and the power generation time length data is prediction data. The prediction period may be a period corresponding to a set power generation period to which the power generation duration data of the original power generation station belongs, for example, when the set power generation period of the original power generation station is in units of years, the prediction period of the power station to be evaluated is also in units of years, and when the set power generation period of the original power generation station is 2020 years, the prediction period of the power station to be evaluated may be 2022 years.

The power generation duration of a photovoltaic power station depends on the environmental conditions in which the power station is located and the operating conditions of the photovoltaic modules in the photovoltaic power station. Although the power station to be evaluated and the original power station are in the same region, the power station to be evaluated and the original power station are influenced by geographic factors and meteorological factors, and the environmental conditions of the two power stations are not completely consistent, so that the included angles between the photovoltaic modules of the two power stations and sunlight are different, and therefore, the environmental data of the two power stations are different. Meanwhile, the operating conditions of the two power stations are different due to different environmental conditions, so that the operating data of the two power stations are different. Therefore, the difference between the power generation time length data of the power station to be evaluated in the prediction period and the power generation time length data of the power station originally built in the set period actually lies in the difference between the operation data and the environment data of the two power stations, and the first correction coefficient can be obtained according to the difference between the operation data and the environment data of the two power stations. Then, according to the power generation duration data of the original power station in the set period obtained in step S110 and the first correction coefficient obtained in step S120, the power generation duration data of the power station to be evaluated in the prediction period can be calculated.

And S130, determining a second correction coefficient according to the operation data and the environment data of the prediction period and the typical period of the power station to be evaluated.

The second correction coefficient is used for correcting the power generation time length data of the power station to be evaluated in the prediction period so as to obtain the power generation time length data of the power station to be evaluated in the typical period. The typical period refers to a power generation period which can represent typical meteorological features of the area where the power station to be evaluated is located. The meteorological features influence the environmental conditions of the photovoltaic power station, the environmental conditions influence the operating conditions of the photovoltaic power station at the same time, and when the meteorological features of the power station to be evaluated are representative in a typical period, the environmental data and the operating data of the power station to be evaluated in the typical period are also representative, and the environmental data and the operating data directly influence the power generation duration data of the power station, so that the power generation duration data of the power station to be evaluated in the typical period is the power generation duration data of the power station to be evaluated, which needs to be calculated finally in the embodiment.

For the same power station to be evaluated, the difference between the predicted power generation period and the typical power generation period is caused by different meteorological conditions, namely, the difference between the environmental conditions of the predicted power generation period and the typical power generation period exists, and the difference between the environmental conditions causes the difference between the operating conditions of the power stations to be evaluated in the two periods. Therefore, the difference between the power generation time length data of the power station to be evaluated in the prediction period and the power generation time length data of the power station to be evaluated in the typical period is the difference between the operation data and the environment data of the two periods, and the second correction coefficient can be obtained according to the difference between the operation data and the environment data of the two power stations. Then, according to the power generation duration data of the power station to be evaluated in the prediction period obtained in step S120 and the second correction coefficient obtained in step S130, the power generation duration data of the power station to be evaluated in the typical period, that is, the power generation duration data of the power station to be evaluated, which is finally calculated in the embodiment, can be calculated.

And S140, calculating the power generation time of the power station to be evaluated in a typical period based on the first correction coefficient, the second correction coefficient and the power generation time data of the original power station.

In summary, in the technical solution of this embodiment, in consideration of differences between operating conditions and environmental conditions of different photovoltaic power stations in the same area, the first correction coefficient is used to correct the power generation duration data of the power station to be evaluated in the set period of the original power station around the power station to be evaluated, so as to obtain the power generation duration data of the power station to be evaluated in the prediction period. And in consideration of the difference of different power generation periods of the same photovoltaic power station in operating conditions and environmental conditions, correcting the power generation duration data of the power station to be evaluated in the prediction period by using the second correction coefficient to obtain the power generation duration data of the power station to be evaluated in a typical period, namely the power generation duration data of the power station to be evaluated, which needs to be calculated finally. According to the technical scheme, the actual power generation time length data of the power stations established around the power station to be evaluated is introduced to calculate the typical power generation time length data of the power station to be evaluated, and the problem that the power generation time length evaluation of the photovoltaic power station is inaccurate due to the fact that the adopted typical annual meteorological data and the calculated system efficiency data are unreasonable in the conventional power generation time length calculation method of the photovoltaic power station is solved. According to the technical scheme, the accuracy of calculating the power generation time of the photovoltaic power station is effectively improved, so that investment loss is reduced for investment and financing mechanisms and photovoltaic power station construction enterprises.

Fig. 2 is a schematic flow chart of another method for calculating the power generation time of the photovoltaic power station according to the embodiment of the present invention. The present embodiment further optimizes the method for determining the first correction coefficient in the above embodiments on the basis of the above embodiments. In this embodiment, the operation data includes system efficiency data, and the environment data includes irradiation duration data. Correspondingly, as shown in fig. 2, the method of the present embodiment specifically includes:

s210, obtaining power generation time length data of original power stations around the power station to be evaluated.

S220, determining the relation between the irradiation duration and the power generation duration of the power station to be evaluated in the prediction period and the system efficiency. Illustratively, the power generation time period T of the photovoltaic power station is G · PR, where G is the irradiation time period of the photovoltaic module receiving surface of the photovoltaic power station irradiated by the light source, and PR (Performance Ratio, PR) is the system efficiency of the photovoltaic power station. According to the T-G-PR, the relation between the irradiation duration and the power generation duration of the power station to be evaluated in the prediction period and the system efficiency is expressed as follows:

T_{to-be-estimated-true-T1}＝G_{to-be-estimated-true-T1}·PR_{to-be-estimated-true-T1}(1)

Wherein, T_{to-be-estimated-true-T1}For the generation duration, G, of the power station to be evaluated within the prediction period T1_{to-be-estimated-true-T1}For the irradiation duration, G, of the power station to be evaluated within the prediction period_{to-be-estimated-true-T1}Specifically, the predicted value, PR, may be obtained from meteorological data in a prediction period_{to-be-estimated-true-T1}For the system efficiency, PR, of the station to be evaluated in the prediction period_{to-be-estimated-true-T1}And may be a predicted value as well.

