Tower type photo-thermal system aiming method and device

Abstract

The invention relates to the technical field of energy storage and new energy power generation, and discloses a tower-type photo-thermal system aiming method and device.The method comprises the steps that a relative coordinate system of the position of a heat absorber, the position of a heliostat and the position of the sun is established; calculating an independent light spot of reflection light corresponding to each heliostat based on the position of the heat absorber, and marking the light spot of which the drop point is the heat absorber as an incident light spot; overlapping all the incident light spots to obtain an initial combined light spot; the initial combined spot is adjusted based on a heat absorber acceptable spot upper limit. The invention provides a light spot simulation, aiming strategy determination and combined light spot detection and correction method and an aiming point determination method of a photo-thermal power station, realizes a heliostat light spot offset and aiming center correction method aiming at a concentrating photovoltaic part, improves the energy utilization rate, and improves the energy utilization rate. And a hardware arrangement strategy provided by the invention can effectively ensure the safety of the heat absorber.

Description

Technical Field

[0001] This invention relates to the fields of energy storage and new energy power generation technology, and in particular to a targeting method and device for a tower-type solar thermal system. Background Technology

[0002] In terms of energy harvesting, the solar-thermal conversion process in a tower-type concentrated solar power (CSP) plant requires a large number of heliostats to concentrate solar energy onto a central receiver. However, due to limitations in heliostat accuracy, receiver size, and temperature tolerance, a significant amount of energy cannot be directly absorbed by the receiver and converted into heat. Instead, it requires protection through special shielding, resulting in waste. Furthermore, under cloudy conditions or when solar irradiance is significantly higher than the design value, some heliostats will focus energy at waiting points outside the receiver, also causing energy loss. Moreover, in terms of energy utilization, tower-type CSP plants require molten salt as the heat transfer medium. Pumping molten salt into the receiver consumes a considerable amount of plant power.

[0003] In summary, conventional solar thermal power (CSP) systems do not consider the resource utilization of receiver overflow during tower-type CSP, resulting in energy waste and potential safety risks due to the overflow potentially causing concrete overheating. For components other than the receiver, only safety is considered, neglecting economic efficiency and technological adaptability. Under cloudy operating conditions, partial defocusing occurs, leading to significant waste in areas with complex resource conditions. Optimization of aiming strategies and overflow control for large-scale mirror fields is necessary. CSP projects have high power consumption, significantly impacting overall efficiency. Current CSP and photovoltaic (PV) coupling projects do not employ tight coupling, and land requirements for PV systems integrated into CSP plants are difficult to meet. Summary of the Invention

[0004] This invention aims to at least partially solve one of the technical problems in the aforementioned technologies. To this end, this invention proposes an aiming method for a tower-type photothermal system, comprising:

[0005] Establish a relative coordinate system for the positions of the receiver, heliostat, and the sun;

[0006] The independent light spot corresponding to the reflected light of each heliostat is calculated based on the position of the receiver, and the light spot that falls on the receiver is recorded as the incident light spot;

[0007] The initial combined light spot is obtained by superimposing all the incident light spots;

[0008] The initial combined light spot is adjusted based on the upper limit of the acceptable light spot size of the absorber.

[0009] Preferably, when calculating the independent spot of reflected light corresponding to each heliostat based on the position of the absorber, the independent spot calculation method used includes: Monte Carlo ray tracing method or HFCAL model method.

[0010] Preferably, the independent light spot corresponding to the reflected light of each heliostat is calculated according to the Monte Carlo ray tracing method, including:

[0011] According to the Monte Carlo method, light spots are randomly scattered within the projection range of the main incident light;

[0012] Calculate the intersection of the incident ray and the heliostat for each random light spot in turn;

[0013] When the incident ray corresponding to a random light spot intersects with any heliostat, the incident ray corresponding to the random light spot is recorded as the effective incident ray;

[0014] Calculate the reflected ray and spot position corresponding to the effective incident ray;

[0015] Record the position of the light spot when it is determined that the reflected ray corresponding to the effective incident ray is not blocked by other heliostats and the light spot corresponding to the reflected ray is located inside the receiver.

