A calculation method and related device for direct solar irradiance value of a candidate site

Abstract

The present application discloses a method for calculating the direct solar irradiance value of a to-be-selected plant site and related devices, which relates to the technical field of solar thermal power generation, and focuses on the influence rules of three meteorological conditions, namely cloud cover, frosting, and extreme strong wind, which affect heat collection, on the effective direct solar irradiance. Obtain a first corrected direct solar irradiance value obtained through the cloud cover meteorological condition; obtain a second corrected direct solar irradiance value obtained through the frosting meteorological condition; obtain a third corrected direct solar irradiance value obtained through the extreme strong wind meteorological condition; based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value, determine the corrected direct solar irradiance value at the second moment. The present application combines cloud cover, frosting, and extreme strong wind meteorological parameters to correct the direct solar irradiance, and obtains the actually available corrected direct solar irradiance value, providing a basis and reference for the site selection, investment decision-making, operation, etc. of solar thermal power plants.

Description

Technical Field

[0001] The present application relates to the technical field of solar thermal power generation, and particularly relates to a method for calculating the direct normal irradiance value of a candidate site and related devices. Background Art

[0002] A solar thermal power generation system includes a solar collector and a solar concentrator system; the solar concentrator system, such as a large mirror, can focus sunlight and concentrate the sunlight onto the solar collector. The solar concentrator system can accurately track the position of the sun to ensure maximum sunlight concentration. The heat transfer working fluid in the solar collector, such as molten salt or mineral oil, is heated, thereby converting light energy into heat energy. This heated working fluid is then used to heat water to generate high-temperature and high-pressure steam. The high-temperature and high-pressure steam drives the steam turbine to rotate, and the steam turbine drives the generator to generate electric energy. Thus, the conversion of light energy into electric energy is achieved. A solar thermal power generation system can only utilize direct normal irradiance (DNI), and the diffuse radiation in solar radiation cannot be utilized by the solar thermal power generation system. Therefore, DNI is the first consideration in the selection of the site for a solar thermal power generation station, and the magnitude of the direct normal irradiance value directly determines the feasibility and economy of the project.

[0003] Therefore, how to determine the direct normal irradiance value of a candidate site is a technical problem that urgently needs to be solved in this field. Summary of the Invention

[0004] In view of the above problems, the present application provides a method for calculating the direct normal irradiance value of a candidate site and related devices to achieve the purpose of obtaining a relatively accurate direct normal irradiance value. The specific solutions are as follows:

[0005] The first aspect of the present application provides a method for calculating the direct normal irradiance value of a candidate site, including:

[0006] Obtaining a first direct normal irradiance value on the ground at a first moment and a second direct normal irradiance value on the ground at a second moment, where the second moment is later than the first moment;

[0007] Determining the difference between the second direct normal irradiance value on the ground and the first direct normal irradiance value on the ground as the actual direct normal irradiance change value;

[0008] Searching for a target maximum direct normal irradiance change value corresponding to the direct normal irradiance value interval where the first direct normal irradiance value on the ground is located from the corresponding relationship between a preset direct normal irradiance value interval and the maximum direct normal irradiance change value that a solar collector can withstand;

[0009] Determine the minimum value of the actual direct solar irradiance change value and the target maximum direct solar irradiance change value as the corrected solar irradiance change value;

[0010] Determine the first corrected direct solar irradiance value corresponding to the second moment as the sum of the first ground direct solar irradiance value and the modified solar irradiance change value;

[0011] Obtain the preset defrosting time corresponding to the candidate site;

[0012] Obtain the measured ambient temperature, measured ambient humidity, and measured ambient wind speed of the candidate site at the second moment;

[0013] If the second moment is greater than the preset defrosting time, determine the second corrected direct solar irradiance value as the second ground direct solar irradiance value;

[0014] Calculate the defrosting probability based on the set ambient temperature, set ambient wind speed, set ambient humidity, the measured ambient temperature, the measured ambient humidity, and the measured ambient wind speed; the set ambient temperature, the set ambient wind speed, and the set ambient humidity are the critical values of the frosting condition;

[0015] If the second moment is earlier than or equal to the preset defrosting time, determine the second corrected direct solar irradiance value as the product of the second ground direct solar irradiance value and the defrosting probability;

[0016] Calculate the wind speed correction coefficient based on the measured ambient wind speed, the first preset wind speed, and the second preset wind speed;

[0017] Wherein, the first preset wind speed is the minimum wind speed affecting the heat collection of the solar collector, and the second preset wind speed is the wind speed triggering the solar collector to enter the protection state;

[0018] If the difference between the second moment and the third moment is greater than the preset duration and the wind speed correction coefficient is greater than 0, determine the third corrected direct solar irradiance value as the product of the second ground direct solar irradiance value and the wind speed correction coefficient; the third moment is the start moment when the solar collector switches from the normal working state to the protection state, and the third moment is earlier than the second moment;

[0019] If the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0, determine the third corrected direct solar irradiance value as 0;

[0020] Determine the corrected direct solar irradiance value at the second moment based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value.

[0021] In a possible implementation, the step of determining the corrected direct solar irradiance value at the second moment based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value includes:

[0022] Determine that the corrected direct solar irradiance value at the second moment is the minimum value among the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value.

[0023] In a possible implementation, the step of calculating the wind speed correction coefficient based on the measured ambient wind speed, the first preset wind speed, and the second preset wind speed includes:

[0024] Through the formula , calculate the wind speed correction coefficient; where η is the wind speed correction coefficient, V is the measured ambient wind speed, V n is the first preset wind speed, V m is the second preset wind speed; a is the first preset coefficient, b is the second preset coefficient, and c is the third preset coefficient.

[0025] In a possible implementation, the step of calculating the defrosting probability based on the set ambient temperature, the set ambient wind speed, the set ambient humidity, the measured ambient temperature, the measured ambient humidity, and the measured ambient wind speed includes:

[0026] Through the formula , calculate the defrosting probability; where N is the defrosting probability, T is the measured ambient temperature, H is the measured ambient humidity, V is the measured ambient wind speed, T s is the set ambient temperature, H s is the set ambient humidity, V S is the set ambient wind speed.

[0027] In a possible implementation, the step of obtaining the measured ambient temperature, the measured ambient humidity, and the measured ambient wind speed of the candidate site at the second moment includes:

[0028] Search for the target Beijing time corresponding to the second moment of the candidate site from the correspondence between the preset Beijing time and the real time of the candidate site;

[0029] Search for the set ambient humidity, the set ambient temperature, and the set ambient wind speed corresponding to the target Beijing time from the correspondence between the preset Beijing time and the set ambient humidity, the set ambient temperature, and the set ambient wind speed.