And S230, determining the relationship between the irradiation duration and the power generation duration of the original power station in a set period and the system efficiency.

Illustratively, according to the relation between the irradiation duration and the power generation duration of the original power station in a set period and the system efficiency, the relation is expressed as follows:

T_{original building-true-T2}＝G_{Original building-true-T2}·PR_{Original building-true-T2}(2)

Wherein, T_{Original building-true-T2}The power generation time length G of the original power station in a set period T2_{Original building-true-T2}The irradiation duration, PR, of the original power station in a set period_{Original building-true-T2}The system efficiency of the original power station in the set period is obtained.

S240, establishing a proportional relation between the power generation time of the power station to be evaluated and the power generation time of the power station originally built.

The proportion coefficient of the power generation time of the power station to be evaluated and the power station built originally comprises the ratio of the irradiation time and the ratio of the system efficiency, and the proportion coefficient of the power generation time of the power station to be evaluated and the power station built originally is a first correction coefficient.

Although the power station to be evaluated and the original power station are in the same region, because the included angles between the light sources of the two power stations and the photovoltaic modules are different, the irradiation time of the photovoltaic modules of the two power stations is different, and meanwhile, the system efficiency of the two power stations is also different, so the power generation time of the two power stations is not equal. According to the formula (1) and the formula (2), the proportional relation of the power generation time of the power station to be evaluated and the power station of the original building is expressed as follows:

wherein the content of the first and second substances,

the proportional coefficient is the power generation time length of the power station to be evaluated and the original power station, and comprises the ratio of the irradiation time lengths of the power station to be evaluated and the original power station

And the ratio of the system efficiency of the power station to be evaluated to that of the original power station

In this embodiment, the ratio of the simulated values of the system efficiencies of the power station to be evaluated and the original power station may be adopted to replace the ratio of the system efficiencies in the proportionality coefficient, and the ratio of the estimated values of the irradiation durations of the power station to be evaluated and the original power station may be adopted to replace the ratio of the irradiation durations in the proportionality coefficient, so as to optimize the proportionality coefficient of the power station to be evaluated and the original power station, so that the first correction coefficient includes the ratio of the estimated values of the irradiation durations of the power station to be evaluated and the original power station and the ratio of the simulated values of the system efficiencies.

Specifically, the ratio of the simulated values of the system efficiency of the power station to be evaluated and the original power station is adopted to replace the ratio of the system efficiency in the proportionality coefficient, because the system efficiency PR of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}The system efficiency PR of the power station and the original power station in a set period_{Original building-true-T2}And the calculation can not be carried out through actual measurement, so that the calculation can be carried out by using simulation software such as PVsyst and the like and by using model simulation of the efficiency of the photovoltaic power station system.

Exemplary simulated values of system efficiency include deterministic losses and non-deterministic losses for photovoltaic power plants. Wherein determining the loss comprises at least: shadow irradiation loss, relative transmittance loss, weak light loss, temperature loss, shadow electrical loss, light-induced attenuation loss, component mismatch loss, direct current cable loss, inverter system efficiency loss, alternating current cable loss and transformer loss; the uncertain losses comprise at least: dust losses and system unavailability losses.

In the loss, determining the shadow irradiation loss as the system irradiation loss caused by the fact that the photovoltaic module is shielded by the shadow; the relative transmittance loss is the system loss caused when the solar light source is not vertically incident on the surface of the photovoltaic module; the weak light loss is irradiation loss caused by weak light of a solar light source; the temperature loss is the system loss caused by lower ambient temperature; the shadow electrical loss is the system electrical loss caused when the photovoltaic module is shielded by the shadow; the photoinduced attenuation loss is loss caused by that the photoelectric material in the photovoltaic module is irradiated by strong light for a long time or current passes through the photoelectric material, and defects are generated in the photoelectric material to reduce the service performance of the photoelectric material and cause a system; the module mismatch loss is system loss caused by mismatch of different modules in the photovoltaic system; the direct current cable loss and the alternating current cable loss are respectively losses generated by the photovoltaic system on a direct current cable transmission line and an alternating current cable transmission line; the efficiency loss of the inverter system is the inverter efficiency of the inverter system in the photovoltaic system, namely the electric energy conversion efficiency, and the loss of the photovoltaic system is caused; the transformer loss is loss brought to the photovoltaic system by loss of a transformer in the photovoltaic system. In the above determination of the loss, since the condition causing the loss is generally determined, the loss of the same photovoltaic power station under the same meteorological condition is also a constant value. In the uncertain loss, the dust loss is the system irradiation loss caused by the fact that the photovoltaic modules are covered by dust, and the dust loss is the uncertain loss due to the fact that the photovoltaic modules are different in dust covering degree; the system unavailability loss is the probability of the photovoltaic system having a fault, so that different losses can be generated to the photovoltaic system according to the different probabilities of the photovoltaic system having a fault.