[0016] Preferably, the formula used to calculate the independent light spot corresponding to the reflected light of each heliostat according to the HFCAL model method includes:

[0017]

[0018] P A =I D ·A·cosθ·f at ·ρ

[0019]

[0020] Where, q HF (x r ,y r ) represents any point (x) on the heat-absorbing surface. r ,y r The energy flux density of P; A σ represents the total energy of the light rays reflected by heliostat A; HF Indicates effective deviation; x Nr ,y Nr Indicates the coordinates of aiming point N on the heat-absorbing surface; I D Direct normal radiation (DNI) is indicated; A represents the surface area of ​​heliostat A; θ represents the angle of solar incidence; f at ρ represents atmospheric attenuation loss; L represents the heliostat reflectivity; σ represents the distance from the heliostat to the aiming point on the absorber surface; sun Indicates the deviation in the shape of the sun; σ bq Indicates the beam quality related to mirror profile error; σ ast Indicates astigmatism; σ t Indicates tracking control deviation; θr This indicates the angle between the reflected ray and the normal to the heat-absorbing surface.

[0021] Preferably, for a heliostat composed of several lenses, the formula used when calculating the independent spot of reflected light corresponding to each heliostat according to the HFCAL model method includes:

[0022]

[0023] Among them, P Mi σ represents the total energy of the light rays reflected by the i-th module on the heliostat; HFMi x represents the effective deviation of the i-th module on the heliostat; Pir ,y Pir This represents the coordinates of the intersection point of the reflected ray from the center point of the i-th module on the heliostat and the heat-absorbing surface.

[0024] Preferably, after calculating the independent light spot corresponding to the reflected light of each heliostat according to the Monte Carlo ray tracing method, the method further includes: performing statistical analysis on the horizontal and vertical axes of all the calculated independent light spots, and recording the 3σ point of the normal distribution of the light rays corresponding to all independent light spots as the size of the light spot.

[0025] Preferably, after calculating the independent light spot corresponding to the reflected light of each heliostat according to the Monte Carlo ray tracing method, the method further includes: when the upper limit of the light spot received by the absorber is greater than the limit value of the light spot received by the absorber, recording the 2σ point of the normal distribution of the light rays corresponding to all independent light spots as the size of the light spot.

[0026] Preferably, the initial combined light spot is obtained by superimposing all incident light spots, including:

[0027] Sort the light spots corresponding to each heliostat from largest to smallest;

[0028] Adjust the aiming center of each heliostat to the center elevation of the receiver;

[0029] Using the center elevation of the receiver as the origin of the coordinate axis, the vertical axis of the aiming center of the odd-numbered heliostat is adjusted to LR, and the vertical axis of the aiming center of the even-numbered heliostat is adjusted to RL; where R represents the longitudinal radius of the light spot; and L represents the elevation of the heat-absorbing surface of the receiver.

[0030] The adjusted light spot is used as the initial combined light spot.

[0031] Preferably, adjusting the initial combined light spot based on the upper limit of the absorber's acceptable light spot further includes: when it is determined that the initial combined light spot exceeds the upper limit of the absorber's acceptable light spot, adjusting the aiming center of the light spot closest to the energy density over-limit region longitudinally to the lowest energy flux density within the range of [RL,LR].

[0032] Preferably, adjusting the initial combined light spot based on the upper limit of the absorber's acceptable light spot further includes: when it is determined that the initial combined light spot exceeds the upper limit of the absorber's acceptable light spot, adjusting the aiming center of the light spot closest to the energy density over-limit region longitudinally to 1 / 4, 1 / 2, or 3 / 4 of [RL,LR].

[0033] Preferably, adjusting the initial combined light spot based on the upper limit of the absorber's acceptable light spot further includes: when the number of adjustments to the initial combined light spot exceeds a preset value and the adjusted initial combined light spot still exceeds the upper limit of the absorber's acceptable light spot, sequentially removing the light spots at the energy density exceeding the limit until the adjusted initial combined light spot does not exceed the upper limit of the absorber's acceptable light spot.

[0034] The present invention also provides a tower-type photothermal system, wherein the tower-type photothermal system concentrates light based at least on the above-described method.