[0030] The second aspect of the present application provides a calculation device for the direct solar irradiance value of a candidate site, including:

[0031] A first acquisition module, configured to acquire a first ground direct solar irradiance value at a first moment and a second ground direct solar irradiance value at a second moment, where the second moment is later than the first moment;

[0032] A first determination module, configured to determine the difference between the second ground direct solar irradiance value and the first ground direct solar irradiance value as the actual direct solar irradiance change value;

[0033] A first search module, configured to search, from the correspondence between a preset direct solar irradiance value interval and the maximum direct solar irradiance change value that a solar collector can withstand, for the target maximum direct solar irradiance change value corresponding to the direct solar irradiance value interval where the first ground direct solar irradiance value is located;

[0034] A second determination module, configured to determine the minimum value of the actual direct solar irradiance change value and the target maximum direct solar irradiance change value as the corrected solar irradiance change value;

[0035] A third determination module, configured to determine the first corrected direct solar irradiance value corresponding to the second moment as the sum of the first ground direct solar irradiance value and the modified solar irradiance change value;

[0036] A second acquisition module, configured to acquire the preset defrosting time corresponding to the candidate site;

[0037] A third acquisition module, configured to acquire the measured ambient temperature, measured ambient humidity, and measured ambient wind speed of the candidate site at the second moment;

[0038] A fourth determination module, configured to determine the second corrected direct solar irradiance value as the second ground direct solar irradiance value if the second moment is greater than the preset defrosting time;

[0039] A first calculation module, configured to calculate a defrosting probability based on a set ambient temperature, set ambient wind speed, set ambient humidity, the measured ambient temperature, the measured ambient humidity, and the measured ambient wind speed; the set ambient temperature, the set ambient wind speed, and the set ambient humidity are critical values of frosting conditions;

[0040] A fifth determination module, configured to determine the second corrected direct solar irradiance value as the product of the second ground direct solar irradiance value and the defrosting probability if the second moment is earlier than or equal to the preset defrosting time;

[0041] A second calculation module, configured to calculate a wind speed correction coefficient based on the measured ambient wind speed, a first preset wind speed, and a second preset wind speed;

[0042] Wherein, the first preset wind speed is the minimum wind speed that affects the heat collection of the solar collector, and the second preset wind speed is the wind speed that triggers the solar collector to enter the protection state;

[0043] A sixth determination module, configured to determine that the third corrected solar direct irradiance value is the product of the second ground solar direct irradiance value and the wind speed correction coefficient if the difference between the second moment and the third moment is greater than a preset duration and the wind speed correction coefficient is greater than 0; the third moment is the start moment when the solar collector switches from the normal working state to the protection state, and the third moment is earlier than the second moment;

[0044] A seventh determination module, configured to determine that the third corrected solar direct irradiance value is 0 if the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0;

[0045] An eighth determination module, configured to determine the corrected solar direct irradiance value at the second moment based on the first corrected solar direct irradiance value, the second corrected solar direct irradiance value, and the third corrected solar direct irradiance value.

[0046] In a possible implementation, the eighth determination module includes:

[0047] A determination unit, configured to determine that the corrected solar direct irradiance value at the second moment is the minimum value among the first corrected solar direct irradiance value, the second corrected solar direct irradiance value, and the third corrected solar direct irradiance value.

[0048] In an alternative implementation, the second calculation module is specifically configured to:

[0049] Through the formula , calculate the wind speed correction coefficient; where η is the wind speed correction coefficient, V is the measured ambient wind speed, V n is the first preset wind speed, V m is the second preset wind speed; a is a first preset coefficient, b is a second preset coefficient, and c is a third preset coefficient.

[0050] The third aspect of the present application provides a computer program product, including computer-readable instructions, which, when running on an electronic device, enable the electronic device to implement the method for calculating the solar direct irradiance value of a candidate site address in the first aspect or any implementation manner of the first aspect.

[0051] The fourth aspect of the present application provides an electronic device, including at least one processor and a memory connected to the processor, wherein:

[0052] The memory is used to store a computer program;

[0053] The processor is used to execute the computer program, so that the electronic device can implement the method for calculating the direct solar irradiance value of the candidate site address in the first aspect or any implementation manner of the first aspect.

[0054] The fifth aspect of the present application provides a computer storage medium. The storage medium carries one or more computer programs. When the one or more computer programs are executed by an electronic device, the electronic device can implement the method for calculating the direct solar irradiance value of the candidate site address in the first aspect or any implementation manner of the first aspect.

[0055] By means of the above technical solution, the present application provides a method for calculating the direct solar irradiance value of a candidate site address, focusing on the influence laws of three meteorological conditions, namely cloud cover, frosting, and extreme strong wind, which affect heat collection, on the effective direct solar irradiance. By presetting the corresponding relationship between the direct solar irradiance value interval and the maximum change value of the direct solar irradiance that the solar collector can withstand, after determining the change from the first ground direct solar irradiance value before cloud occlusion to the second ground direct solar irradiance value after cloud non-occlusion, the first corrected direct solar irradiance value corresponding to the energy that the solar collector can actually absorb is determined; based on the measured ambient temperature, measured ambient humidity, measured ambient wind speed of the candidate site address and the critical value of the frosting condition, it is determined whether the solar concentrator system is frosted; if the solar concentrator system is frosted, the second corrected direct solar irradiance value corresponding to the energy that the solar collector can actually absorb is 0, and if the solar concentrator system is not frosted, the second corrected direct solar irradiance value corresponding to the energy that the solar collector can actually absorb is the second ground direct solar irradiance value; if the measured ambient wind speed is greater than the second preset wind speed, the solar collector enters a protection state, and at this time the solar collector does not absorb any energy; if the measured ambient wind speed is less than the first preset wind speed, the solar collector is in a normal operation state, and the solar collector can normally absorb energy; if the measured ambient wind speed is greater than or equal to the first preset wind speed and less than or equal to the second preset wind speed, it will have a certain impact on the solar collector, so a wind speed correction coefficient can be obtained based on the set ambient temperature, set ambient wind speed, set ambient humidity, measured ambient temperature, measured ambient humidity, and measured ambient wind speed. If the difference between the second moment and the third moment is greater than the preset duration and the wind speed correction coefficient is greater than 0, it is determined that the third corrected direct solar irradiance value is the product of the second ground direct solar irradiance value and the wind speed correction coefficient; if the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0, it is determined that the third corrected direct solar irradiance value is 0; based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value, the corrected direct solar irradiance value at the second moment is determined.

[0056] This application combines meteorological parameters such as cloud cover, frosting, and extreme strong winds to correct direct solar irradiance, obtaining a corrected direct solar irradiance value that can be actually utilized, providing a basis and reference for the site selection, investment decision-making, operation, etc. of solar thermal power plants. Description of the Drawings

[0057] In combination with the accompanying drawings and with reference to the following specific embodiments, the above and other features, advantages, and aspects of the various embodiments of the present disclosure will become more apparent. Throughout the drawings, the same or similar reference numerals denote the same or similar elements. It should be understood that the drawings are schematic, and the original components and elements are not necessarily drawn to scale.

[0058] Figure 1 It is a schematic diagram of a system architecture provided by this application;

[0059] Figure 2 It is a schematic diagram of an optional hardware structure of a terminal provided by this application;

[0060] Figure 3 It is a schematic diagram of the structure of a server provided by this application;

[0061] Figure 4 It is a schematic flowchart of a method for calculating the direct solar irradiance value of a candidate site provided by an embodiment of this application;

[0062] Figure 5 It is a schematic diagram of the structure of a device for calculating the direct solar irradiance value of a candidate site provided by an embodiment of this application. Detailed Embodiments

[0063] The following describes the embodiments of this application in combination with the drawings in the embodiments of this application. The terms used in the embodiments part of this application are only used to explain the specific embodiments of this application, and are not intended to limit this application.

[0064] The following describes the embodiments of this application in combination with the drawings. Those skilled in the art know that with the development of technology and the emergence of new scenarios, the technical solutions provided by the embodiments of this application are equally applicable to similar technical problems.

[0065] In the description, claims, and the above-mentioned drawings of this application, terms such as "first" and "second" are used to distinguish similar objects and do not necessarily describe a specific order or sequence. It should be understood that these terms can be interchanged under appropriate circumstances, which is merely a way of distinguishing objects with the same attributes when describing the embodiments of this application. In addition, the terms "comprising" and "having" and any variations thereof are intended to cover non-exclusive inclusion, so that a process, method, system, product, or device comprising a series of units does not have to be limited to those units, but may include other units that are not clearly listed or are inherent to these processes, methods, products, or devices.

[0066] A solar thermal power station includes: a solar concentrating system and a solar collector. The implementation principle of the solar thermal power station will be described below.

[0067] A solar concentrating system, such as a large mirror, can focus sunlight and concentrate it on the solar collector. The solar concentrating system can accurately track the position of the sun to ensure maximum sunlight concentration.