The detailed theoretical basis of the ratio of the system efficiency in the substitution proportionality coefficient by adopting the ratio of the simulated values of the system efficiency of the power station to be evaluated and the power station originally built is as follows:

illustratively, a computational model of the system efficiency of the photovoltaic power station is established by using Pvsyst simulation software, and the computational model of the simulation value of the system efficiency of the power station to be evaluated comprises (1-J) when the influence of the determined loss on the system efficiency is considered₁)·(1-J₂)·(1-J₃)……(1-J_n). Wherein, J₁～J_nThere may be a plurality of loss values in the above-described determined loss. Suppose (1-J)₁)·(1-J₂)·(1-J₃)……(1-J_n) Set to 0.85 (virtual values, which may be other values), considering that Pvsyst software is calculated based on a theoretical model of the photovoltaic system and the model is relatively accurate (1-J)₁)·(1-J₂)·(1-J₃)……(1-J_n) If the error between the simulated value and the actual value is ± 2%, the actual value of the system efficiency of the power station to be evaluated may be set to include (0.85+0.04 × rand-0.02) by using the rand function that generates random numbers in the simulation system. In the same way, the system for setting the original power stationThe calculation model of the simulated value of the efficiency comprises (1-K)₁)·(1-K₂)·(1-K₃)……(1-K_n) Wherein, K is₁～K_nThe determined loss J of the original power station corresponding to the power station to be evaluated₁～J_nN loss values. Suppose (1-K)₁)·(1-K₂)·(1-K₃)……(1-K_n) Equal to 0.83 (virtual value, may be other value), and is set to (1-K) in the same manner₁)·(1-K₂)·(1-K₃)……(1-K_n) The error between the simulated value and the actual value is +/-2%, and the actual value of the system efficiency of the original power station can be obtained to include (0.83+ 0.04) rand-0.02). Among them, the more the rand times are, the more representative the value of the system efficiency is.

When considering the influence of uncertain losses on the efficiency of the system, e.g. considering dust loss J_n+1The calculation model of the simulated value of the system efficiency of the power station to be evaluated also comprises (1-J)_n+1) 0.97 (virtual values, among others), the actual value of the system efficiency of the plant to be evaluated also includes (0.97+0.02 × rand-0.01). Considering the unavailability loss J_n+2Then, the calculation model of the simulated value of the system efficiency of the power station to be evaluated further comprises (1-J)_n+2) 0.99 (virtual values, among others), the actual value of the system efficiency of the plant to be evaluated also includes (0.99+0.02 rand-0.01).

The system efficiency PR of the plant to be evaluated in the prediction period_{to-be-estimated-true-T1}Can be calculated as:

PR_{to-be-estimated-true-T1}＝(1-J_1-true)……(1-J_n-true)·(1-J_{n + 1-true})·(1-J_{n + 2-true})

Wherein, J_1-true～J_n-trueDetermining loss J for a power station to be evaluated₁～J_nTrue value of, J_{n + 1-true}For the true value of the dust loss of the power station to be evaluated, J_{n + 2-true}The real value of the unavailability loss of the power station to be evaluated.

Simulated value PR of system efficiency of power station to be evaluated in prediction period_{To be estimated-X-T1}Can be calculated as:

PR_{to be estimated-X-T1}＝(1-J_1-simulation)……(1-J_n-simulation)·(1-J_{n + 1-simulation})·(1-J_{n + 2-simulation})

Wherein, J_1-simulation～J_n-simulationDetermining loss J for a power station to be evaluated₁～J_nSimulation value of (1, J)_{n + 1-simulation}As a simulated value of the dust loss of the power station to be evaluated, J_{n + 2-simulation}Is a simulated value of the unavailability loss of the power station to be evaluated.

System efficiency PR of original power station in set period_{Original building-true-T2}Can be calculated as:

PR_{original building-true-T2}＝(1-K_1-true)……(1-K_n-true)·(1-K_{n + 1-true})·(1-K_{n + 2-true})

Wherein, K_1-true～K_n-trueDetermining loss K for original power station₁～K_nTrue value of, K_{n + 1-true}Is the true value of dust loss, K, of the originally constructed power station_{n + 2-true}The real value of the unavailable rate loss of the original power station is obtained.

Simulated value PR of system efficiency of original power station in set period_{Original building-X-T2}Can be calculated as:

PR_{original building-X-T2}＝(1-K_1-simulation)……(1-K_n-simulation)·(1-K_{n + 1-simulation})·(1-K_{n + 2-simulation})

Wherein, K_1-simulation～K_n-simulationDetermining loss K for original power station₁～K_nTrue value of, K_{n + 1-simulation}Is the true value of dust loss, K, of the originally constructed power station_{n + 2-simulation}The real value of the unavailable rate loss of the original power station is obtained.

PR can be obtained_{to-be-estimated-true-T1}And PR_{Original building-true-T2}The relationship between:

in practical situations, because the power station to be evaluated and the original power station are in the same area, and the dust loss Jn +1 and the unavailability loss Jn +2 of the same area are basically the same, the uncertain loss term in the above formula can be eliminated, and the following results are obtained:

and also has PR_{to-be-estimated-true-T1}And PR_{Original building-true-T2}The relationship between:

random number generation and calculation are performed by simulation software for 1000 ten thousand times

And

the difference value of the two power stations is calculated for 1000 ten thousand times, the average value of the difference value of the two power stations is 0.0002, and the difference value of the two power stations is 0.02 percent, namely, the ratio of the real system efficiency of the power station to be evaluated and the original power station in the same area is approximately equal to the ratio of the simulated values of the system efficiency of the two power stations, namely:

wherein, PR_{To be estimated-X-T1}Can be obtained by simulation calculation based on meteorological data of the station site of the power station to be evaluated provided by the X meteorological source by using simulation software, namely PR_{Original building-X-T2}Simulation software can be used for carrying out simulation calculation based on meteorological data of the site of the original power station provided by the X meteorological source. The X meteorological source is a meteorological database provided by a Solargis platform, the meteorological database comprises a series of data consisting of solar radiation, photovoltaic data, weather, time and geographic elements, and specifically comprises historical, recent and predicted meteorological data of any place around the world, and the X meteorological source is the current known meteorological source with the highest precisionA high weather source.