[0035] Preferably, the system includes: a concentrating photovoltaic module, a heat absorber, and a conventional photovoltaic module; wherein,

[0036] The concentrated photovoltaic module is connected to the power system along with the ordinary photovoltaic module.

[0037] Two concentrating photovoltaic modules are respectively arranged in the upper and lower parts of the heat absorber; the concentrating photovoltaic modules and the heat absorber share a high-pressure air cooling system;

[0038] The conventional photovoltaic module is arranged between the concrete and the concentrated photovoltaic module.

[0039] The present invention also provides an electronic device, including a memory and a processor, wherein the memory stores a computer program or instructions; when the computer program or instructions are executed by the processor, they are used to implement at least the method described in the claims.

[0040] The present invention also provides a computer-readable storage medium storing a computer program or instructions; when the computer program or instructions are executed by a processor, they are used to implement at least the above-described method.

[0041] Compared with the prior art, the beneficial effects of the present invention are:

[0042] 1. This invention improves energy utilization efficiency and prevents concrete overheating by arranging concentrated photovoltaics above and below the receiver in a tower-type solar thermal power generation project, and arranging ordinary photovoltaics on the receiver tower. Through simulation, the relevant photovoltaic arrangement range and size are optimized.

[0043] 2. This invention proposes a method for simulating the light spot in a solar thermal power plant, determining the aiming strategy, and combining the detection and correction of the light spot, as well as a method for determining the aiming point. It realizes a method for correcting the heliostat light spot offset and aiming center for the concentrating photovoltaic part, thereby improving the energy utilization rate.

[0044] 3. The photovoltaic system proposed in this invention can be used for plant power supply and molten salt heating, and can provide emergency power supply when other power sources fail.

[0045] Other features and advantages of the invention will be set forth in the following description, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the written description and the accompanying drawings.

[0046] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0047] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0048] Figure 1 This is a schematic diagram of the aiming method for a tower-type photothermal system given in an embodiment;

[0049] Figure 2 The photovoltaic-thermal combined system structure diagram is shown in the embodiment.

[0050] Figure 3 The following is an operational flowchart of the tower-type solar thermal system aiming system provided as an example;

[0051] Figure 4 The diagram shows an electronic device as illustrated in the embodiment.

[0052] Figure 5 This is a schematic diagram of a computer-readable storage medium provided for an embodiment. Detailed Implementation

[0053] The present invention will be described below with reference to the accompanying drawings. The preferred embodiments described herein are for illustration and explanation only and are not intended to limit the present invention.

[0054] Figure 1 The aiming method for a tower-type photothermal system provided by this invention includes:

[0055] S101. Establish a relative coordinate system for the positions of the receiver, heliostat, and the sun;

[0056] S102. Calculate the independent light spot corresponding to the reflected light of each heliostat based on the position of the receiver, and record the light spot with the receiver as the incident light spot;

[0057] S103. Superimpose all incident light spots to obtain an initial combined light spot;

[0058] S104. Adjust the initial combined light spot based on the upper limit of the acceptable light spot of the absorber.

[0059] Figure 2 The diagram shows the structure of the photovoltaic-thermal combined system provided in this invention. The first section of the system mainly uses concentrating photovoltaic modules, arranged above and below the absorber. The arrangement size is determined by the size of the absorber's light-receiving surface, using 1 / 3 to 1 / 2 of the absorber's light-receiving surface (adjusted according to the module size) as a standard configuration. This part is mainly used to absorb the light spot energy from the heat collection mirror field. The second section mainly uses ordinary photovoltaic modules, arranged on the upper concrete surface, with an arrangement range of 10 to 15 meters below the concrete elevation of the heat absorption tower (adjusted according to the module size). This part can collect some of the overflow energy and natural radiation, and also protect the concrete safety. Both sections of photovoltaic modules are fed into the plant's power system after being collected. The relevant electrical equipment can be arranged in the electrical equipment layer inside the heat absorption tower. The concentrating photovoltaic module shares the high-pressure air system of the absorber, which provides air cooling when the temperature of the concentrating photovoltaic module is too high.