[0068] The heat transfer working fluid in the solar collector, such as molten salt or mineral oil, is heated, thereby converting light energy into heat energy. This heated working fluid is then used to heat water to generate high-temperature and high-pressure steam. The high-temperature and high-pressure steam drives the steam turbine to rotate, and the steam turbine drives the generator to generate electric energy. Thus, the conversion of light energy to electric energy is achieved.

[0069] In the related art, the efficiency of converting light energy into electric energy is judged based on the direct normal irradiance value on the ground. The larger the direct normal irradiance value on the ground, the higher the efficiency of converting light energy into electric energy; the smaller the direct normal irradiance value on the ground, the lower the efficiency of converting light energy into electric energy. This method of judging the efficiency of converting light energy into electric energy is inaccurate for the following reasons:

[0070] Reason 1: The solar concentrating system concentrates sunlight on the solar collector, and the solar collector absorbs the direct normal irradiance energy. If the direct normal irradiance value on the ground changes greatly within a unit time, in order to avoid damage to the solar collector, the solar concentrating system will not concentrate all the sunlight on the solar collector. Even if the direct normal irradiance value on the ground changes greatly within a unit time, the direct normal irradiance energy that the solar collector can absorb is limited and may not be fully absorbed.

[0071] Because the solar collector is made of metal, due to material properties such as fatigue characteristics, after the solar collector is irradiated by sunlight with a first ground direct solar irradiance value (when the sun is blocked by clouds) for a period of time, the temperature of the solar collector tends to be stable, and the maximum change value of the direct irradiance that the solar collector can absorb is related to the first ground direct solar irradiance value; if at a second moment (when the clouds do not block the sun), it changes to sunlight with a second ground direct solar irradiance value, since the maximum change value of the direct irradiance that the solar collector can absorb is limited, it may not be able to absorb all of the second ground direct solar irradiance value. Therefore, the efficiency of converting light energy into electrical energy cannot be judged solely based on the direct solar irradiance value on the ground.

[0072] It can be understood that the reason for the change in the direct solar irradiance value is clouds. If the clouds cover the sun, the direct solar irradiance value on the ground is small; if the clouds are blown away and no longer block the sun, the direct solar irradiance value on the ground is large. That is, before and after the clouds block the sun, it will cause a large change in the direct solar irradiance value on the ground per unit time.

[0073] Exemplarily, the unit time can be determined based on the actual situation. For example, the unit time is 10 minutes.

[0074] Reason two: The solar concentrator system can be a mirror. If the solar concentrator system is frosted, the solar concentrator system cannot concentrate sunlight into the solar collector. At this time, although the direct solar irradiance value on the ground is not 0, the solar collector cannot absorb any energy. Therefore, the efficiency of converting light energy into electrical energy cannot be judged solely based on the direct solar irradiance value on the ground.

[0075] Reason three: In strong wind weather, if it is detected that the wind speed is higher than the second preset wind speed, in order to protect the solar collector, the solar collector is controlled to switch from the normal working state to the protection state; if it is detected that the wind speed is lower than the first preset wind speed, the solar collector is controlled to switch from the protection state to the normal working state. During the process of switching from the normal working state to the protection state, the process of switching from the protection state to the normal working state, and the process in the protection state, the solar collector will not absorb any energy.

[0076] During the process of switching from the normal working state to the protection state, the process of switching from the protection state to the normal working state, and the process in the protection state, even if the direct solar irradiance value on the ground is not 0, the solar collector cannot absorb any energy. Therefore, the efficiency of converting light energy into electrical energy cannot be judged solely based on the direct solar irradiance value on the ground.

[0077] Based on this, the present application proposes a method for calculating the direct solar irradiance value of a candidate site, which combines meteorological conditions such as cloud cover, frosting, and strong wind to obtain a relatively accurate corrected direct solar irradiance value.

[0078] See Figure 1 , Figure 1 which shows a schematic diagram of a system architecture. The system may include: a direct solar irradiance meter 100 disposed at a candidate site corresponding to a solar thermal power plant, a database 200, a wind speed sensor 300 for measuring the actual ambient wind speed of the candidate site, a temperature sensor 400 for measuring the actual ambient temperature of the candidate site, a humidity sensor 500 for measuring the actual ambient humidity of the candidate site, and an electronic device 600.

[0079] Exemplarily, the direct solar irradiance meter 100 can measure the direct solar irradiance value irradiating the ground surface. Therefore, in the embodiments of the present application, the direct solar irradiance value measured by the direct solar irradiance meter 100 is referred to as the ground surface direct solar irradiance value.

[0080] Exemplarily, a ground surface direct solar irradiance value can be obtained every unit time interval, so as to obtain a plurality of ground surface direct solar irradiance values sorted by time. Exemplarily, the ground surface direct solar irradiance values corresponding to each moment are stored in the database 200.

[0081] Exemplarily, the database 200 stores the corresponding relationship between a preset direct solar irradiance value interval and the maximum direct solar irradiance change value that a solar collector can withstand, and the critical value of the frosting condition, such as the set ambient temperature, the set ambient wind speed, and the set ambient humidity.

[0082] It can be understood that the data stored in the database 200 can be updated. For example, other servers send the updated data to the database 200.

[0083] Exemplarily, the actual ambient wind speeds corresponding to each moment measured by the wind speed sensor 300 can be stored in the database 200.

[0084] Exemplarily, the actual ambient temperatures corresponding to each moment measured by the temperature sensor 400 can be stored in the database 200.

[0085] Exemplarily, the actual ambient humidities corresponding to each moment measured by the humidity sensor 500 can be stored in the database 200.

[0086] The electronic device 600 can, based on the data stored in the database 200, for each moment, which is referred to as the second moment in the embodiments of the present application, execute the method for calculating the direct solar irradiance value of the candidate site provided in the embodiments of the present application.

[0087] Exemplarily, the electronic device 600 can be a terminal or a server.

[0088] Exemplarily, the terminal may be a mobile phone, a tablet computer, a wearable device, a vehicle-mounted device, an augmented reality (AR) / virtual reality (VR) device, a laptop computer, an ultra-mobile personal computer (UMPC), a netbook, a personal digital assistant (PDA), etc., and the embodiments of the present application do not impose any restrictions thereon.

[0089] Figure 2 FIG. shows a schematic diagram of an optional hardware structure of the terminal.

[0090] Referring to Figure 2 as shown, the terminal may include a radio frequency unit 110, a memory 120, an input unit 130, a display unit 140, a camera 150 (optional), an audio circuit 160 (optional), a speaker 161 (optional), a microphone 162 (optional), a headphone jack 163 (optional), a processor 170, an external interface 180, a power supply 190, and other components. Those skilled in the art can understand that Figure 2 this is merely an example of the terminal and does not constitute a limitation on the terminal. It may include more or fewer components than shown in the figure, or combine certain components, or different components.

[0091] The input unit 130 can be used to receive input digital or character information, and generate key signal inputs related to the user settings and function controls of the terminal. Specifically, the input unit 130 may include a touch screen 131 (optional) and / or other input devices 132. The touch screen 131 can collect touch operations of the user thereon or nearby (such as operations of the user using a finger, a joint, a stylus, or any suitable object on or near the touch screen), and drive the corresponding connection device according to a pre-set program. The touch screen can detect the touch actions of the user on the touch screen, convert the touch actions into touch signals and send them to the processor 170, and can receive commands sent by the processor 170 and execute them; the touch signals at least include contact coordinate information. The touch screen 131 can provide an input interface and an output interface between the terminal and the user. In addition, various types such as resistive, capacitive, infrared, and surface acoustic wave can be used to implement the touch screen. In addition to the touch screen 131, the input unit 130 may further include other input devices. Specifically, the other input devices 132 may include, but are not limited to, one or more of a physical keyboard, function keys (such as volume control keys, switch keys, etc.), a trackball, a mouse, a joystick, etc.