The ratio of the estimated value of the irradiation duration of the power station to be evaluated to the original power station is adopted to replace the ratio of the irradiation duration in the proportional coefficient, the reason is that the irradiation duration of the power station to be evaluated in the proportional coefficient in the prediction period is a real value which cannot be obtained through actual measurement, the estimated value of the irradiation duration of the photovoltaic power station can be obtained through calculation according to meteorological data in an X meteorological source, although the estimated value of the irradiation duration of the photovoltaic power station has deviation relative to an actual value, the relative value of the irradiation duration of the power station to be evaluated to the original power station is more accurate compared with the absolute value of the irradiation duration of the power station to be evaluated to the original power station, therefore, the change ratio of the irradiation duration of the photovoltaic power station is approximately equal to the change ratio of the estimated value of the irradiation duration of the photovoltaic power station provided by the X meteorological source, and then the change ratios are obtained:

that is, the estimated value G of the irradiation duration of the power station to be evaluated in the prediction period T1 may be used_{To be estimated-X-T1}Estimated value G of irradiation duration of original power station in set period T2_{Original building-X-T2}In the alternative proportionality coefficient, the irradiation duration G of the power station to be evaluated in the prediction period T1_{to-be-estimated-true-T1}The irradiation duration G of the original power station in a set period T2_{Original building-true-T2}The ratio of (a) to (b). Wherein G is_{To be estimated-X-T1}Providing irradiation duration G of power station to be evaluated in prediction period T1 for X meteorological source_{Original building-X-T2}The irradiation duration of the original power station provided for the X meteorological source in the set period T2.

In summary, after the simulation ratio of the system efficiency of the power station to be evaluated and the original power station is adopted to replace the ratio of the system efficiency in the proportionality coefficient, and the ratio of the estimated value of the irradiation duration of the power station to be evaluated and the original power station is adopted to replace the ratio of the irradiation duration in the proportionality coefficient, the expression (4) and the expression (5) are substituted into the expression (3) of the proportional relation of the power generation duration of the power station to be evaluated and the original power station, and the following results can be obtained:

wherein the first correction coefficient is expressed as:

in step S210, the power generation time T of the original power station in the set period has been obtained_{Original building-true-T2}Combining the first correction coefficient shown in the formula (7) to obtain the power generation time length T of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}，T_{to-be-estimated-true-T1}The method can be used for correcting the power generation time of the power station to be evaluated in the subsequent steps through the second correction coefficient, so that the power generation time of the power station to be evaluated in the typical period which needs to be calculated finally is obtained.

And S250, determining a second correction coefficient according to the operation data and the environment data of the prediction period and the typical period of the power station to be evaluated.

The second correction coefficient is used for correcting the power generation time length data of the power station to be evaluated in the prediction period so as to obtain the power generation time length data of the power station to be evaluated in the typical period.

And S260, calculating the power generation time of the power station to be evaluated in a typical period based on the first correction coefficient, the second correction coefficient and the power generation time data of the original power station.

According to the technical scheme of the embodiment, the proportional relation between the power generation time of the power station to be evaluated in the prediction period and the power generation time of the original power station in the set period is established, and the proportional coefficient in the proportional relation between the power generation time of the power station to be evaluated and the power generation time of the original power station is determined according to the difference between the irradiation time of the power station to be evaluated and the original power station and the system efficiency. And replacing the ratio of the system efficiency in the proportionality coefficient by adopting the ratio of the simulated values of the system efficiency of the power station to be evaluated and the system efficiency of the original power station to be evaluated, and replacing the ratio of the irradiation time in the proportionality coefficient by adopting the ratio of the estimated value of the irradiation time of the power station to be evaluated and the original power station to obtain a first correction coefficient. Through the first correction coefficient, the power generation time of the original power station in the set period can be corrected, and the power generation time of the power station to be evaluated in the prediction period is obtained. In the subsequent implementation steps, the power generation duration of the power station to be evaluated in the prediction period can be corrected by using the second correction coefficient, so that the power generation duration of the power station to be evaluated in the typical period, which needs to be calculated finally, can be obtained. The technical scheme of this embodiment helps promoting the degree of accuracy that length was calculated during photovoltaic power plant electricity generation to reduce investment loss for investment and financing mechanism and photovoltaic power plant construction enterprise.

Fig. 3 is a schematic flow chart of another method for calculating the power generation time of the photovoltaic power station according to the embodiment of the present invention. In this embodiment, on the basis of the above embodiment, the method for determining the second correction coefficient in the above embodiment is further optimized. In this embodiment, the operation data includes system efficiency data, and the environment data includes irradiation duration data. Correspondingly, as shown in fig. 3, the method of the present embodiment specifically includes:

s310, acquiring power generation time data of original power stations around the power station to be evaluated.

S320, determining a first correction coefficient according to the operation data and the environment data of the power station to be evaluated and the power station originally built.

The first correction coefficient is used for correcting the power generation duration data of the original power station to obtain the power generation duration data of the power station to be evaluated in the prediction period.

S330, determining the relation between the irradiation duration and the power generation duration of the power station to be evaluated in the prediction period and the system efficiency.

Illustratively, the power generation time period T of the photovoltaic power station is G · PR, where G is the irradiation time period of the photovoltaic module receiving surface of the photovoltaic power station irradiated by the light source, and PR (Performance Ratio, PR) is the system efficiency of the photovoltaic power station. According to the T-G-PR, the relation between the irradiation duration and the power generation duration of the power station to be evaluated in the prediction period and the system efficiency is expressed as follows:

Wherein, T_{to-be-estimated-true-T1}Forecasting for the power station to be evaluatedDuration of power generation in period T1, G_{to-be-estimated-true-T1}For the irradiation duration, PR, of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}And the system efficiency of the power station to be evaluated in the prediction period is obtained.