[0060] According to some embodiments of the present invention, the process of building an independent light spot model includes: for different site coordinates and heliostat arrangements, calculating the independent light spot situation of each heliostat in the tower solar thermal power plant according to the solar trajectory and operation mode. The methods that can be used include Monte Carlo ray tracing method and HFCAL model method.

[0061] 1. Monte Carlo ray tracing method for calculating independent light spots

[0062] First, it is necessary to determine the projection area on the ground along the principal incident light, using the coordinates of the heliostat's vertex and center. Then, the projection range is determined. Next, the Monte Carlo method is used to randomly project light points, with the number of points being as large as possible to cover the projection area formed by all the mirror surfaces on the ground. A ray is formed by any random light point and the incident vector. The coordinates of the randomly projected light points on the ground can be expressed as follows:

[0063] X is =x min +(x max -x min rand(N,1)

[0064] Y is =y min +(y max -y minrand(N,1)

[0065] Where, x min ,x max These are the minimum and maximum x-coordinate values ​​of the projection of the heliostat vertex coordinates onto the ground along the principal incident light; y-coordinate values ​​are respectively. min ,y max These are the minimum and maximum y-coordinates of the heliostat vertex coordinates projected onto the ground along the principal incident light; N is the number of light spots; rand(N,1) represents the random generation of N random numbers between 0 and 1.

[0066] The intersection of the incident ray with each heliostat is determined sequentially by the projection coordinates of the four vertices of the randomly projected light spot on the ground along the ground. If the light spot is not within any heliostat, the next light spot is considered, and the ray corresponding to this light spot is considered an invalid incident ray; otherwise, the heliostat that the incident ray finally illuminates (here called the target heliostat) is determined, and the intersection point with the heliostat is calculated. Next, the occlusion determination stage begins. First, the reflected ray corresponding to the incident ray is calculated, and it is determined whether the reflected ray is occluded by other mirrors. If it is not occluded, the intersection point of the reflected ray with the absorber is calculated, and it is determined whether the intersection point is within the absorber. After all the rays have been processed, the shadow occlusion efficiency and overflow efficiency of the mirror field can be calculated. At the same time, the intersection points of the effective rays with the absorber can be obtained. Then, the absorber is meshed, and the mesh position of each intersection point is determined sequentially to obtain the ray quantity matrix corresponding to the absorber mesh. Finally, the weather conditions of the day are observed, and the ray quantity matrix is ​​converted into the corresponding energy matrix.

[0067] For any random light spot, the ray tracing algorithm process is as follows:

[0068] (1) Initialize each parameter, looping with the number of heliostats NumMir;

[0069] (2) Shadow determination stage: Determine whether the target point is inside the mirror; if it is, proceed to step (3); otherwise, proceed to (6). The determination method is described in the efficiency calculation section above.

[0070] (3) Calculate the coordinates of the intersection point between the incident ray corresponding to the spot and the heliostat;

[0071] (4) Determine whether it is within the range of the heliostat. If it is, turn (5); otherwise, turn (6).

[0072] (5) Record the position of the heliostat, which is called the target heliostat;

[0073] (6) Determine if the loop has ended; if so, go to (7), otherwise go to (2);

[0074] (7) Read the shadow judgment flag status of the light ray. If the light ray is blocked, proceed to (8) and enter the occlusion judgment stage. Otherwise, go to (3) and start judging the next light spot after the end.

[0075] (8) Calculate the coordinates (Xb, Yb, Zb) of the intersection point of the reflected ray corresponding to the incident ray with other heliostats (except the target heliostat M). Here, the intersection point with other heliostats (except the target heliostat M) is calculated.

[0076] (9) Determine whether the intersection point (Xb, Yb, Zb) is within the target surface heliostat; if so, turn (10), otherwise turn (12);

[0077] (10) Determine whether the coordinates of the intersection point are within the coordinate area of ​​the target heliostat. If they are, turn to (11); otherwise, turn to (12).