[0092] Among them, the input device 132 can receive input data and the like.

[0093] The display unit 140 can be used to display information input by the user or information provided to the user, various menus of the terminal, an interactive interface, file display, and / or the playing of any multimedia file. In the embodiments of the present application, the display unit 140 can be used to display an interface of the corrected direct solar irradiance value at the second moment, a processing result, etc.

[0094] The memory 120 can be used to store instructions and data. The memory 120 mainly includes a storage instruction area and a storage data area. The storage data area can store various data, such as multimedia files, texts, etc.; the storage instruction area can store software units such as an operating system, an application, instructions required for at least one function, or their subsets or extended sets. It can also include a non-volatile random access memory; it provides for the processor 170 to manage the hardware, software, and data resources in the computing processing device, support control software and applications. It is also used for the storage of multimedia files, as well as the storage of running programs and applications.

[0095] The processor 170 is the control center of the terminal. It connects various parts of the entire terminal using various interfaces and lines. By running or executing the instructions stored in the memory 120 and calling the data stored in the memory 120, it executes various functions of the terminal and processes data, thereby performing overall control of the terminal device. Optionally, the processor 170 can include one or more processing units; preferably, the processor 170 can integrate an application processor and a modem processor. Among them, the application processor mainly processes the operating system, user interface, and application programs, etc., and the modem processor mainly processes wireless communication. It can be understood that the above-mentioned modem processor may not be integrated into the processor 170. In some embodiments, the processor and the memory can be implemented on a single chip. In some embodiments, they can also be separately implemented on independent chips. The processor 170 can also be used to generate corresponding operation control signals, send them to corresponding components of the computing processing device, read and process data in the software, especially read and process the data and programs in the memory 120, so that each function module therein executes corresponding functions, thereby controlling the corresponding components to act according to the requirements of the instructions.

[0096] Among them, the memory 120 can be used to store software codes related to the calculation method of the direct solar irradiance value of the candidate site. The processor 170 can execute the steps of the calculation method of the direct solar irradiance value of the candidate site, or can also schedule other units (such as the above input unit 130 and display unit 140) to implement corresponding functions.

[0097] The radio frequency unit 110 (optional) can be used for receiving and transmitting information or signals during a call. For example, after receiving the downlink information from the base station, it is sent to the processor 170 for processing; in addition, the uplink data is sent to the base station. Generally, the RF circuit includes but is not limited to antennas, at least one amplifier, a transceiver, a coupler, a low noise amplifier (LNA), a duplexer, etc. In addition, the radio frequency unit 110 can also communicate with network devices and other devices via wireless communication. This wireless communication can use any communication standard or protocol, including but not limited to Global System of Mobile communication (GSM), General Packet Radio Service (GPRS), Code Division Multiple Access (CDMA), Wideband Code Division Multiple Access (WCDMA), Long Term Evolution (LTE), email, Short Messaging Service (SMS), etc.

[0098] Among them, in the embodiment of this application, the radio frequency unit 110 can send data to the server and receive the processing result sent by the server.

[0099] It should be understood that the radio frequency unit 110 is optional and can be replaced by other communication interfaces, such as a network port.

[0100] The terminal also includes a power supply 190 (such as a battery) for powering each component. Preferably, the power supply can be logically connected to the processor 170 through a power management system, so as to realize functions such as management of charging, discharging, and power consumption management through the power management system.

[0101] The terminal also includes an external interface 180, which can be a standard Micro USB interface or a multi-pin connector. It can be used to connect the terminal to other devices for communication and can also be used to connect a charger to charge the terminal.

[0102] Although not shown, the terminal may also include a flashlight, a wireless fidelity (WiFi) module, a Bluetooth module, sensors with different functions, etc., which will not be elaborated here. Some or all of the methods described below can be applied to the terminal as Figure 2 shown.

[0103] Next, describe Figure 1Product form of the middle server;

[0104] Figure 3 A schematic structural diagram of a server is provided, as Figure 3 shown. The server includes a bus 201, a processor 202, a communication interface 203, and a memory 204. The processor 202, the memory 204, and the communication interface 203 communicate with each other through the bus 201.

[0105] The bus 201 can be a Peripheral Component Interconnect (PCI) bus or an Extended Industry Standard Architecture (EISA) bus, etc. The bus can be divided into an address bus, a data bus, a control bus, etc. For the sake of simplicity in representation, Figure 3 only a thick line is used in the figure to represent it, but it does not mean that there is only one bus or one type of bus.

[0106] The processor 202 can be any one or more of a central processing unit (CPU), a graphics processing unit (GPU), a microprocessor (MP), or a digital signal processor (DSP), etc.

[0107] The memory 204 can include volatile memory, such as random access memory (RAM). The memory 204 can also include non-volatile memory, such as read-only memory (ROM), flash memory, a hard disk drive (HDD), or a solid state drive (SSD).

[0108] Among them, the memory 204 can be used to store software codes related to the calculation method of the direct solar irradiance value of the candidate site, and the processor 202 can execute the steps of the calculation method of the direct solar irradiance value of the candidate site of the chip, or can also schedule other units to implement the corresponding functions.

[0109] It should be understood that the above terminal and server can be centralized or distributed devices, and the processors in the above terminal and server (such as processor 170 and processor 202) can be hardware circuits (such as application specific integrated circuit (ASIC), field-programmable gate array (FPGA), general-purpose processor, digital signal processing (DSP), microprocessor or microcontroller, etc.), or a combination of these hardware circuits. For example, the processor can be a hardware system with the function of executing instructions, such as CPU, DSP, etc., or a hardware system without the function of executing instructions, such as ASIC, FPGA, etc., or a combination of the above hardware system without the function of executing instructions and the hardware system with the function of executing instructions.

[0110] Referring to Figure 4 , Figure 4 FIG. is a schematic flow chart of a method for calculating the direct solar irradiance value of a candidate site provided by an embodiment of the present application. As Figure 4 shown, for a method for calculating the direct solar irradiance value of a candidate site provided by an embodiment of the present application, for any moment, which is referred to as the second moment in an embodiment of the present application, the method may include steps 401 to 414, and the following will describe these steps in detail.

[0111] Step 401: Obtain the first surface direct solar irradiance value at the first moment and the second surface direct solar irradiance value at the second moment.

[0112] The second moment is later than the first moment.

[0113] Exemplarily, the first moment is the moment when the sun is blocked by clouds, and the second moment is the moment when the sun is not blocked by clouds.

[0114] Exemplarily, the first surface direct solar irradiance value and the second surface direct solar irradiance value can be measured by the direct solar irradiance meter 100.

[0115] Step 402: Determine the difference between the second surface direct solar irradiance value and the first surface direct solar irradiance value as the actual direct solar irradiance change value.

[0116] Steps 401 to 405 are the calculation process of the influence of cloud cover meteorological conditions on the effective direct solar irradiance value.

[0117] Step 403: Look up the target maximum solar direct irradiance change value corresponding to the solar direct irradiance value range where the first ground solar direct irradiance value is located from the corresponding relationship between the preset solar direct irradiance value range and the maximum solar direct irradiance change value that the solar collector can withstand.

[0118] It can be understood that the change in the solar direct irradiance value before and after being blocked by clouds is relatively large, but the maximum solar direct irradiance energy that the solar collector can absorb is limited. Therefore, the corresponding relationship between the solar direct irradiance value range and the maximum solar direct irradiance change value that the solar collector can withstand is preset. The following is an example to illustrate the above corresponding relationship. Suppose the above corresponding relationship is represented by a table, then the above corresponding relationship can be shown in Table 1.

[0119] Table 1

[0120]

[0121] It can be understood that the higher the solar direct irradiance value, the higher the temperature of the solar collector. Therefore, the maximum solar direct irradiance change value may change. When the first ground solar direct irradiance value belongs to any of the above intervals, regardless of the magnitude of the second solar direct irradiance value, the change value corresponding to the maximum energy that the solar collector can absorb is ΔE.

[0122] If the first ground solar direct irradiance value is 220 W / m 2 , and the second ground solar direct irradiance value is 420 W / m 2 , then the target maximum solar direct irradiance change value corresponding to the target interval (200, 300] is 100 W. At the second moment, the ground solar direct irradiance value corresponding to the energy that the solar collector can actually absorb is 320 W / m 2 , rather than 420 W / m 2 .

[0123] Exemplarily, the time difference between the second moment and the first moment can be determined based on the actual situation. For example, 10 minutes.

[0124] Step 404: Determine the minimum value of the actual solar direct irradiance change value and the target maximum solar direct irradiance change value as the corrected solar irradiance change value.

[0125] It can be understood that the "corresponding relationship between the preset solar direct irradiance value range and the maximum solar direct irradiance change value that the solar collector can withstand" can correspond to a piecewise function, and the piecewise function is as follows:

[0126] , where, in the interval (A i ,A i+1 , Ai is the lower limit of the interval, A i+1 is the upper limit of the interval. ΔEi is the maximum direct solar irradiance change value corresponding to (A i , A i+1 . i is a positive integer greater than or equal to 1; Q is a positive integer greater than or equal to 1. W D1 is the first direct solar irradiance value on the ground surface.

[0127] Exemplarily, step 404 specifically includes: if the actual direct solar irradiance change value is less than or equal to the target maximum direct solar irradiance change value, determining the corrected solar irradiance change value as the actual direct solar irradiance change value; if the actual direct solar irradiance change value is greater than the target maximum direct solar irradiance change value, determining the corrected solar irradiance change value as the target maximum direct solar irradiance change value. The specific formula is as follows:

[0128] , where, ΔW DX is the corrected solar irradiance change value. ΔW D is the actual direct solar irradiance change value. That is, ΔW D = the second direct solar irradiance value on the ground surface - the first direct solar irradiance value on the ground surface.

[0129] It can be understood that if the actual direct solar irradiance change value is less than or equal to the target maximum direct solar irradiance change value, it means that the solar collector can absorb the energy corresponding to the actual direct solar irradiance change value, so the corrected solar irradiance change value is the actual direct solar irradiance change value. If the actual direct solar irradiance change value is greater than the target maximum direct solar irradiance change value, it means that the solar collector can absorb the energy corresponding to the target maximum direct solar irradiance change value, but cannot absorb all the energy corresponding to the actual direct solar irradiance change value, so the corrected solar irradiance change value is the target maximum direct solar irradiance change value.

[0130] Step 405: Determine the first corrected direct solar irradiance value corresponding to the second moment as the sum of the first direct solar irradiance value on the ground surface and the modified solar irradiance change value.

[0131] Exemplarily, the first corrected direct solar irradiance value W DX = the first direct solar irradiance value on the ground surface + ΔW DX .

[0132] Exemplarily, the first corrected direct solar irradiance value W at the Kth moment DXK = the first direct solar irradiance value on the ground surface at the (K - 1)th moment + ΔW DXK . ΔW DXK = the second direct solar irradiance value on the ground surface at the Kth moment - the first direct solar irradiance value on the ground surface at the (K - 1)th moment.

[0133] Step 406: Obtain the preset defrosting time corresponding to the to-be-selected plant site.

[0134] Exemplarily, the standard defrosting time can be obtained from the database 200. It can be understood that the standard defrosting time is Beijing time. However, the actual time of the to-be-selected plant site may be different from Beijing time.

[0135] The following is an example for illustration.

[0136] Suppose the to-be-selected plant site is at geographical location AA. 10:10 am at geographical location AA may correspond to 7:10 am Beijing time, that is, the actual time at geographical location AA is 3 hours later than Beijing time. If the standard defrosting time is 12:00 Beijing time, then the preset defrosting time at geographical location AA is 3:00 pm.

[0137] The preset defrosting time refers to the time when the frost on the solar concentrator system disappears. It can be understood that if the current time is greater than the preset defrosting time, there is no frost on the solar concentrator system; if the current time is less than or equal to the preset defrosting time, whether there is frost on the solar concentrator system needs to be determined according to the actual situation.

[0138] Steps 405 to 410 are the calculation process of the influence of frosting meteorological conditions on the effective direct solar irradiance value.

[0139] Step 407: Obtain the measured ambient temperature, measured ambient humidity, and measured ambient wind speed of the to-be-selected plant site at the second moment.

[0140] Exemplarily, the measured ambient temperature, measured ambient humidity, and measured ambient wind speed of the to-be-selected plant site at Beijing time can be obtained from the database 200. However, the actual time of the to-be-selected plant site may be different from Beijing time. If the actual time of the to-be-selected plant site is the same as Beijing time, the measured ambient temperature, measured ambient humidity, and measured ambient wind speed corresponding to the second moment can be directly obtained from the database 200. If the actual time of the to-be-selected plant site is different from Beijing time, then Step 407 may include the following Steps A1 to A2.

[0141] Step A1: Search for the target Beijing time corresponding to the second moment of the to-be-selected plant site from the corresponding relationship between the preset Beijing time and the actual time of the to-be-selected plant site.

[0142] Step A2: Search for the set ambient humidity, set ambient temperature, and set ambient wind speed corresponding to the target Beijing time from the corresponding relationship between the preset Beijing time and the set ambient humidity, set ambient temperature, and set ambient wind speed.

[0143] Exemplarily, the second moment of the candidate site = Beijing time when the second ground direct solar irradiance value is obtained - (true time zone S - 8 of the candidate site). The true time zone of the candidate site refers to the time zone of the area where the candidate site is located.

[0144] Step 408: If the second moment is greater than the preset defrosting time, determine that the second corrected direct solar irradiance value is the second ground direct solar irradiance value.

[0145] It can be understood that if the second moment is greater than the preset defrosting time, even if the solar concentrator system has been frosted, due to solar irradiation, there is no frost on the solar concentrator system. Therefore, the solar concentrator system can concentrate sunlight into the solar collector, so the second corrected direct solar irradiance value is the second ground direct solar irradiance value.

[0146] Step 409: Calculate the defrosting probability based on the set environmental temperature, set environmental wind speed, set environmental humidity, the measured environmental temperature, the measured environmental humidity, and the measured environmental wind speed.

[0147] The set environmental temperature, the set environmental wind speed, and the set environmental humidity are the critical values of the frosting conditions.

[0148] Exemplarily, step 409 specifically includes the following steps:

[0149] Through the formula , calculate the defrosting probability; where N is the defrosting probability, T is the measured environmental temperature, H is the measured environmental humidity, V is the measured environmental wind speed, T s is the set environmental temperature, H s is the set environmental humidity, V S is the set environmental wind speed.

[0150] It can be understood that if the measured environmental temperature is less than the set environmental temperature, the measured environmental humidity is greater than the set environmental humidity, and the measured environmental wind speed is less than the set environmental wind speed, the frosting conditions are met and frost will form on the solar concentrator system. Otherwise, if the frosting conditions are not met, no frost will form on the solar concentrator system.

[0151] Step 410: If the second moment is earlier than or equal to the preset defrosting time, determine that the second corrected direct solar irradiance value is the product of the second ground direct solar irradiance value and the defrosting probability.

[0152] The formulas corresponding to steps 408 to 410 are as follows:

[0153] , where W D2 is the second ground direct solar irradiance value, WDS is the second corrected direct solar irradiance value, T i2 is the second moment, T ix is the preset defrosting time.

[0154] The above formula will be illustrated by the following examples.

[0155] Suppose the set ambient temperature T S = 3°C, the set ambient humidity H S = 70%, and the set ambient wind speed V S = 1 m / S. The measured parameters are T = 2°C, H = 85%, V = 1 m / s, that is, T S > T, H S < H, and V is less than V S ), so the defrosting probability N = 0.

[0156] Suppose W D2 = 220 W / m 2 , T i1 = 9 am Beijing time, and the preset defrosting time is 12 o'clock. Suppose the true time zone of the candidate site is in the 9th time zone, that is, S = 9; then based on the formula: the second moment T of the candidate site i2 = the Beijing time T for obtaining the second direct solar irradiance value on the ground i1 - (the true time zone S - 8) of the candidate site. The second moment of the candidate site refers to the time zone of the area where the candidate site is located = 9 - (9 - 8) = 8 o'clock. Since T i2 < T i1 , so W DS= W D2 × N = W D2 × 0 = 0.

[0157] Step 411: Based on the measured ambient wind speed, the first preset wind speed, and the second preset wind speed, calculate the wind speed correction coefficient.

[0158] Wherein, the first preset wind speed is the minimum wind speed affecting the heat collection of the solar collector, and the second preset wind speed is the wind speed triggering the solar collector to enter the protection state.

[0159] Steps 411 to 413 are the calculation process of the influence of extreme high wind meteorological conditions on the effective direct solar irradiance value.

[0160] Exemplarily, the implementation process of step 411 includes:

[0161] Through the formula, , calculate the wind speed correction coefficient; wherein, η is the wind speed correction coefficient, V is the measured ambient wind speed, V n is the first preset wind speed, V mis the second preset wind speed; a is the first preset coefficient, b is the second preset coefficient, and c is the third preset coefficient.

[0162] It can be understood that if the measured ambient wind speed is greater than the second preset wind speed, the solar collector is in the process of switching from the normal working state to the protection state, or is in the protection state; when the solar collector is in the process of switching from the normal working state to the protection state, or in the protection state, the solar collector cannot absorb any energy, so the wind speed correction coefficient η is 0. It can be understood that if the measured ambient wind speed is less than the first preset wind speed, the wind speed has no effect on the solar collector, so the wind speed correction coefficient η is 1. It can be understood that if the measured ambient wind speed is greater than or equal to the first preset wind speed and less than the second preset wind speed, the wind speed has already affected the solar collector, but it will not trigger the solar collector to switch to the protection state, so the wind speed correction coefficient η is related to the magnitude of the measured ambient wind speed.

[0163] Step 412: If the difference between the second moment and the third moment is greater than the preset duration and the wind speed correction coefficient is greater than 0, determine that the third corrected solar direct irradiance value is the product of the second ground solar direct irradiance value and the wind speed correction coefficient.

[0164] The third moment is the start moment when the solar collector switches from the normal working state to the protection state, and the third moment is earlier than the second moment; the preset duration is the duration when the solar collector is in the protection state.

[0165] Step 413: If the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0, determine that the third corrected solar direct irradiance value is 0.

[0166] Exemplarily, the formulas corresponding to Step 412 and Step 413 are as follows:

[0167] , where W DF is the third corrected solar direct irradiance value, T i2 is the second moment, T i3 is the third moment. The third moment is the start moment when the solar collector switches from the normal working state to the protection state.

[0168] If at a certain moment between the third moment and the second moment, the actual ambient wind speed is less than the second preset wind speed, the solar collector needs to switch from the protected state to the normal working state. Exemplarily, ΔT = the duration for the solar collector to switch from the normal working state to the protected state + the duration for the solar collector to switch from the protected state to the normal working state. Because the solar collector does not absorb any energy during the process of switching from the normal working state to the protected state, from the protected state to the normal working state, and when it is in the protected state.

[0169] It can be understood that if T i2 - T i3 ≤ΔT, the solar collector is not in the normal working state, so W DF is 0.

[0170] The following is an example for illustration.

[0171] Suppose the second ground direct solar irradiance value W D2 = 850 W / m 2 , ΔT = 30 min, the third moment when η = 0 is 9:00 am, V n = 10 m / S, V m = 14 m / S, the measured ambient wind speed V = 12 m / S; assume the second moment is 10:00 am, then T i2 - T i3 = 60 min > ΔT; then the calculated wind speed correction coefficient = 85%, and the third corrected direct solar irradiance value = W D2 ×η = 850 * 85% = 722.5 W / m 2 .

[0172] Step 414: Based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value, determine the corrected direct solar irradiance value at the second moment.

[0173] Exemplarily, determine the corrected direct solar irradiance value at the second moment as the minimum value among the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value.

[0174] Exemplarily, determine the first influence weight of the cloud cover meteorological condition on the effective direct solar irradiance value, determine the second influence weight of the frosting meteorological condition on the effective direct solar irradiance value, determine the third influence weight of the extreme high wind meteorological condition on the effective direct solar irradiance value; determine that the first corrected direct solar irradiance value * the first influence weight + the second corrected direct solar irradiance value * the second influence weight + the third corrected direct solar irradiance value * the third influence weight = the corrected direct solar irradiance value at the second moment.

[0175] The embodiment of the present application provides a method for calculating the direct solar irradiance value of a candidate site, focusing on the influence laws of three meteorological conditions, namely cloud cover, frosting, and extreme strong wind, which affect heat collection, on the effective direct solar irradiance. By presetting the corresponding relationship between the direct solar irradiance value range and the maximum change value of the direct solar irradiance that the solar collector can withstand, the first corrected direct solar irradiance value corresponding to the energy that the solar collector can actually absorb is determined after the first ground direct solar irradiance value before cloud occlusion changes to the second ground direct solar irradiance value after cloud non-occlusion; the frosting condition of the solar concentrator system is determined through the measured ambient temperature, measured ambient humidity, measured ambient wind speed, and the critical value of the frosting condition at the candidate site; if the solar concentrator system is frosted, the second corrected direct solar irradiance value corresponding to the energy that the solar collector can actually absorb is 0, and if the solar concentrator system is not frosted, the second corrected direct solar irradiance value corresponding to the energy that the solar collector can actually absorb is the second ground direct solar irradiance value; if the measured ambient wind speed is greater than the second preset wind speed, the solar collector enters a protection state, and at this time, the solar collector does not absorb any energy; if the measured ambient wind speed is less than the first preset wind speed, the solar collector is in a normal operation state, and the solar collector can normally absorb energy; if the measured ambient wind speed is greater than or equal to the first preset wind speed and less than or equal to the second preset wind speed, it will have a certain impact on the solar collector, so a wind speed correction coefficient can be obtained based on the set ambient temperature, set ambient wind speed, set ambient humidity, measured ambient temperature, measured ambient humidity, and measured ambient wind speed. If the difference between the second moment and the third moment is greater than the preset duration and the wind speed correction coefficient is greater than 0, the third corrected direct solar irradiance value is determined to be the product of the second ground direct solar irradiance value and the wind speed correction coefficient; if the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0, the third corrected direct solar irradiance value is determined to be 0; based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value, the corrected direct solar irradiance value at the second moment is determined.

[0176] The present application combines meteorological parameters such as cloud cover, frosting, and extreme strong wind to correct the direct solar irradiance, obtains the corrected direct solar irradiance value that can be actually utilized, and provides a basis and reference for the site selection, investment decision-making, operation, etc. of solar thermal power plants.

[0177] The above introduces a method for calculating the direct solar irradiance value of a candidate site provided by the embodiment of the present application. Next, an apparatus for executing the above method for calculating the direct solar irradiance value of a candidate site will be introduced.

[0178] Please refer to Figure 5 , Figure 5This is a schematic structural diagram of a solar direct irradiation value calculation device for a candidate site provided by an embodiment of the present application. As Figure 5 shown, the solar direct irradiation value calculation device for the candidate site includes:

[0179] A first acquisition module 501, configured to acquire a first ground solar direct irradiation value at a first moment and a second ground solar direct irradiation value at a second moment, where the second moment is later than the first moment;

[0180] A first determination module 502, configured to determine a difference between the second ground solar direct irradiation value and the first ground solar direct irradiation value as an actual solar direct irradiation change value;

[0181] A first search module 503, configured to search, from a correspondence between a preset solar direct irradiation value interval and a maximum solar direct irradiation change value that a solar collector can withstand, for a target maximum solar direct irradiation change value corresponding to the solar direct irradiation value interval where the first ground solar direct irradiation value is located;

[0182] A second determination module 504, configured to determine a minimum value of the actual solar direct irradiation change value and the target maximum solar direct irradiation change value as a corrected solar irradiation change value;

[0183] A third determination module 505, configured to determine a first corrected solar direct irradiation value corresponding to the second moment as a sum of the first ground solar direct irradiation value and the modified solar irradiation change value;

[0184] A second acquisition module 506, configured to acquire a preset defrosting time corresponding to the candidate site;

[0185] A third acquisition module 507, configured to acquire a measured ambient temperature, a measured ambient humidity, and a measured ambient wind speed of the candidate site at the second moment;

[0186] A fourth determination module 508, configured to, if the second moment is greater than the preset defrosting time, determine a second corrected solar direct irradiation value as the second ground solar direct irradiation value;

[0187] A first calculation module 509, configured to calculate a defrosting probability based on a set ambient temperature, a set ambient wind speed, a set ambient humidity, the measured ambient temperature, the measured ambient humidity, and the measured ambient wind speed; the set ambient temperature, the set ambient wind speed, and the set ambient humidity are critical values of frosting conditions;

[0188] A fifth determination module 510, configured to, if the second moment is earlier than or equal to the preset defrosting time, determine the second corrected solar direct irradiation value as a product of the second ground solar direct irradiation value and the defrosting probability;

[0189] A second calculation module 511, configured to calculate a wind speed correction coefficient based on the measured ambient wind speed, a first preset wind speed, and a second preset wind speed;

[0190] Wherein, the first preset wind speed is the minimum wind speed that affects the heat collection of the solar collector, and the second preset wind speed is the wind speed that triggers the solar collector to enter a protection state;

[0191] A sixth determination module 512, configured to determine that the third corrected solar direct irradiance value is the product of the second ground solar direct irradiance value and the wind speed correction coefficient if the difference between the second moment and the third moment is greater than a preset duration and the wind speed correction coefficient is greater than 0; the third moment is the start moment when the solar collector switches from the normal working state to the protection state, and the third moment is earlier than the second moment;

[0192] A seventh determination module 513, configured to determine that the third corrected solar direct irradiance value is 0 if the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0;

[0193] An eighth determination module 514, configured to determine the corrected solar direct irradiance value at the second moment based on the first corrected solar direct irradiance value, the second corrected solar direct irradiance value, and the third corrected solar direct irradiance value.

[0194] In an alternative implementation, the eighth determination module includes:

[0195] A determination unit, configured to determine that the corrected solar direct irradiance value at the second moment is the minimum value among the first corrected solar direct irradiance value, the second corrected solar direct irradiance value, and the third corrected solar direct irradiance value.

[0196] In an alternative implementation, the second calculation module is specifically configured to:

[0197] Through the formula , calculate the wind speed correction coefficient; where η is the wind speed correction coefficient, V is the measured ambient wind speed, V n is the first preset wind speed, V m is the second preset wind speed; a is a first preset coefficient, b is a second preset coefficient, and c is a third preset coefficient.

[0198] In an alternative implementation, the first calculation module is specifically configured to:

[0199] Through the formula , the defrost probability is calculated; where N is the defrost probability, T is the measured ambient temperature, H is the measured ambient humidity, V is the measured ambient wind speed, and T s is the set ambient temperature, and H s is the set ambient humidity, and V S is the set ambient wind speed.

[0200] In an alternative implementation, the third acquisition module includes:

[0201] A first lookup unit, configured to look up the target Beijing time corresponding to the second moment of the candidate site from the correspondence between the preset Beijing time and the true time of the candidate site;

[0202] A second lookup unit, configured to look up the set ambient humidity, set ambient temperature, and set ambient wind speed corresponding to the target Beijing time from the correspondence between the preset Beijing time and the set ambient humidity, set ambient temperature, and set ambient wind speed.

[0203] An embodiment of the present application further provides a computer program product, including computer-readable instructions, which, when run on an electronic device, cause the electronic device to implement any of the solar direct irradiance value calculation methods for candidate sites provided in the embodiments of the present application.

[0204] An embodiment of the present application further provides a computer-readable storage medium, which carries one or more computer programs, and when the one or more computer programs are executed by an electronic device, can cause the electronic device to implement any of the solar direct irradiance value calculation methods for candidate sites provided in the embodiments of the present application.

[0205] In addition, it should be noted that the device embodiments described above are only illustrative. The units described as separate components may or may not be physically separated, and the components shown as units may or may not be physical units, that is, they may be located in one place, or may be distributed to multiple network units. Some or all of the modules can be selected according to actual needs to achieve the purpose of the solution of this embodiment. In addition, in the drawings of the device embodiments provided in the present application, the connection relationships between the modules indicate that they have communication connections, which can be specifically implemented as one or more communication buses or signal lines.

[0206] Through the description of the above embodiments, those skilled in the art can clearly understand that the present application can be implemented by means of software plus necessary general hardware. Of course, it can also be implemented by dedicated hardware including application-specific integrated circuits, dedicated CPUs, dedicated memories, dedicated components, etc. Generally, functions accomplished by computer programs can easily be implemented by corresponding hardware, and the specific hardware structures for implementing the same function can also be various, such as analog circuits, digital circuits or dedicated circuits, etc. However, for the present application, in more cases, software program implementation is a better embodiment. Based on such an understanding, the technical solution of the present application, in essence or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product is stored in a readable storage medium, such as a floppy disk, USB flash drive, mobile hard disk, ROM, RAM, magnetic disk or optical disc of a computer, etc., and includes several instructions for causing a computer device (which can be a personal computer, training device, or network device, etc.) to execute the methods described in various embodiments of the present application.

[0207] In the above embodiments, it can be implemented in whole or in part by software, hardware, firmware or any combination thereof. When implemented using software, it can be implemented in whole or in part in the form of a computer program product.

[0208] The computer program product includes one or more computer instructions. When the computer program instructions are loaded and executed on a computer, the processes or functions described in the embodiments of the present application are generated in whole or in part. The computer can be a general-purpose computer, a dedicated computer, a computer network, or other programmable devices. The computer instructions can be stored in a computer-readable storage medium, or transmitted from one computer-readable storage medium to another computer-readable storage medium. For example, the computer instructions can be transmitted from one website, computer, training device or data center to another website, computer, training device or data center in a wired manner (such as coaxial cable, optical fiber, digital subscriber line (DSL)) or a wireless manner (such as infrared, wireless, microwave, etc.). The computer-readable storage medium can be any available medium that a computer can store or a data storage device such as a training device or data center that includes one or more integrated available media. The available medium can be a magnetic medium (for example, floppy disk, hard disk, magnetic tape), an optical medium (for example, DVD), or a semiconductor medium (for example, solid state disk (SSD)), etc.

Claims

1. A calculation method for the direct solar irradiance value of a candidate site for a plant, characterized in that, Including: Obtaining a first ground direct solar irradiance value at a first moment and a second ground direct solar irradiance value at a second moment, where the second moment is later than the first moment; Determining the difference between the second ground direct solar irradiance value and the first ground direct solar irradiance value as the actual direct solar irradiance change value; Searching for a target maximum direct solar irradiance change value corresponding to the solar direct irradiance value interval where the first ground direct solar irradiance value is located from the corresponding relationship between the preset solar direct irradiance value interval and the maximum direct solar irradiance change value that the solar collector can withstand; Determining the minimum value of the actual direct solar irradiance change value and the target maximum direct solar irradiance change value as the corrected solar irradiance change value; Determining the first corrected direct solar irradiance value corresponding to the second moment as the sum of the first ground direct solar irradiance value and the corrected solar irradiance change value; Obtaining the preset defrosting time corresponding to the to-be-selected plant site; Obtaining the measured ambient temperature, measured ambient humidity, and measured ambient wind speed at the to-be-selected plant site at the second moment; If the second moment is greater than the preset defrosting time, determining the second corrected direct solar irradiance value as the second ground direct solar irradiance value; Calculating a defrosting probability based on the set ambient temperature, set ambient wind speed, set ambient humidity, the measured ambient temperature, the measured ambient humidity, and the measured ambient wind speed; the set ambient temperature, the set ambient wind speed, and the set ambient humidity are the critical values of the frosting condition; If the second moment is earlier than or equal to the preset defrosting time, determining the second corrected direct solar irradiance value as the product of the second ground direct solar irradiance value and the defrosting probability; Calculating a wind speed correction coefficient based on the measured ambient wind speed, a first preset wind speed, and a second preset wind speed; Wherein, the first preset wind speed is the minimum wind speed affecting the heat collection of the solar collector, and the second preset wind speed is the wind speed triggering the solar collector to enter the protection state; If the difference between the second moment and the third moment is greater than a preset duration and the wind speed correction coefficient is greater than 0, determining the third corrected direct solar irradiance value as the product of the second ground direct solar irradiance value and the wind speed correction coefficient; the third moment is the start moment when the solar collector switches from the normal working state to the protection state, and the third moment is earlier than the second moment; If the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0, determining the third corrected direct solar irradiance value as 0; Determining the corrected direct solar irradiance value at the second moment based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value.

2. The method for calculating the direct solar irradiance value of the candidate site according to claim 1, characterized in that The step of determining the corrected direct solar irradiance value at the second moment based on the first corrected direct solar irradiance value, the second corrected direct solar irradiance value, and the third corrected direct solar irradiance value includes: Determine that the corrected solar direct irradiance value at the second moment is the minimum of the first corrected solar direct irradiance value, the second corrected solar direct irradiance value, and the third corrected solar direct irradiance value.

3. The method for calculating the direct solar irradiance value of the candidate site according to claim 1, characterized in that, The step of calculating the wind speed correction coefficient based on the measured environmental wind speed, the first preset wind speed, and the second preset wind speed includes: The wind speed correction coefficient is calculated through the formula where η is the wind speed correction coefficient, V is the measured ambient wind speed, V n is the first preset wind speed, V m is the second preset wind speed; a is the first preset coefficient, b is the second preset coefficient, and c is the third preset coefficient.

4. The method for calculating the direct solar irradiance value of the candidate site according to claim 1, characterized in that, The step of calculating the defrost probability based on the set environmental temperature, the set environmental wind speed, the set environmental humidity, the measured environmental temperature, the measured environmental humidity, and the measured environmental wind speed includes: The defrost probability is calculated through the formula where N is the defrost probability, T is the measured ambient temperature, H is the measured ambient humidity, V is the measured ambient wind speed, T s is the set ambient temperature, H s is the set ambient humidity, and V S is the set ambient wind speed.

5. The method for calculating the direct solar irradiance value of the candidate site according to any one of claims 1 to 4, characterized in that, The step of obtaining the measured environmental temperature, the measured environmental humidity, and the measured environmental wind speed of the candidate site at the second moment includes: Search for the target Beijing time corresponding to the second moment of the candidate site from the correspondence between the preset Beijing time and the true time of the candidate site; Search for the set environmental humidity, the set environmental temperature, and the set environmental wind speed corresponding to the target Beijing time from the correspondence between the preset Beijing time and the set environmental humidity, the set environmental temperature, and the set environmental wind speed.

6. A solar direct irradiance value calculation device for a to-be-selected site, characterized in that, Includes: A first acquisition module for acquiring the first ground solar direct irradiance value at the first moment and the second ground solar direct irradiance value at the second moment, where the second moment is later than the first moment; A first determination module for determining that the difference between the second ground solar direct irradiance value and the first ground solar direct irradiance value is the actual solar direct irradiance change value; A first search module for searching for the target maximum solar direct irradiance change value corresponding to the solar direct irradiance value interval where the first ground solar direct irradiance value is located from the correspondence between the preset solar direct irradiance value interval and the maximum solar direct irradiance change value that the solar collector can withstand; A second determination module for determining that the minimum value of the actual solar direct irradiance change value and the target maximum solar direct irradiance change value is the corrected solar irradiance change value; A third determination module for determining that the first corrected solar direct irradiance value corresponding to the second moment is the sum of the first ground solar direct irradiance value and the corrected solar irradiance change value; A second acquisition module for acquiring the preset defrost time corresponding to the candidate site; A third acquisition module for acquiring the measured environmental temperature, the measured environmental humidity, and the measured environmental wind speed of the candidate site at the second moment; A fourth determination module for determining that the second corrected solar direct irradiance value is the second ground solar direct irradiance value if the second moment is greater than the preset defrost time; A first calculation module for calculating the defrost probability based on the set environmental temperature, the set environmental wind speed, the set environmental humidity, the measured environmental temperature, the measured environmental humidity, and the measured environmental wind speed; the set environmental temperature, the set environmental wind speed, and the set environmental humidity are the critical values of the frosting conditions; A fifth determination module for determining that the second corrected solar direct irradiance value is the product of the second ground solar direct irradiance value and the defrost probability if the second moment is earlier than or equal to the preset defrost time; A second calculation module, configured to calculate a wind speed correction coefficient based on the measured environmental wind speed, a first preset wind speed, and a second preset wind speed; Wherein, the first preset wind speed is the minimum wind speed that affects the heat collection of the solar collector, and the second preset wind speed is the wind speed that triggers the solar collector to enter a protection state; A sixth determination module, configured to determine that a third corrected solar direct irradiance value is the product of the second ground solar direct irradiance value and the wind speed correction coefficient if the difference between the second moment and the third moment is greater than a preset duration and the wind speed correction coefficient is greater than 0; the third moment is the start moment when the solar collector switches from a normal working state to a protection state, and the third moment is earlier than the second moment; A seventh determination module, configured to determine that the third corrected solar direct irradiance value is 0 if the difference between the second moment and the third moment is less than or equal to the preset duration, or the wind speed correction coefficient is 0; An eighth determination module, configured to determine a corrected solar direct irradiance value at the second moment based on the first corrected solar direct irradiance value, the second corrected solar direct irradiance value, and the third corrected solar direct irradiance value.

7. The direct solar irradiance value calculation device for the to-be-selected site according to claim 6, characterized in that The eighth determination module includes: A determination unit, configured to determine that the corrected solar direct irradiance value at the second moment is the minimum value among the first corrected solar direct irradiance value, the second corrected solar direct irradiance value, and the third corrected solar direct irradiance value.

8. A computer program product, characterized in that, Including computer-readable instructions, when the computer-readable instructions run on an electronic device, enabling the electronic device to implement the method for calculating the solar direct irradiance value of a candidate site as described in any one of claims 1 to 5.

9. An electronic device, characterized in that, Including at least one processor and a memory connected to the processor, wherein: The memory is used to store a computer program; The processor is configured to execute the computer program so that the electronic device can implement the method for calculating the solar direct irradiance value of a candidate site as described in any one of claims 1 to 5.

10. A computer storage medium, characterized in that, The storage medium carries one or more computer programs, and when the one or more computer programs are executed by an electronic device, enabling the electronic device to implement the method for calculating the solar direct irradiance value of a candidate site as described in any one of claims 1 to 5.

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