S340, determining the relation between the irradiation duration and the power generation duration of the power station to be evaluated in the typical period and the system efficiency.

Illustratively, according to T ═ G · PR, the relationship between the irradiation duration, the power generation duration, and the system efficiency of the power station to be evaluated in a typical period is expressed as:

T_{to estimate-true-T}＝G_{To estimate-true-T}·PR_{To estimate-true-T}(8)

Wherein, T_{To estimate-true-T}For the generation duration of the station to be evaluated in a typical period T, G_{To estimate-true-T}For the duration of irradiation, PR, of the station to be evaluated in a typical cycle_{To estimate-true-T}The system efficiency of the power station to be evaluated in a typical cycle is obtained.

And S350, establishing a proportional relation between the prediction period of the power station to be evaluated and the power generation duration of the typical period.

The proportionality coefficient of the prediction period of the power station to be evaluated and the power generation time of the typical period comprises the ratio of the irradiation time and the ratio of the system efficiency, and the proportionality coefficient of the prediction period of the power station to be evaluated and the power generation time of the typical period is a second correction coefficient.

For the same power station to be evaluated, the difference between the predicted period T1 and the typical period T is caused by different meteorological conditions, that is, the irradiation durations of the photovoltaic modules in the predicted period T1 and the typical period T are different, and the difference between the meteorological conditions causes the system efficiency of the power station to be evaluated in two periods to be different. The proportional relation between the predicted period T1 of the power station to be evaluated and the power generation time of the typical period T is expressed as follows:

wherein the content of the first and second substances,

the proportionality coefficient of the power generation time of the prediction period and the typical period of the power station to be evaluated comprises the ratio of the prediction period and the irradiation time of the typical period of the power station to be evaluated

And the ratio of the system efficiency of the predicted period to the typical period of the power station to be evaluated

In this embodiment, the ratio of the simulated value of the system efficiency of the prediction period of the power station to be evaluated to the typical period may be used to replace the ratio of the system efficiency in the proportional coefficient, and the ratio of the prediction period of the power station to be evaluated to the estimated value of the irradiation duration of the typical period may be used to replace the ratio of the irradiation duration in the proportional coefficient, so as to optimize the proportional coefficient, so that the second correction coefficient includes the ratio of the estimated value of the irradiation duration of the prediction period of the power station to be evaluated to the typical period to the simulated value of the system efficiency.

Specifically, according to the formula (4) and the inference process thereof in the above embodiment, it can be known that the ratio of the real system efficiencies of the two power stations in the same area is approximately equal to the ratio of the simulated values of the system efficiencies of the two power stations, and thus the ratio of the real system efficiency of the same power station in different power generation cycles is also approximately equal to the ratio of the simulated values of the system efficiencies of the different power generation cycles, and therefore, the ratio of the system efficiency in the ratio coefficient of the substitute expression (9), that is, the ratio of the predicted cycle of the power station to be evaluated to the simulated value of the system efficiency of the typical cycle, can be adopted:

wherein, PR_{To be estimated-X-T1}For a simulated value, PR, of the system efficiency of the plant to be evaluated during the prediction period T1_{To be estimated-X-T1}Simulation software can be utilized to simulate the power station site to be evaluated based on the meteorological data of the power station site to be evaluated in the prediction period T1 provided by the X meteorological sourceAnd (4) calculating. PR_{To estimate-X-T}For a simulated value, PR, of the system efficiency of the plant to be evaluated in a typical period T_{To estimate-X-T}Simulation software can be used for carrying out simulation calculation on the basis of meteorological data of the station site of the power station to be evaluated in a typical period T provided by the X meteorological source.

Similarly, according to the formula (5) and the inference process thereof in the above embodiment, it can be known that the change ratio of the irradiation time periods of the two power stations is approximately equal to the change ratio of the estimated values of the irradiation time periods of the two power stations provided by the X meteorological source. Therefore, for the same power station, the change ratio of the irradiation duration of different power generation cycles is also approximately equal to the change ratio of the estimated value of the irradiation duration of different power generation cycles provided by the X meteorological source, that is to say:

wherein G is_{To be estimated-X-T1}Providing irradiation duration G of power station to be evaluated in prediction period T1 for X meteorological source_{To estimate-X-T}And the irradiation duration of the power station to be evaluated in a typical period T is provided for the X meteorological source.

When the photovoltaic module of the photovoltaic power station is a single-side module, the irradiation time of the photovoltaic power station can be directly determined according to the irradiation time provided by the X meteorological source, and when the photovoltaic module of the photovoltaic power station is a double-side module or a rotatable module of a real-time tracking light source, the irradiation time of the photovoltaic power station is long and the total available irradiation time which can be received by the module is long.

In summary, after replacing the ratio of the irradiation time length in the proportionality coefficient by using the ratio of the simulated value of the system efficiency of the prediction period of the power station to be evaluated and the simulated value of the system efficiency of the typical period, and by using the ratio of the prediction period of the power station to be evaluated and the estimated value of the irradiation time length of the typical period, the expressions (10) and (11) are substituted into the expression (9) of the proportional relation between the power station to be evaluated and the power generation time length of the original power station, so that the following can be obtained:

wherein the second correction coefficient is:

in step S310, the power generation time T of the original power station in the set period is obtained_{Original building-true-T2}Combining the first correction coefficient determined in step S320, the power generation time T of the power station to be evaluated in the prediction period can be calculated_{to-be-estimated-true-T1}. By using the second correction coefficient determined in the formula (13) in this embodiment, T can be corrected_{to-be-estimated-true-T1}Correcting to obtain the final power generation time T of the power station to be evaluated in the typical period needing to be calculated_{To estimate-true-T}。

And S360, calculating the power generation time of the power station to be evaluated in a typical period based on the first correction coefficient, the second correction coefficient and the power generation time data of the original power station.