[0078] (11) This indicates that the light was blocked, and the state of the light changed accordingly;

[0079] (12) Determine if the loop has ended; if so, go to (13), otherwise go to (8);

[0080] (13) Read the occlusion determination status of the light ray. If occlusion occurs, turn to (14) and enter the overflow stage; otherwise, turn to (17).

[0081] (14) Calculate the coordinates (Xr, Zr) of the intersection point between the reflected ray and the absorber;

[0082] (15) Determine whether the intersection is inside the absorber. If it is, turn to (16); otherwise, turn to (17).

[0083] (16) Record the coordinates of the intersection point;

[0084] (17) End.

[0085] Through the above process, the tracing process of any random light spot can be realized. It can simultaneously realize shadow occlusion judgment, occlusion judgment and overflow judgment. The ray tracing method can effectively simulate and model the light spot on the surface of the heat absorber, providing a foundation for subsequent work.

[0086] 2. Calculation of independent light spots using the HFCAL model method

[0087] The distribution of heat flux density on the absorbing surface is calculated using the circular Gaussian flux density function. For any heliostat A, the heat flux density distribution of its reflected light on the absorbing surface at a certain moment can be expressed by the following formula:

[0088]

[0089]

[0090] Where, q HF (x r ,y r ) represents any point (x) on the heat-absorbing surface. r ,y r The energy flux density of P; A σ represents the total energy of the light rays reflected by heliostat A; HF Indicates effective deviation; x Nr ,y Nr Indicates the coordinates of aiming point N on the heat-absorbing surface;

[0091] P A =I D ·A·cosθ·f at ·ρ

[0092] Among them, I D Direct normal radiation (DNI) is indicated; A represents the surface area of ​​heliostat A; θ represents the angle of solar incidence; f at ρ represents atmospheric attenuation loss, which is related to the distance between the heliostat and the aiming point on the absorbing surface; ρ represents the heliostat's reflectivity.

[0093]

[0094] L represents the distance from the heliostat to the aiming point on the absorbing surface; σ sun Indicates the deviation in the shape of the sun; σ bq Indicates the beam quality related to mirror profile error; σ ast Indicates astigmatism; σ t Indicates tracking control deviation; θ r This indicates the angle between the reflected ray and the normal to the heat-absorbing surface.

[0095] According to some embodiments of the present invention, some heliostats are composed of several lenses, and they need to be modularized during the calculation process. For a heliostat composed of n lenses, it is divided into n modules. First, the center point M of each module is determined according to the geometry of the entire heliostat. i The coordinates of (i = 1, ..., n) in the mirror field coordinate system. Then, the heat flux density distribution of sunlight reflected by the i-th module on the absorbing surface is calculated:

[0096]

[0097] Among them, P Mi σ represents the total energy of the light rays reflected by the i-th module on the heliostat; HFMi x represents the effective deviation of the i-th module on the heliostat; Pir ,y Pir P represents the coordinates of the intersection point of the reflected ray from the center point of the i-th module on the heliostat and the heat-absorbing surface.Mi and σ HFMi The calculation method is the same as above. By superimposing the heat flux density distributions of each module on the absorbing surface of the heliostat, the heat flux density distribution of sunlight reflected by the entire heliostat on the absorbing surface can be obtained:

[0098]

[0099] Based on the above technical solutions, this invention presents a basic aiming strategy for a heliostat and a simulation of combined light spots, the specific process of which includes:

[0100] 1. Coordinate system establishment and coordinate processing, the specific process includes: establishing a relative coordinate system for the position of the receiver, heliostat, and sun, unfolding the coordinates of the receiver surface to form a two-dimensional xy coordinate system that is convenient for aiming point optimization.

[0101] 2. Using the independent spot calculation method described above, calculate the single-mirror spot of the full-field heliostat based on the center elevation position of the corresponding receiver.

[0102] 3. Heliostat Spot Edge Recognition: For the single-mirror spot calculated using the Monte Carlo ray tracing method described above, statistical analysis is performed on the vertical and horizontal axes, and the spot size is recorded at the 3σ point corresponding to the normal ray distribution. For single-mirror spots calculated using the HFCAL model described above, the calculation results can be directly used and recorded as the spot size.