For example, substituting equation (12) in this embodiment into equation (12) in this embodiment, equation (6) in the above embodiment can result in:

that is, the calculation formula of the power generation time of the power station to be evaluated in a typical period can be represented as follows:

wherein, T_{Original building-true-T2}Is a known amount, G_{To estimate-X-T}And G_{Original building-X-T2}All can be obtained by using X meteorological source, PR_{To estimate-X-T}And PR_{Original building-X-T2}Can be obtained by simulating with an X meteorological source.

According to the technical scheme of the embodiment, the proportional relation between the power generation time of the power station to be evaluated in the prediction period and the power generation time of the power station to be evaluated in the typical period is established, and the proportional coefficient in the proportional relation between the power generation time of the power station to be evaluated and the power generation time of the power station to be evaluated in the typical period is determined according to the difference between the irradiation time of the prediction period and the typical period and the system efficiency. And replacing the ratio of the system efficiency in the proportionality coefficient by adopting the ratio of the simulated value of the system efficiency of the prediction period and the typical period of the power station to be evaluated, and replacing the ratio of the irradiation time in the proportionality coefficient by adopting the ratio of the prediction period and the estimated value of the irradiation time of the typical period of the power station to be evaluated to obtain a second correction coefficient. And correcting the power generation time of the power station to be evaluated in the prediction period through the second correction coefficient to obtain the final power generation time of the power station to be evaluated in the typical period, which needs to be calculated. The technical scheme of this embodiment helps promoting the degree of accuracy that length was calculated during photovoltaic power plant electricity generation to reduce investment loss for investment and financing mechanism and photovoltaic power plant construction enterprise.

In another embodiment of the present invention, when the power station to be evaluated is an original power station (2), and the peripheral power station of the power station to be evaluated is another original power station (1), the typical power generation time data of the original power station 2 in (20XX + n) years can be calculated according to the actual power generation time data of the original power station 1 in 20XX years, that is, according to equation (14) in the above embodiment, the following data can be obtained:

wherein, T_{Original 2-true- (20xx + n)}For the power generation duration of the original power station 2 in (20XX + n) years, G_{Original 2-X- (20xx + n)}For an estimate of the exposure time of the primary power plant 2 in the (20XX + n) year, PR_{Original 2-X- (20xx + n)}Is a simulated value of the system efficiency of the original power station 2 in (20XX + n) years, T_{Original 1-true-20 xx}For the actual power generation duration of the original power station 1 in 20XX years, G_{Original construction 1-X-20xx is}Estimation of the irradiation duration, PR, of the primary power station 1 in 20XX years_{Original 1-X-20xx}Is a simulated value of the system efficiency of the original power station 1 in 20XX years.

According to the technical scheme, when the power station to be evaluated and the peripheral power stations of the power station to be evaluated are all the original power stations, the time data of the future power generation of another original power station can be calculated in an auxiliary mode according to the historical power generation time data of the original power station, so that the theoretical basis is provided for the calculation of the power generation time of the other original power station, the accuracy of the calculation of the power generation time of the other original power station is improved, and the investment loss of investment and financing mechanisms and photovoltaic power station construction enterprises is reduced.

Table 1 is a table of power generation time data and meteorological data of a photovoltaic power station in a certain area, and referring to table 1, the present embodiment may specifically explain a power generation time calculation method of a photovoltaic power station by combining with an example based on the above embodiments. Specifically, table 1 shows data of the X meteorological source, the proposed power station, and the original power stations around the proposed power station in 2017-2019, where G_{To build-X-20 XX}Estimated value G of irradiation equivalent hour of 20XX year of proposed power station provided for X meteorological source_{Original construction-X-typical year}Estimated value T of typical annual radiation equivalent hour of original power station provided for X meteorological source_{Original construction-true-20 XX}Is the true value, PR, of the power generation equivalent hour of the original power station in 20XX years_{Original building-X-20 XX}Is a simulated value, PR, of the system efficiency of the original power station in 20XX years_{pseudo-X-typical year}Is a simulated value of the system efficiency of a proposed power station in a typical year.

TABLE 1 Generation time data and Meteorological data Table for photovoltaic power station in certain area

According to the formula (14) in the above embodiment, it is possible to obtain:

g in Table 1_{Original construction-X-typical year}A value of (a), and G_{To build-X-20 XX}、T_{Original construction-true-20 XX}、PR_{Original building-X-20 XX}And PR_{pseudo-X-typical year}In the mean value substitution formula (15) in 2017 and 2019, the following can be obtained:

T_{pseudo-true-typical year}＝(1420.38/1443.1)*(84.60％/80.13％)*1235.74h

＝1284.13h

Therefore, according to the actual power generation time length data of original power stations around the proposed power station in 2017-2019 and G_{Original construction-X-typical year}、G_{To build-X-20 XX}、PR_{Original building-X-20 XX}And PR_{pseudo-X-typical year}The typical annual generating time length data of the proposed power station can be calculated and obtained through the simulation data.

Fig. 4 is a schematic structural diagram of a system for calculating the power generation time of a photovoltaic power station according to an embodiment of the present invention, where the embodiment is applicable to a situation of calculating the power generation time of a photovoltaic power station to be evaluated. The photovoltaic power station power generation time length calculation system provided by the embodiment of the invention can execute the photovoltaic power station power generation time length calculation method provided by any embodiment of the invention, and has corresponding functional modules and beneficial effects of the execution method.

The system specifically comprises a first power generation duration data acquisition module 410, a first correction coefficient determination module 420, a second correction coefficient determination module 430 and a second power generation duration data calculation module 440, wherein:

the first power generation duration data acquisition module 410 is configured to acquire power generation duration data of an original power station around a power station to be evaluated;

the first correction coefficient determining module 420 is configured to determine a first correction coefficient according to the operating data and the environmental data of the power station to be evaluated and the original power station, where the first correction coefficient is used to correct the power generation duration data of the original power station, so as to obtain the power generation duration data of the power station to be evaluated in the prediction period;

the second correction coefficient determining module 430 is configured to determine a second correction coefficient according to the prediction period of the power station to be evaluated, the operation data of the typical period, and the environment data, where the second correction coefficient is used to correct the power generation duration data of the power station to be evaluated in the prediction period, so as to obtain the power generation duration data of the power station to be evaluated in the typical period;

the second generation duration data calculation module 440 is configured to calculate a generation duration of the power station to be evaluated in a typical period based on the first correction coefficient, the second correction coefficient, and the generation duration data of the original power station.

The photovoltaic power station power generation time length calculation system provided by the embodiment of the invention can execute the photovoltaic power station power generation time length calculation method provided by any embodiment of the invention, has corresponding functional modules and beneficial effects of the execution method, and is not repeated.

Fig. 5 is a schematic structural diagram of a terminal according to an embodiment of the present invention. FIG. 5 illustrates a block diagram of an exemplary device 512 suitable for use in implementing embodiments of the present invention. The device 512 shown in fig. 5 is only an example and should not bring any limitations to the functionality or scope of use of the embodiments of the present invention.

As shown in fig. 5, device 512 is in the form of a general purpose device. Components of device 512 may include, but are not limited to: one or more processors 516, a storage device 528, and a bus 518 that couples the various system components including the storage device 528 and the processors 516.

Bus 518 represents one or more of any of several types of bus structures, including a memory device bus or memory device controller, a peripheral bus, an accelerated graphics port, and a processor or local bus using any of a variety of bus architectures. By way of example, such architectures include, but are not limited to, Industry Standard Architecture (ISA) bus, Micro Channel Architecture (MAC) bus, enhanced ISA bus, Video Electronics Standards Association (VESA) local bus, and Peripheral Component Interconnect (PCI) bus.

Device 512 typically includes a variety of computer system readable media. Such media can be any available media that is accessible by device 512 and includes both volatile and nonvolatile media, removable and non-removable media.

Storage 528 may include computer system readable media in the form of volatile Memory, such as Random Access Memory (RAM) 530 and/or cache Memory 532. The device 512 may further include other removable/non-removable, volatile/nonvolatile computer system storage media. By way of example only, storage system 535 may be used to read from and write to non-removable, nonvolatile magnetic media (not shown in FIG. 5, commonly referred to as a "hard drive"). Although not shown in FIG. 5, a magnetic disk drive for reading from and writing to a removable, nonvolatile magnetic disk (e.g., a "floppy disk") and an optical disk drive for reading from or writing to a removable, nonvolatile optical disk such as a Compact disk Read-Only Memory (CD-ROM), Digital Video disk Read-Only Memory (DVD-ROM) or other optical media may be provided. In these cases, each drive may be connected to bus 518 through one or more data media interfaces. Storage 528 may include at least one program product having a set (e.g., at least one) of program modules that are configured to carry out the functions of embodiments of the invention.

A program/utility 550 having a set (at least one) of program modules 552 may be stored, for instance, in storage 528, such program modules 552 including, but not limited to, an operating system, one or more application programs, other program modules, and program data, each of which examples or some combination thereof may include an implementation of a network environment. The program modules 552 generally perform the functions and/or methodologies of the described embodiments of the invention.

The device 512 may also communicate with one or more external devices 515 (e.g., keyboard, pointing terminal, display 525, etc.), with one or more terminals that enable a user to interact with the device 512, and/or with any terminals (e.g., network card, modem, etc.) that enable the device 512 to communicate with one or more other computing terminals. Such communication may occur via input/output (I/O) interfaces 522. Also, the device 512 may communicate with one or more networks (e.g., a Local Area Network (LAN), a Wide Area Network (WAN), and/or a public Network such as the internet) via the Network adapter 520. As shown in FIG. 5, the network adapter 520 communicates with the other modules of the device 512 via the bus 518. It should be appreciated that although not shown, other hardware and/or software modules may be used in conjunction with the device 512, including but not limited to: microcode, end drives, Redundant processors, external disk drive Arrays, RAID (Redundant Arrays of Independent Disks) systems, tape drives, and data backup storage systems, among others.

The processor 516 executes various functional applications and data processing by running a program stored in the storage device 528, for example, implementing a method for calculating a power generation time of a photovoltaic power plant provided by an embodiment of the present invention, the method includes:

determining a first correction coefficient according to the operating data and the environmental data of the power station to be evaluated and the original power station, wherein the first correction coefficient is used for correcting the power generation duration data of the original power station to obtain the power generation duration data of the power station to be evaluated in the prediction period;

An embodiment of the present invention further provides a computer-readable storage medium, on which a computer program is stored, where the computer program, when executed by a processor, implements a method for calculating a power generation time of a photovoltaic power station, where the method includes:

Computer storage media for embodiments of the invention may employ any combination of one or more computer-readable media. The computer readable medium may be a computer readable signal medium or a computer readable storage medium. A computer readable storage medium may be, for example, but not limited to, an electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination of the foregoing. More specific examples (a non-exhaustive list) of the computer readable storage medium would include the following: an electrical connection having one or more wires, a portable computer diskette, a hard disk, a Random Access Memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disc read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing. In the context of this document, a computer readable storage medium may be any tangible medium that can contain, or store a program for use by or in connection with an instruction execution system, apparatus, or device.