[0103] 4. Divide the overall heliostat field into heliostat zones based on the number of receiver panels: For receivers with n panels, each (360 degrees / n) degree in the heliostat field corresponds to a receiver and is a heliostat zone for overall optimization of aiming strategy.

[0104] 5. Optimize the heliostats in each partition. When the number of heliostats in a partition is k, sort them from largest to smallest according to the size of the light spot on the receiver for each heliostat k. Arrange the light spots from largest to smallest within the same region.

[0105] 6. Set the initial coordinate position of each heliostat in the receiver to the center elevation of the receiver at the corresponding angle. Then, adjust the basic aiming strategy according to the order determined in step 5. This step only adjusts the aiming center on the vertical axis, while keeping the horizontal axis consistent with the center installation position of the heliostat: take the center elevation of the receiver as the 0 coordinate of the vertical axis. When the elevation of the heated surface of the receiver is L, for the odd-numbered heliostat, if its longitudinal radius of the spot is R, adjust its aiming center vertical axis to LR; for the even-numbered heliostat, if its longitudinal radius of the spot is R, adjust its aiming center vertical axis to RL.

[0106] 7. Based on the light spots obtained from all the heliostats in steps 5 and 6 above, superimpose them to obtain an initial combined light spot.

[0107] 8. Detect and count the initial combined light spots to determine if there are any situations that exceed the upper limit of the combined light spots that the solar collector can accept. If so, make fine adjustments to the light spots.

[0108] 9. Adjust the aiming center of the spot closest to the upper limit of the acceptable combined spot area of ​​the solar collector. The adjustment method is to adjust it longitudinally to the point of lowest energy flux density within the range of [RL,LR]. After adjustment, recalculate the combined spot.

[0109] 10. Repeat steps 7, 8, and 9 until no combined light spot exceeds the maximum energy flux density of the receiver. If the requirement is still not met after repeating a certain number of times, remove the light spot with the excessive energy density until the overall requirement is met.

[0110] This application also provides an optimization method for the aiming strategy of a concentrated photovoltaic system, including: determining the operating status of the concentrated solar collector system through the aforementioned mirror field simulation and infrared camera imaging. When the receiver's received power is less than its maximum receiveable power, and the energy flux density of the combined light spot on the receiver surface does not exceed the upper limit, the current aiming strategy is maintained. When the receiver's received power is greater than its maximum receiveable power, the calculation of the light spot size using the Monte Carlo ray tracing method in the above aiming strategy is modified from "taking the 3σ point of the corresponding ray normal distribution as the light spot size" to "taking the 2σ point of the corresponding ray normal distribution as the light spot size," and the aforementioned "adjusting along the longitudinal direction to the lowest energy flux density within the range [RL,LR]" is corrected to "adjusting along the longitudinal direction to 1 / 4, 1 / 2, and 3 / 4 of [RL,LR]." Finally, the energy flux density of the concentrating photovoltaic (PV) system is tested for the receiver, the concentrating PV area, and the ordinary PV area. If the energy flux density of both the concentrating PV system and the receiver exceeds the limit, and the problem cannot be resolved after repeated cycles of the above process, the light spot at the point of exceeding the limit is removed until the overall requirements are met.

[0111] According to some embodiments of the present invention, the main signals of the concentrated photovoltaic (CPV) section can be connected to the entire field DCS through the electrical layer inside the receiver tower. In the event of overheating or other situations, safety is ensured primarily by removing the relevant heliostats. The electricity generated by the CPV is mainly used for the plant's auxiliary power supply. In the event of an emergency power outage in the plant area, the electricity generated by the CPV is prioritized for receiver desalination and other related safety protection measures.

[0112] According to some embodiments of the present invention, by collecting the simulation data obtained above, the concentrated photovoltaic (PV) size determined in the first step can be optimized by increasing the PV size by 5% and 10% and decreasing it by 5% and 10%, respectively. The levelized cost of electricity (LCOE) over the entire lifecycle under the corresponding size is calculated, and the optimal solution is selected as the final solution. This portion of electricity is treated as another subsystem of the entire site, excluding the heat collection, heat storage, and power generation systems, and a full-process simulation is performed.

[0113] According to some embodiments of the present invention, since the power of the molten salt cold pump is positively correlated with the light intensity, the plant power should preferably be matched with the molten salt cold pump. This part of the power can be connected to the main plant through the electrical layer at the top of the heat absorber and the internal cable tray. The excess plant power is used for electric heating to improve the molten salt temperature at the heat absorber outlet and to realize energy storage and transfer through the molten salt storage tank.

[0114] The operation flow of the tower-type photothermal system aiming system provided in this invention is as follows: Figure 3 As shown, the process includes: first, initial system hardware setup; second, single-spot modeling; third, determining and running a basic aiming strategy based on the single-spot modeling results; fourth, determining whether there is surplus energy in the spot during operation; if so, fine-tuning the aiming point to the photovoltaic section; otherwise, energy harvesting according to the current basic aiming strategy. The photovoltaic system is connected to and shares power with the plant's auxiliary power system; specific configuration strategies are detailed above. Finally, system simulation is used to optimize the solution.

[0115] like Figure 4 As shown, the present invention provides an electronic device 1000, which includes a memory 1002 and a processor 1001. The memory 1002 stores computer programs or instructions, and when the computer programs or instructions are executed by the processor 1001, they are used to at least implement the aforementioned tower-type photothermal system aiming method. In addition, as... Figure 5 As shown, the present invention provides a computer-readable storage medium 1100, which stores a computer program or instructions. When the computer program or instructions are executed by a processor, they are used to implement at least the above-described tower photothermal system aiming method.

[0116] Obviously, those skilled in the art can make various modifications and variations to this invention without departing from its spirit and scope. Therefore, if these modifications and variations fall within the scope of the claims of this invention and their equivalents, this invention also intends to include these modifications and variations.

Claims

1. A method for aiming a tower-type photothermal system, characterized in that, include: Establish a relative coordinate system for the positions of the receiver, heliostat, and the sun; The independent light spot corresponding to the reflected light of each heliostat is calculated based on the position of the receiver, and the light spot that falls on the receiver is recorded as the incident light spot; The initial combined light spot is obtained by superimposing all the incident light spots; The initial combined light spot is adjusted based on the upper limit of the acceptable light spot size of the absorber.

2. The method as described in claim 1, characterized in that, When calculating the independent spot of reflected light corresponding to each heliostat based on the location of the receiver, the independent spot calculation methods used include: Monte Carlo ray tracing method or HFCAL model method.

3. The method as described in claim 2, characterized in that, The independent light spot corresponding to the reflected light from each heliostat was calculated using the Monte Carlo ray tracing method, including: According to the Monte Carlo method, light spots are randomly scattered within the projection range of the main incident light; Calculate the intersection of the incident ray and the heliostat for each random light spot in turn; When the incident ray corresponding to a random light spot intersects with any heliostat, the incident ray corresponding to the random light spot is recorded as the effective incident ray; Calculate the reflected ray and spot position corresponding to the effective incident ray; Record the position of the light spot when it is determined that the reflected ray corresponding to the effective incident ray is not blocked by other heliostats and the light spot corresponding to the reflected ray is located inside the receiver.

4. The method as described in claim 2, characterized in that, The independent light spot corresponding to the reflected light of each heliostat is calculated using the HFCAL model method, and the formulas used include: P A =I D ·A·cosθ·f at ·r Where, q HF (x r ,y r ) represents any point (x) on the heat-absorbing surface. r ,y r The energy flux density of P; A σ represents the total energy of the light rays reflected by heliostat A; HF Indicates effective deviation; x Nr ,y Nr Indicates the coordinates of aiming point N on the heat-absorbing surface; I D Direct normal radiation (DNI) is indicated; A represents the surface area of ​​heliostat A; θ represents the angle of solar incidence; f at ρ represents atmospheric attenuation loss; L represents the heliostat reflectivity; σ represents the distance from the heliostat to the aiming point on the absorber surface; sun Indicates the deviation in the shape of the sun; σ bq Indicates the beam quality related to mirror profile error; σ ast Indicates astigmatism; σ t Indicates tracking control deviation; θ r This indicates the angle between the reflected ray and the normal to the heat-absorbing surface.

5. The method as described in claim 2, characterized in that, For a heliostat composed of several lenses, the formulas used to calculate the independent spot of reflected light for each heliostat according to the HFCAL model method include: Among them, P Mi σ represents the total energy of the light rays reflected by the i-th module on the heliostat; HFMi x represents the effective deviation of the i-th module on the heliostat; Pir ,y Pir This represents the coordinates of the intersection point of the reflected ray from the center point of the i-th module on the heliostat and the heat-absorbing surface.

6. The method as described in claim 3, characterized in that, After calculating the independent light spot corresponding to the reflected light of each heliostat according to the Monte Carlo ray tracing method, the method also includes: performing statistics on the horizontal and vertical axes of all the calculated independent light spots, and recording the 3σ point of the normal distribution of the light rays corresponding to all independent light spots as the size of the light spot.

7. The method as described in claim 3, characterized in that, After calculating the independent light spot corresponding to the reflected light of each heliostat according to the Monte Carlo ray tracing method, the method further includes: when the upper limit of the light spot received by the absorber is greater than the limit value of the light spot received by the absorber, the 2σ point of the normal distribution of the light rays corresponding to all independent light spots is recorded as the size of the light spot.

8. The method as described in claim 7, characterized in that, The initial combined light spot is obtained by superimposing all incident light spots, including: Sort the light spots corresponding to each heliostat from largest to smallest; Adjust the aiming center of each heliostat to the center elevation of the receiver; Using the center elevation of the receiver as the origin of the coordinate axis, the vertical axis of the aiming center of the odd-numbered heliostat is adjusted to LR, and the vertical axis of the aiming center of the even-numbered heliostat is adjusted to RL; where R represents the longitudinal radius of the light spot; and L represents the elevation of the heat-absorbing surface of the receiver. The adjusted light spot is used as the initial combined light spot.

9. The method as described in claim 8, characterized in that, Adjusting the initial combined light spot based on the upper limit of the absorber's acceptable light spot further includes: when it is determined that the initial combined light spot exceeds the upper limit of the absorber's acceptable light spot, adjusting the aiming center of the light spot closest to the energy density over-limit region longitudinally to the lowest energy flux density within the range of [RL,LR].

10. The method as described in claim 8, characterized in that, Adjusting the initial combined light spot based on the upper limit of the absorber's acceptable light spot further includes: when it is determined that the initial combined light spot exceeds the upper limit of the absorber's acceptable light spot, adjusting the aiming center of the light spot closest to the energy density over-limit region longitudinally to 1 / 4, 1 / 2, or 3 / 4 of [RL,LR].

11. The method according to any one of claims 7-10, characterized in that, Adjusting the initial combined light spot based on the upper limit of the absorber's acceptable light spot further includes: when the number of adjustments to the initial combined light spot exceeds a preset value and the adjusted initial combined light spot still exceeds the upper limit of the absorber's acceptable light spot, sequentially removing the light spot at the point where the energy density exceeds the limit, until the adjusted initial combined light spot does not exceed the upper limit of the absorber's acceptable light spot.

12. A tower-type solar thermal system, characterized in that, The tower-type solar thermal system concentrates light at least based on the method described in any one of claims 1-11.

13. The system as described in claim 12, characterized in that, include: Concentrated photovoltaic modules, heat absorbers, and conventional photovoltaic modules; among which, The concentrated photovoltaic module is connected to the power supply system along with the ordinary photovoltaic module. Two concentrating photovoltaic modules are respectively arranged in the upper and lower parts of the heat absorber; the concentrating photovoltaic modules and the heat absorber share a high-pressure air cooling system; The conventional photovoltaic module is arranged between the concrete and the concentrated photovoltaic module.

14. An electronic device, characterized in that, It includes a memory and a processor, wherein the memory stores a computer program or instructions; when the computer program or instructions are executed by the processor, they are used to implement at least the method according to any one of claims 1-11.

15. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program or instructions; when the computer program or instructions are executed by a processor, they are used to implement at least the method of any one of claims 1-11.

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