A computer readable signal medium may include a propagated data signal with computer readable program code embodied therein, for example, in baseband or as part of a carrier wave. Such a propagated data signal may take many forms, including, but not limited to, electro-magnetic, optical, or any suitable combination thereof. A computer readable signal medium may also be any computer readable medium that is not a computer readable storage medium and that can communicate, propagate, or transport a program for use by or in connection with an instruction execution system, apparatus, or device.

Program code embodied on a computer readable medium may be transmitted using any appropriate medium, including but not limited to wireless, wireline, optical fiber cable, RF, etc., or any suitable combination of the foregoing.

Computer program code for carrying out operations for aspects of the present invention may be written in any combination of one or more programming languages, including an object oriented programming language such as Java, Smalltalk, C + + or the like and conventional procedural programming languages, such as the "C" programming language or similar programming languages. The program code may execute entirely on the user's computer, partly on the user's computer, as a stand-alone software package, partly on the user's computer and partly on a remote computer or entirely on the remote computer or terminal. In the case of a remote computer, the remote computer may be connected to the user's computer through any type of network, including a Local Area Network (LAN) or a Wide Area Network (WAN), or the connection may be made to an external computer (for example, through the Internet using an Internet service provider).

It is to be noted that the foregoing is only illustrative of the preferred embodiments of the present invention and the technical principles employed. It will be understood by those skilled in the art that the present invention is not limited to the particular embodiments described herein, but is capable of various obvious changes, rearrangements and substitutions as will now become apparent to those skilled in the art without departing from the scope of the invention. Therefore, although the present invention has been described in greater detail by the above embodiments, the present invention is not limited to the above embodiments, and may include other equivalent embodiments without departing from the spirit of the present invention, and the scope of the present invention is determined by the scope of the appended claims.

Claims

1. A method for calculating the power generation time of a photovoltaic power station is characterized by comprising the following steps:

2. The method of claim 1, wherein the operational data comprises system efficiency data and the environmental data comprises exposure duration data;

3. The method according to claim 2, characterized in that the ratio of the system efficiencies in the proportionality coefficients is replaced by the ratio of the simulated values of the system efficiencies of the power station to be evaluated and the original power station;

4. The method of claim 3,

the relationship among the irradiation duration, the power generation duration and the system efficiency of the power station to be evaluated in the prediction period is expressed as follows:

wherein the first correction coefficient is expressed as:

wherein, T_{to-be-estimated-true-T1}For the generating time length G of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the irradiation duration, PR, of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the system efficiency, G, of the power station to be evaluated in the prediction period_{To be estimated-X-T1}For the estimation of the irradiation duration of the power station to be evaluated in the prediction period, PR_{To be estimated-X-T1}Is a simulated value, T, of the system efficiency of the power station to be evaluated in a prediction period_{Original building-true-T2}For the power generation duration G of the original power station in a set period_{Original building-true-T2}The irradiation duration, PR, of the original power station in a set period_{Original building-true-T2}For the system efficiency, G, of the original power station in a set period_{Original building-X-T2}For estimating the irradiation duration of the power station in a set period, PR_{Original building-X-T2}And the simulation value is the simulation value of the system efficiency of the original power station in a set period.

5. The method of claim 3, wherein the simulated values of system efficiency comprise deterministic losses and non-deterministic losses of a photovoltaic power plant;

6. The method of claim 1, wherein the operational data comprises system efficiency data and the environmental data comprises exposure duration data;

7. The method according to claim 6, characterized in that the ratio of the system efficiency in the scaling factors is replaced by the ratio of the simulated values of the system efficiency of the prediction period to the typical period of the plant to be evaluated;

8. The method according to claim 7, characterized in that the relationship between the irradiation duration, the power generation duration and the system efficiency of the power station to be evaluated in the prediction period is expressed as:

T_{to estimate-true-T}＝G_{To estimate-true-T}·PR_{To estimate-true-T}；

wherein the second correction coefficient is:

wherein, T_{to-be-estimated-true-T1}For the generating time length G of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the irradiation duration, PR, of the power station to be evaluated in the prediction period_{to-be-estimated-true-T1}For the system efficiency, G, of the power station to be evaluated in the prediction period_{To be estimated-X-T1}For the estimation of the irradiation duration of the power station to be evaluated in the prediction period, PR_{To be estimated-X-T1}Is a simulated value, T, of the system efficiency of the power station to be evaluated in a prediction period_{To estimate-true-T}For the generation duration, G, of the power station to be evaluated in a typical period_{To estimate-true-T}For the irradiation duration, PR, of the power station to be evaluated in a typical cycle_{To estimate-true-T}For the system efficiency of the power station to be evaluated in a typical period, G_{To estimate-X-T}For the evaluation of the irradiation duration of the power station to be evaluated in a typical cycle, PR_{To estimate-X-T}Is the evaluation to be madeA simulated value of the system efficiency of the plant over a typical period.

9. The method according to claim 1, characterized in that the power generation duration of the plant to be evaluated in a typical period is calculated as:

wherein, T_{To estimate-true-T}For the generation duration, G, of the power station to be evaluated in a typical period_{To estimate-X-T}For the evaluation of the irradiation duration of the power station to be evaluated in a typical cycle, PR_{To estimate-X-T}Is a simulated value of the system efficiency of the power station to be evaluated in a typical period, T_{Original building-true-T2}For the power generation duration G of the original power station in a set period_{Original building-X-T2}For estimating the irradiation duration of the power station in a set period, PR_{Original building-X-T2}And the simulation value is the simulation value of the system efficiency of the original power station in a set period.

10. A photovoltaic power plant electricity generation time length calculation system is characterized by comprising: