17.35% average exergy efficiency
No. . | Author/ref . | Year . | Type of thermal collector . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Vaziri Rad . [ ] | 2021 | Serpentine-shape sheet and tube with PCM | Experiment | Monocrystalline | 14.86–15.71% | 61.6% | 20°C temperature reduction of PV module; 17.35% average exergy efficiency |
2 | UI Abdin . [ ] | 2021 | Parallel-shape sheet and tube | Simulation | / | 10.28% | 35–70% | The PVT module incorporates a Tedlar layer and parallel tubes; the mathematical model has been proposed and parameter analysis has been conducted |
3 | Salameh . [ ] | 2021 | Parallel-shape sheet and tube (rectangle tube) | Simulation | / | 10.0–12.6% | 60.3–65.8% | A novel three-dimensional numerical model is proposed; the parameter analysis is investigated through the CFD model |
4 | Li . [ ] | 2021 | Parallel-shape sheet and tube | Experiment and simulation | CdfTe | 9.86% | 17.7% | CdTe-type PV module is applied to form the thin-film PVT module; a new quasi-steady-state mathematical model is established |
5 | Kaewchoothong . [ ] | 2021 | Parallel-shape flow channel with alternative ribs | Experiment and simulation | Polycrystalline | 14.8% | 53.0% | The PVT module is installed with a rib tabulator in the fluid channel; the influence of design parameters on the system performance has been studied |
6 | Das . [ ] | 2021 | Spiral-shape sheet and tube with form-stable composite material | Experiment | / | 13% | 66.6% | A novel form-stable composite material is used to control the temperature uniformity of the PVT module; a spiral-shape rectangular tube is used |
7 | Colombini . [ ] | 2021 | Roll-bond thermal collector | Simulation | Polycrystalline | 13.4–14.0% | 42.1–45.7% | A roll-bond panel with various shapes are studied; the temperature uniformity has been considered during the fluid channel design |
8 | Hissouf . [ ] | 2020 | Sheet and tube | Simulation | Polycrystalline | 12.0–15.5% | 30.0–53.0% | Circular tube, half tube and square tube have been studied; boundary conditions have been investigated |
9 | Yu . [ ] | 2019 | Roll-bond thermal collector | Experiment | Polycrystalline | 11.8% | 25.2% | A harp-channel absorber and grid-channel absorber are comparatively investigated; the temperature uniformity has been studied |
10 | Pang . [ ] | 2019 | Roll-bond thermal collector | Experiment and simulation | Polycrystalline | 13.67% | 40.56% | The exergy efficiency is 15.56%; the temperature uniformity and hydraulic performance have been investigated |
Water (including antifreeze), nanofluids and heat transfer oil are four working mediums of the liquid-based PVT module. These four cooling fluids have different characteristics and applications, thus, the structures of the liquid-based PVT would be diversified.
The water-based PVT module uses water as the working medium, and water performs better in the heat transfer characteristic than air due to its large heat capacity [ 14 ]. However, the sealing requirements would be improved, which lead to an increasing system cost [ 15 ]. In addition, the usage of pure water would cause the freezing pipe bursting problem in cold climate regions [ 16 ]. In this regard, antifreeze (a solution of water and ethylene glycol) could be adopted to avoid the freezing problem [ 17 – 19 ]. Numerous researchers have proposed various structures of the water-based PVT module and their corresponding mathematical models to improve the thermal and electrical efficiencies [ 20 – 22 ].
The simplest structure of the water-based thermal collector is the sheet-and-tube type, the tube (copper tube is commonly used) is welded in the absorbing plate. Then, the sheet-and-tube collector is attached to the backside of the PV module to form the water-based PVT module. Bakker et al . [ 23 ] applied this kind of cooling component to improve the heat transfer between the solar cells and water. As shown in Fig. 3 , they installed 25 m 2 of water-based PVT module on the top of the roof for comparative experiments with the conventional PV module and solar collector. The experimental results indicated that this kind of system could meet the electricity and hot water demand of a single-family in Dutch. In terms of this kind of water-based PVT module, Vokas et al . [ 24 ] proposed a theoretical model to predict thermal and electrical performance. For a building with an installed area of 30 m 2 , the solar fraction of the PVT module could reach 47.79%. However, the thermal efficiency of the PVT module is lower than the conventional solar collector by 9%. Moreover, they investigated the payback period of the system is around 4.6 years.
(a) Linear-type fluid channel. (b) Spiral-type fluid channel. [ 46 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Photograph of the PVT module, which uses copper oxide as nanoparticles. [ 48 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The water-based PVT modules are commonly set in serial, different arrangements would influence the hydraulic, thermal and electrical performance of the system. Therefore, Dubey et al . [ 25 ] have done research about the arrangement style and fill factor of the PVT module. The structure of the PVT module and four different forms of PVT module arrangement are shown in Fig. 4 . The results show that the b-form arrangement is more suitable for the family that takes heat as the first demand while the levelized cost of heat is the lowest among the four arrangement forms. In the country, the e-form arrangement is more preferable for the family, which takes electricity as the first demand. This kind of system is applicable for the suburban and rural areas where both heat and electricity are needed. Based on the above system, Mishra et al . [ 26 ] analysed the energy conversion efficiency and exergy efficiency of the system under the constant water tank temperature mode. The simulation results showed that the annual average exergy efficiency of the system using the e-form is 39.16% higher than that of the traditional flat collector system.
Chen et al . [ 27 ] assembled a lab-scale sheet-and-tube PVT module, and its structure is shown in Fig. 5 . During the test of the components, it is found that higher irradiation conditions and greater mass flow of circulating water could improve the power generation efficiency. However, the heat collection efficiency of 620 W/m 2 solar radiation intensity is 4–8% higher than that of 1000 W/m 2 solar radiation intensity under different mass flow rates of circulating water. The highest power generation efficiency of the module is 15.82%, when the irradiation intensity is 1000 W/m 2 , the corresponding heat collection efficiency is 59.41%.
The mini-channel thermal collector is another kind of structure for the PVT module, and the mini-channel could enlarge the heat transfer area remarkably and thereby increase the thermal efficiency of the PVT module. Zhou et al . [ 28 ] evaluated the comprehensive performance of the mini-channel PVT module (as shown in Fig. 6 ) in summer mode. The experimental and simulated electrical efficiencies are 11.5% and 12.6%, respectively, while the thermal efficiencies are 46.8% and 48%, respectively. The outlet water temperature of the experiments could reach 59.3°C.
The demerit of the sheet-and-tube structure of the water-based PVT module is that the heat transfer area is limited due to the welding process. The low thermal conductive coefficient would have an adverse effect on the thermal performance of the water-based PVT module. Therefore, the heat transfer area between the working fluid and the absorbing plate should be extended. In this regard, the roll-bond thermal collector has been used in the PVT module for a higher heat transfer coefficient.
From this aspect, Aste et al . [ 29 ] proposed a roll-bond panel-based PVT module to improve the thermal efficiency of the water-based PVT module. As shown in Fig. 7 , the area of the PVT module is 1.62 m 2 , while the pump power is 230 W. The roll-bond panel has larger flow resistance than the sheet-and-tube PVT module. The experimental results indicated that the electrical efficiency of the PVT module is around 12.8–13.5% while the thermal efficiency is around 20.8–32.9%. The temperature uniformity of the water-based PVT module is not well, and in this case, the maximum temperature difference reached 30°C.
The operation of a traditional water-based PVT system needs a water pump to circulate the working fluid. The pump power is determined by the flow resistance of the fluid channel in the whole system, and it would be a significant power consumption of the PVT system. Thus, some researchers have proposed the PVT system without a water pump, the system has a natural circulation of water driven by gravity and density difference. As shown in Fig. 8 , He et al . [ 30 ] comparatively conducted experiments to evaluate the performance of conventional flat plate solar collectors, PV modules and the PVT module. The experimental results showed that the thermal efficiency of the PVT module is slightly lower than that of a conventional flat plate solar collector, and the total efficiency is much higher than that of a flat plate collector and single PV module (the type of single PV module is the same as the PVT module). The natural circulation PVT water collector has no moving parts and no power consumption. Its thermal efficiency fluctuates between 38% and 43.51% and its electrical efficiency fluctuates between 9.01% and 12.51%.
The summary of the water-based PVT systems has shown in Table 1 .
The nanofluids have an outstanding heat transfer coefficient compared with water, which would improve the thermal efficiency of the PVT module significantly. The nanoparticles below 100 nm are added to the base fluid to form the nanofluids. It was firstly proposed by Choi et al . [ 39 ] and the characteristics of nanofluids have been studied and developed in the past decades. It was found that the type of nanoparticles [ 40 ], the volume fraction of nanoparticles [ 41 ], the particle size [ 42 ], the type of base liquid [ 43 ] and other factors [ 44 ] would influence the performance of the nanofluids to varying degrees [ 45 ].
Karami et al . [ 46 ] used the boehmite nanofluids to cool the solar cells and they designed two different fluid channel patterns (as shown in Fig. 9 ) to enhance the thermal efficiency. The average temperature of linear and spiral type decreases by 39.70% and 53.76%, respectively, when the nano-fluid concentration is 0.1 wt%. For linear and helical channels, the efficiency of the nanofluidic cooled PV modules increased by 20.57% and 37.67%, respectively. Sardarabadi et al . [ 47 ] found that the total energy efficiency of 1 wt% nanoparticles in the nanofluid increased by 3.6%, and that of 3 wt% nanoparticles increased by 7.9%. The thermal efficiency of 1 wt% and 3 wt% nanofluids increased by 7.6% and 12.8%, respectively. The total exergy energy in the PVT module of pure water, silicon/water nanofluids (1 wt%) and silicon/water nanofluids (3 wt%) were increased by 19.36%, 22.61% and 24.31%, respectively.
(a) Schematic diagram of the system. (b) Cross-section view of the magnetic nanofluids-based PVT module. [ 49 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Photograph of the nanofluids-based PVT system. (b) Schematic diagram of the nanofluids-based PVT system. [ 50 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Michael et al . [ 48 ] directly embedded the absorber plate beneath the PV module to reduce the thermal conductive resistance between the solar cells and working fluid. The experimental rig is shown in Fig. 10 . They synthesized copper oxide nanoparticles and prepared copper oxide/water nanofluids with a volume concentration of 0.05%, and it could effectively reduce the temperature by 13.82%. The thermal efficiency is increased by 45% by using nanofluids as heat transfer fluid. The temperature of the PV module increases due to the high thermal conductivity of nanofluids. Thus, the output power and electrical efficiency of the PVT system decrease under high working temperatures.
Except for the traditional nanoparticles, Ghadiri et al . [ 49 ] proposed a magnetic nanoparticle (Fe 3 O 4 )-based nanofluid. The magnetic fluid could be magnetized by applying a magnetic field to the working fluid. The experimental setup has shown in Fig. 11 . The effect of magnetic nanofluids on the overall efficiency of the PVT system was studied by placing magnetic nanofluids under constant and variable magnetic fields. The overall efficiency of the PVT system could be increased by 50% and reach 45% when adding 3% ferric oxide compared with distilled water as the cooling liquid phase under the same conditions (50 Hz alternating frequency).
Rejeb et al . [ 50 ] numerically and experimentally investigated the thermoelectric properties of nanofluids-based PVT modules with sheet-and-tube structure collectors. The experimental rig and schematic diagrams have shown in Fig. 12 . They studied the combination of alumina and copper nanoparticles with water and glycol as the base solution. The effects of 0.1, 0.2 and 0.4 wt% concentration of nanoparticles on the performance of the PVT system were studied. It is found that the thermal and electrical properties of PVT modules are improved with the increase of the concentration of nanoparticles, and the performance of water-based nanofluids is better than that of ethylene glycol nanofluids.
Structure of the sheet-and-tube PVT module. [ 51 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Structure of the concentrating PVT module with directly cooling. [ 57 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Photograph of the concentrating PVT module with directly cooling. [ 58 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The simulation system of the heat transfer oil-based PVT module. (APPLICABLE SOCIETY COPYRIGHT OWNER)
Ag and Al 2 O 3 are other options to form the nanofluids, thus, Khanjari et al . [ 51 ] studied the performance of the Ag/water and Al 2 O3/water nanofluids. They investigated the effects of volume concentration of nanoparticles and inlet flow rate on efficiency and heat transfer enhancement. Figure 13 shows the structure of the sheet-and-tube PVT module. The results showed that the efficiency and heat transfer coefficient increase with the increase of the volume concentration of nanoparticles. Al 2 O 3 /water nanofluids and Ag/water nanofluids have the maximum enhancement of heat transfer coefficient of 12% and 43%, respectively. The heat transfer performance of Al 2 O 3 /water nanofluids and Ag/water nanofluids is 8–10% and 28–45% higher than that of pure water, respectively, when the volume fraction is 5%.
Surface morphology of synthesized MXene (Ti3C2). [ 60 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Table 2 summarizes the specific parameters of the nanofluids-based PVT system.
Summary of nanofluids-based PVT systems
No. . | Author/ref . | Year . | Type of nanoparticle . | Research method . | Type of PV module . | Volumefraction . | Nanoparticle size . | Electrical efficiency . | Thermal efficiency . |
---|---|---|---|---|---|---|---|---|---|
1 | Sangeetha . [ ] | 2021 | Al O ; TiO | Experiment | Monocrystalline | 0.3% | 35–55 nm | 10.5–17.5% | 24.5–57.5% |
2 | Khanjari . [ ] | 2016 | Al; Ag | Simulation | / | 0–10% | 50nm | 10.3–11.3% | 70–85% |
3 | Rejeb . [ ] | 2016 | Al O ; Cu | Simulation | Monocrystalline | 0.1/0.2/0.4% | / | 13.2–13.6% | 20–78% |
4 | Hassani . [ ] | 2016 | CNT; Ag | Simulation | / | 3% | 15/10 nm | 8.5–12% | 1.68–2.38% (thermal exergy efficiency) |
5 | Ghadiri . [ ] | 2015 | Fe O | Experiment | Monocrystalline | 1/3% | 45 nm | 6.64–7.28% | 65.96–74.96% |
6 | Michael . [ ] | 2015 | CuO | Experiment | / | 0.05% | 75 nm | 6.18–8.77% | 45.76% |
7 | Sardarabadi . [ ] | 2014 | Silica | Experiment | Monocrystalline | 1/3% | 11–14 nm | 7–11% | 30–55% |
8 | Xu . [ ] | 2014 | Al O | Simulation | / | 5% | 5–10 nm | 11% | 59% |
9 | Karami . [ ] | 2014 | Boehmite | Experiment | Polycrystalline | 0.01/0.1 /0.5% | 5–10 nm | / | / |
No. . | Author/ref . | Year . | Type of nanoparticle . | Research method . | Type of PV module . | Volumefraction . | Nanoparticle size . | Electrical efficiency . | Thermal efficiency . |
---|---|---|---|---|---|---|---|---|---|
1 | Sangeetha . [ ] | 2021 | Al O ; TiO | Experiment | Monocrystalline | 0.3% | 35–55 nm | 10.5–17.5% | 24.5–57.5% |
2 | Khanjari . [ ] | 2016 | Al; Ag | Simulation | / | 0–10% | 50nm | 10.3–11.3% | 70–85% |
3 | Rejeb . [ ] | 2016 | Al O ; Cu | Simulation | Monocrystalline | 0.1/0.2/0.4% | / | 13.2–13.6% | 20–78% |
4 | Hassani . [ ] | 2016 | CNT; Ag | Simulation | / | 3% | 15/10 nm | 8.5–12% | 1.68–2.38% (thermal exergy efficiency) |
5 | Ghadiri . [ ] | 2015 | Fe O | Experiment | Monocrystalline | 1/3% | 45 nm | 6.64–7.28% | 65.96–74.96% |
6 | Michael . [ ] | 2015 | CuO | Experiment | / | 0.05% | 75 nm | 6.18–8.77% | 45.76% |
7 | Sardarabadi . [ ] | 2014 | Silica | Experiment | Monocrystalline | 1/3% | 11–14 nm | 7–11% | 30–55% |
8 | Xu . [ ] | 2014 | Al O | Simulation | / | 5% | 5–10 nm | 11% | 59% |
9 | Karami . [ ] | 2014 | Boehmite | Experiment | Polycrystalline | 0.01/0.1 /0.5% | 5–10 nm | / | / |
The heat transfer oil is another kind of working medium of the liquid-based PVT module. It is not commonly used as the cooling fluid of the PVT module due to its poor hydraulic behavior [ 55 , 56 ]. Notwithstanding, the heat transfer oil has its own merits including a wide working temperature range and low electric conductivity. Thus, the heat transfer oil-based PVT module is more suitable for the concentrating PVT module.
For instance, Ji et al . [ 57 ] proposed a transmissive concentrator PVT module that uses silicone oil to cool the solar cells and further realize solar cogeneration. As shown in Fig. 14 , the concentrating system would increase the temperature of solar cells significantly, thus, the conventional heat transfer fluid is not suitable. The heat transfer oil (silicon oil which used in this study) could stay steady when it absorbs heat from the high-temperature solar cells (around 119°C). The maximum temperature of the thermal receiver could reach 180°C and this kind of system could utilize 86.1% of the solar irradiation. Moreover, Codd et al . [ 58 ] experimentally tested the performance of the concentrating PVT module with directly cooling silicon oil (as shown in Fig. 15 ), and the results indicated that the total efficiency could reach 85.1% ± 3%, and 138 W of electrical power at 304 suns.
Schematic diagram of the typical CPVT system based on the silicon oil/MXene fluid. [ 61 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Summary of heat transfer oil-based PVT systems
No. . | Author/ref . | Year . | Type of heat transfer oil . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Ji . [ ] | 2021 | Silicon oil | Simulation | / | 1.5–3.1% | 83.5–88.8% | The silicon oil directly cools the solar cells; dish concentrator is applied to realize high-grade thermal utilization; the temperature of the steam generation could reach 280°C |
2 | Codd . [ ] | 2020 | Silicon oil | Experiment | / | |||
3 | Samylingam . [ ] | 2020 | Olein palm oil/MXene | Simulation | / | 12.0–13.2% | 60–80% | It could reduce the temperature of PV module by 40°C compared with a single PV module; the thermal conductivity is improved remarkably |
4 | Rubbi . [ ] | 2020 | Soybean oil/MXene | Simulation | Polycrystalline | 12.2–14.3% | 61–84% | The overall efficiency of the PVT system could reach 84.25% using the Soybean oil/MXene |
5 | Aslfattahi . [ ] | 2020 | Silicon oil/MXene | Experiment | / | 17.8% | 60% | The performance of the CPVT module under different solar concentrations has been studied |
No. . | Author/ref . | Year . | Type of heat transfer oil . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Ji . [ ] | 2021 | Silicon oil | Simulation | / | 1.5–3.1% | 83.5–88.8% | The silicon oil directly cools the solar cells; dish concentrator is applied to realize high-grade thermal utilization; the temperature of the steam generation could reach 280°C |
2 | Codd . [ ] | 2020 | Silicon oil | Experiment | / | |||
3 | Samylingam . [ ] | 2020 | Olein palm oil/MXene | Simulation | / | 12.0–13.2% | 60–80% | It could reduce the temperature of PV module by 40°C compared with a single PV module; the thermal conductivity is improved remarkably |
4 | Rubbi . [ ] | 2020 | Soybean oil/MXene | Simulation | Polycrystalline | 12.2–14.3% | 61–84% | The overall efficiency of the PVT system could reach 84.25% using the Soybean oil/MXene |
5 | Aslfattahi . [ ] | 2020 | Silicon oil/MXene | Experiment | / | 17.8% | 60% | The performance of the CPVT module under different solar concentrations has been studied |
Samylingam et al . [ 59 ] proposed another heat transfer fluid based on olein palm oil (OPO), which could improve the thermal conductivity significantly compared to pure water (as shown in Fig. 16 ). They further added the MXene (Ti 3 C 2 ) into the OPO to enhance the heat transfer coefficient of the working fluid. It was found that the heat transfer coefficient could increase by 9% of the MXene-OPO fluid compared with the MXene-water fluid. Moreover, the employment of the novel heat transfer fluid could reduce the working temperature of the solar cells by 40% compared with the single PV module (the type of single PV module is the same as the PVT module).
Based on the abovementioned system, Rubbi et al . [ 60 ] optimized the performance of the PVT module through the Soybean oil/MXene heat transfer fluid. The CFD model was established to evaluate the thermal and electrical efficiencies of the novel PVT module. The thermal conductivity of the Soybean oil/MXene could be improved by 60.82% compared with the pure Soybean oil. The remarkable thermal performance of the heat transfer oil could decrease the working temperature of the solar cells and increase the electrical efficiency of the solar cells by 15.44% compared with the water/alumina fluid. The structure of the MXene particle is shown in Fig. 17 . Aslfattahi et al . [ 61 ] experimentally investigated the thermal and electrical performance of the Silicon oil/MXene-based PVT module. Figure 18 shows the schematic diagram of this system, they found that the maximum electrical efficiency could reach 17.8% while the thermal efficiency is 60%.
Table 3 presents the summary of the heat transfer oil-based PVT module.
Various structures of the air-based PVT module. [ 62 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Cross-section view of the V-shape air-based PVT module. (b) Photograph of the V-shape fluid channel. [ 63 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Four kinds of air-based bifacial PVT modules. [ 64 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Novel structured air-based PVT module. (b) Experimental setup of the system. [ 65 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The air is free to acquire for the air-based PVT module, and the structure of this kind of PVT module is more simple and reliable. The sealing requirement of the airflow channel is lower than that of the liquid-based PVT module’s fluid channel, thus, the air-based PVT module has the advantage in the initial cost. In addition, the low heat capacity of the air could make a remarkable temperature rise of the air during the operation. Moreover, the air-based PVT module does not have the problem of freezing the working medium compared with the liquid-based PVT module. The high-temperature air could be used for space heating, solar dryers, dehumidification, and industry process preheating, etc. Numerous studies have been conducted in terms of mathematical models, boundary conditions and structures to evaluate and improve the performance of the air-based PVT module.
Tonui et al . [ 62 ] designed different structures of the air-based PVT module as shown in Fig. 19 , including glass-covered, uncovered, the channel with fins, thin metal sheet structure, etc. They established the corresponding mathematical models of each structure and experimentally validated their correctness. The adoption of fin and thin metal sheets could efficiently increase the heat transfer area between the air and the PV module and then improve the thermal efficiency of the PVT collector. The results indicated that the arrangement of fin and the thin metal sheet would not rise the initial cost significantly, but it could improve the comprehensive thermal and electrical efficiencies remarkably.
From the aspect of structure design, Fudholi et al . [ 63 ] developed a V-shape thermal collector for air-based PVT collectors. The cross-section view of the V-shape PVT module and its photograph have shown in Fig. 20 . The numerical model was proposed and verified through the experiments. It was found that the error between the simulation and the experiments was within 5.49%. The exergy efficiency of this kind of PVT module is 12.89%.
The bifacial PV module was adopted to form the PVT module by Ooshaksaraei et al . [ 64 ] as shown in Fig. 21 and experimentally studied the performance of different structures. The experimental results showed that the comprehensive conversion efficiency of the air-based bifacial PVT module with the double-channel in the same direction is 51–67%. The single-channel air-based bifacial PVT module has a minimum conversion efficiency of 28–49%. However, due to the use of dual flow channels, the fluid on the upper surface of the PV module and the cover plate will affect the direct radiation incident to the surface of the PV module. Therefore, it is recommended to use a single-flow channel PVT air collector if electricity is preferred, and the dual-flow channel air-based bifacial PVT module in the same direction should be adopted if heat generation is preferred. In addition, the single-channel air-based bifacial PVT module has the highest exergy efficiency of 8.2–8.4%, followed by the dual-channel co-directed air-based bifacial PVT module with the exergy efficiency of 7.2–8%.
To further increase the heat transfer coefficient of the air-based PVT module, Gholampour et al . [ 65 ] designed a novel structured air-based PVT module as shown in Fig. 22 . The air enters the channel from all sides for heat exchange with the back of the PV module, and the heated air enters the outlet channel through the suction effect of the fan to take heat away. Through CFD simulation and experimental approaches, it is found that the equivalent thermal efficiency is taken as the index to obtain the optimal value of air suction velocity and PV coverage under different conditions, which provides guidance for designers to design air-based PVT modules schemes in the future.
(a) Cross-section view of the multiple inlets air-based PVT module. (b) Photograph of the system. [ 66 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Structure of the roof-type air-based PVT module. (b) Photograph of the PVT system. [ 68 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Photograph of the building integrated roof type air-based PVT module. (b) Cross-section view of the PVT module. (c) Schematic diagram of the roof type air-based PVT module. [ 73 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Yang et al . [ 66 ] improved on the basis of the original PVT air collector, multiple air inlets were set up at the assembly installation place and metal mesh heat collecting parts were installed at the outlet of the air flow passage. The cross-section view of the structure and photographs have shown in Fig. 23 . The experimental results revealed that the multi-inlet and metal mesh heat collecting parts could effectively improve the thermal efficiency, but also improve the working temperature of the air. Therefore, the working temperature of the PV module would also be increased and its electrical efficiency would be reduced. Thus, power generation or heat generation should be given priority according to different demands, and then the system should be designed and optimized accordingly. In addition, they [ 67 ] further studied the transmittance of this kind of PVT module. During the experiment, they found that the dual-inlet air-based PVT module with translucent PV modules improved the thermal efficiency by 7.6% compared with the dual-inlet air-based PVT module with opaque PV modules, and the dual-inlet air-based PVT module increased the thermal efficiency by 5% compared with the single-inlet air-based PVT module.
The air-based PVT module is suitable for building integration, Tiwari et al . [ 68 ] integrated the circular PV module with the air channel to form the roof air-based PVT module, and they used the PVT module to preheat the biogas. Figure 24a shows the structure of the roof-type air-based PVT module. The surface coverage is low due to the circular PV module unit, so more solar radiation could directly heat the air in the flow channel. Figure 24b shows the experimental rig. The experimental results showed that the thermal output of roof-type air-based PVT modules equipped with 1.27 square meters of components reaches 11.18 kWh under good irradiation conditions.
Figure 25 presents another kind of building integrated roof type air-based PVT module, the air flows from downside to upside and the tilt angle is 35 degrees. In the case of an effective building area of 65 m 2 , the annual electricity generation of the system is 16 209 kWh and the heat generation is 1531 kWh, and the average thermal efficiency is 53.7%. Based on this component structure form, Bambrook et al . [ 69 ] changed the mass flow rate of inlet air through experiments to explore the optimal mass flow rate of inlet air to achieve the highest comprehensive efficiency of the system. The experimental results showed that the power generation and thermal efficiency of the system are the highest at the mass flow rate of 0.03–0.05 kg/s. In addition, the electrical efficiency of the system fluctuates between 10.6% and 12.2%, and the thermal efficiency fluctuates between 28% and 55%. In addition to optimizing the operating parameters, Farshchimonfared et al . [ 70 , 71 ] optimized and analysed the physical structure parameters of air-based PVT modules. They used modules of 10, 15, 25 and 30 m 2 with ratios of 0.5, 1, 1.5 and 2, respectively. The optimal mass flow rate to component area ratio is 0.021 kg/s, and the optimal flow height is 0.026–0.09 m when the inlet and outlet temperature rises to 10°C. In addition, Singh et al . [ 72 ] optimized the performance of air-based PVT module by genetic algorithm, and analysed the effects of runner length and width, inlet velocity, inlet temperature, glass thickness and backplane thickness on component efficiency, respectively. The maximum power generation efficiency is 14.15%, and the thermal efficiency is 49.11% when the exergy efficiency is taken as the target.
Table 4 presents the summary of air-based PVT modules.
Summary of air-based PVT modules
No. . | Author/ref . | Year . | Type of thermal collector . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Shen . [ ] | 2021 | Shark dorsal fin-type | Simulation | Polycrystalline | 11.2–11.8% | 35–55% | The special cooling channel is designed; the flow characteristics have been investigated |
2 | Akshayveer . [ ] | 2021 | Flat-plate with PCM | Simulation | / | 10.5–12% | / | The air-based PVT module with PCM structure is proposed |
3 | Wajs . [ ] | 2020 | Air duct | Experiment | Monocrystalline | 4.4–5.8% | 20–27% | Building-integrated air-based PVT module |
4 | Kong . [ ] | 2020 | Rectangular air channel | Experiment | Polycrystalline | 5.7% | 46.8% | The air-based PVT system is used for drying |
5 | Choi . [ ] | 2020 | Transverse triangular obstacle | Experiment | / | 16.61% | 26.04–33.23% | The arrangement of transverse triangular obstacle could improve the thermal efficiency; the PVT module is integrated with air source heat pump |
6 | Arslan . [ ] | 2020 | L-shape finned channel | Simulation | Monocrystalline | 13.98% | 49.5% | A new type of finned air-fluid PVT module is designed and the CFD model is proposed |
7 | Fudholi . [ ] | 2019 | V-shape fluid channel | Experiment and simulation | Monocrystalline | / | / | The total exergy efficiency is 12.89–13.36% |
8 | Ooshaksaraei . [ ] | 2017 | Four configurations | Experiment and simulation | Monocrystalline | / | / | The total exergy efficiency is 51–67%; bifacial solar cells are adopted |
9 | Tiwari . [ ] | 2016 | Flat-plate fluid channel | Experiment | Monocrystalline | 12–14% | 23–36% | The circular solar cell is used to form an air-based PVT module |
10 | Gholampour . [ ] | 2016 | Flat transpired plate | Experiment and simulation | Polycrystalline | / | 45–55% | The design of multiple air inlets could increase the heat transfer coefficient |
No. . | Author/ref . | Year . | Type of thermal collector . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Shen . [ ] | 2021 | Shark dorsal fin-type | Simulation | Polycrystalline | 11.2–11.8% | 35–55% | The special cooling channel is designed; the flow characteristics have been investigated |
2 | Akshayveer . [ ] | 2021 | Flat-plate with PCM | Simulation | / | 10.5–12% | / | The air-based PVT module with PCM structure is proposed |
3 | Wajs . [ ] | 2020 | Air duct | Experiment | Monocrystalline | 4.4–5.8% | 20–27% | Building-integrated air-based PVT module |
4 | Kong . [ ] | 2020 | Rectangular air channel | Experiment | Polycrystalline | 5.7% | 46.8% | The air-based PVT system is used for drying |
5 | Choi . [ ] | 2020 | Transverse triangular obstacle | Experiment | / | 16.61% | 26.04–33.23% | The arrangement of transverse triangular obstacle could improve the thermal efficiency; the PVT module is integrated with air source heat pump |
6 | Arslan . [ ] | 2020 | L-shape finned channel | Simulation | Monocrystalline | 13.98% | 49.5% | A new type of finned air-fluid PVT module is designed and the CFD model is proposed |
7 | Fudholi . [ ] | 2019 | V-shape fluid channel | Experiment and simulation | Monocrystalline | / | / | The total exergy efficiency is 12.89–13.36% |
8 | Ooshaksaraei . [ ] | 2017 | Four configurations | Experiment and simulation | Monocrystalline | / | / | The total exergy efficiency is 51–67%; bifacial solar cells are adopted |
9 | Tiwari . [ ] | 2016 | Flat-plate fluid channel | Experiment | Monocrystalline | 12–14% | 23–36% | The circular solar cell is used to form an air-based PVT module |
10 | Gholampour . [ ] | 2016 | Flat transpired plate | Experiment and simulation | Polycrystalline | / | 45–55% | The design of multiple air inlets could increase the heat transfer coefficient |
Cross-section view of the direct expansion PVT module. [ 80 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The liquid-based PVT module and air-based PVT module apply the sensible heat working fluid to collect heat, while the refrigerant-based PVT module applies the latent heat working fluid. The cooling ability of the latent heat working fluid is better than the sensible heat working fluid due to the higher heat transfer coefficient. In this subsection, the refrigerant-based PVT module would be reviewed accordingly.
(a) Cross-section view of the triangular tube-type sheet-and-tube collector. (b) Photograph of the system. [ 82 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Cross-section view of the novel evacuated PVT collector/evaporator. (b) Vertical view of the component. [ 83 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The direct expansion PVT module means that the working medium (refrigerant) directly evaporates in the fluid channel and extracts heat from the solar cells through the phase transition process. The evaporation channel is attached to the PV module to form the direct expansion PVT module. Furthermore, the direct expansion PVT module is utilized as an evaporator. The solar-assisted PVT heat pump system consists of PVT module, compressor, expansion valve, and condenser. The refrigerant absorbs heat in the PVT module and then it would be compressed to a high-temperature and high-pressure state. Afterward, the refrigerant releases the heat to the heat storage medium [water, phase change material (PCM), etc.] during the condensation process. The condensed refrigerant enters the PVT collector/evaporator after cooling and reducing pressure through the expansion valve and then evaporates again through the heat absorption to complete the whole thermodynamic cycle. The thermal efficiency of the direct expansion PVT module is improved effectively due to the evaporation of refrigerants. However, the phase change process of the refrigerant is the two-phase flow, which would lead to a complex design of the fluid channel. The high flow resistance, uneven flow distribution and uneven temperature distribution would have adversely affected the performance of the PVT module. In this regard, various experiments and simulations have been studied to attain a higher comprehensive solar energy utilization efficiency.
Ji et al . [ 80 , 81 ] developed a sheet-and-tube PVT collector/evaporator, the fluid channel tube is welded to the heat-collecting aluminum metal sheet, which collects the heat from the back of the solar cells and transfers it to the copper tube through thermal conduction. The working medium in the copper tube collects the heat through the convection heat transfer process, the cross-section view of this kind of PVT module is shown in Fig. 26 . They coupled the component with the heat pump system to form the direct expansion solar-assisted PVT heat pump system. According to the experimental results, the maximum COP of the system could reach 8.4 while the average COP is 5.4, and the average electrical efficiency of the PVT module is about 13.4%. In addition, Ji et al . [ 81 ] developed a distributed dynamic model to describe the direct expansion solar-assisted PVT heat pump system. The model could calculate the refrigerant conditions, such as pressure, temperature, quality, enthalpy, etc. under given environmental conditions including ambient temperature, irradiation intensity, wind speed, etc. The simulation results showed that the electrical efficiency is 12% and the thermal efficiency is 50%.
The circular copper tube type sheet-and-tube collector has a demerit, which is that the heat transfer area between the copper tube and the absorbing plate is small. Therefore, Mohanraj et al . [ 82 ] designed a triangular tube-type sheet-and-tube collector and compared its performance with the conventional circular copper tube. Figure 27 shows the component structure and the experimental rig. In addition to experimental tests, they also used artificial neural network algorithms to make predictions about the system. In practical tests in India, it was found that the use of triangular flow channels resulted in significant improvements in system efficiency, such as a 3–7% increase in thermal efficiency, a 3–5% increase in COP and a 4–13% increase in electrical efficiency.
Structure of the flat-box-based PVT module. [ 84 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a–d) Four fluid channel patterns of the roll-bond panel. (e) Cross-section view of the roll-bond panel-based PVT module. [ 85 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Roof-type PVT module. [ 87 ] (b) Building integrating PVT module. [ 88 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) [ 93 ] Heat pipe-based PVT module. (b) [ 94 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Novel structured heat pipe-based PVT module. [ 98 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Summary of direct expansion PVT modules
No. . | Author/ref . | Year . | Type of thermal collector . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | COP . | Highlights . |
---|---|---|---|---|---|---|---|---|---|
1 | Yao . [ , ] | 2021 | Roll-bond panel | Experiment and simulation | Monocrystalline | 17.93% | 109.4% | 5.43 | Optimized the fluid channel pattern of the roll-bond panel regarding temperature uniformity, thermal and electrical efficiencies, hydraulic performance |
2 | Vaishak . [ ] | 2021 | Sheet and tube | Experiment and simulation | / | 13.66–14.74% | 35–55% | 3.03–3.42 | Three different back sheet materials are used including Glass, TPT, Cu |
3 | Shao . [ ] | 2020 | Roll-bond panel | Experiment | Polycrystalline | 11.67% | 60.17% | 3.7 | Building-integrated PVT module |
4 | Zhou . [ ] | 2019 | Roll-bond panel | Experiment | Polycrystalline | 8.7% | / | 5.3 | Tri-generation system |
5 | Liang . [ ] | 2018 | Roll-bond panel | Experiment | Monocrystalline | 9.0% | / | 3.1 | The system is driven by a refrigerant pump |
6 | Mohanraj . [ ] | 2015 | Sheet and tube | Experiment and simulation | Polycrystalline | 10–14% | / | 2.7–4.1 | Circular and triangular tube configurations |
7 | Tsai . [ ] | 2014 | Sheet and tube | Experiment and simulation | Polycrystalline | 12.2–12.5% | 73.6–74% | 7.07–7.10 | Roof type PVT module for water heating |
8 | Xu . [ ] | 2011 | Muti-port flat extruded aluminum tube | Experiment | / | 17.5% | / | 4.8 | Low-concentrating structure-based PVT module |
9 | Chen . [ ] | 2011 | Evacuated sheet-and-tube collector | Simulation | / | 14.8–16.2% | 71.1–79.4% | 4.65–6.16 | Novel structure with evacuated PVT module |
10 | Mastrullo . [ ] | 2010 | Flat-box thermal collector | Simulation | / | 13.7–14.2% | 52.0–84.3% | 4.0–8.5 | Flat-box tube-based PVT module |
No. . | Author/ref . | Year . | Type of thermal collector . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | COP . | Highlights . |
---|---|---|---|---|---|---|---|---|---|
1 | Yao . [ , ] | 2021 | Roll-bond panel | Experiment and simulation | Monocrystalline | 17.93% | 109.4% | 5.43 | Optimized the fluid channel pattern of the roll-bond panel regarding temperature uniformity, thermal and electrical efficiencies, hydraulic performance |
2 | Vaishak . [ ] | 2021 | Sheet and tube | Experiment and simulation | / | 13.66–14.74% | 35–55% | 3.03–3.42 | Three different back sheet materials are used including Glass, TPT, Cu |
3 | Shao . [ ] | 2020 | Roll-bond panel | Experiment | Polycrystalline | 11.67% | 60.17% | 3.7 | Building-integrated PVT module |
4 | Zhou . [ ] | 2019 | Roll-bond panel | Experiment | Polycrystalline | 8.7% | / | 5.3 | Tri-generation system |
5 | Liang . [ ] | 2018 | Roll-bond panel | Experiment | Monocrystalline | 9.0% | / | 3.1 | The system is driven by a refrigerant pump |
6 | Mohanraj . [ ] | 2015 | Sheet and tube | Experiment and simulation | Polycrystalline | 10–14% | / | 2.7–4.1 | Circular and triangular tube configurations |
7 | Tsai . [ ] | 2014 | Sheet and tube | Experiment and simulation | Polycrystalline | 12.2–12.5% | 73.6–74% | 7.07–7.10 | Roof type PVT module for water heating |
8 | Xu . [ ] | 2011 | Muti-port flat extruded aluminum tube | Experiment | / | 17.5% | / | 4.8 | Low-concentrating structure-based PVT module |
9 | Chen . [ ] | 2011 | Evacuated sheet-and-tube collector | Simulation | / | 14.8–16.2% | 71.1–79.4% | 4.65–6.16 | Novel structure with evacuated PVT module |
10 | Mastrullo . [ ] | 2010 | Flat-box thermal collector | Simulation | / | 13.7–14.2% | 52.0–84.3% | 4.0–8.5 | Flat-box tube-based PVT module |
To further improve the thermal efficiency of the PVT module, Chen et al . [ 83 ] developed a novel structured evacuated PVT collector/evaporator as shown in Fig. 28 . They adopted it to the solar-assisted heat pump system for water heating. The simulation results indicated that the average monthly thermal efficiency is 75.2% and the electrical efficiency is 15.5%. In addition, the average COP of the system is 5.35. The performance of the component decreases slightly when the irradiation intensity is low, so this kind of structure has a better application prospect in high latitude areas.
The flat-box absorber is another structure of the thermal collector, Mastrullo et al . [ 84 ] proposed a new structure of the PVT collector/evaporator with a flat-box absorber as shown in Fig. 29 . The arranged air gap could lower the thermal loss of the PVT module and then more waste heat could be absorbed by the working fluids. The simulated highest electrical efficiency could reach 14.2% while the thermal efficiency is 52.0%. The electrical efficiency is 13.7% when the highest thermal efficiency (84.3%) is attained. The temperature of the flat-box absorber would decrease with the increase of the fill factor of the solar cell units.
Except for the sheet-and-tube type and flat-box type thermal collector, the roll-bond panel type thermal collector is a promising method to realize high efficient thermal collection. The heat transfer area between the working fluids and the absorbing plate could be enlarged significantly due to its special structure. Yao et al . [ 85 ] proposed the roll-bond panel-based PVT module with an optimized fluid channel pattern. The various fluid channel patterns of the roll-bond panel and the cross-section view of the PVT module have shown in Fig. 30 . The temperature uniformity, electrical and thermal efficiencies and hydraulic performance have been evaluated numerically and comparatively. The simulation results indicated that the temperature uniformity of the fluid channel Pattern 2 is the best with the lowest flow resistance. It was found that the optimized fluid channel pattern could reduce the solar cells’ working temperature by up to 47.3°C and increase its electrical efficiency by 46.5% on a typical summer day. In this circumstance, the average system COP is 4.37, and the average temperature difference of the PVT module could be controlled within 4.6°C, while the average electrical and thermal efficiencies could reach 16.7% and 47.6%, respectively. Furthermore, they [ 86 ] conducted experiments to evaluate the performance of the PVT module, it was found that the average electrical and thermal efficiencies could reach 17.93% and 109.4%, respectively.
From the building integrating aspect, the roll-bond PVT module could also be used as a roof. For instance, Tsai et al . [ 87 ] integrated the direct expansion PVT module to the building façade as the roof as shown in Fig. 31a . The structure of the thermal collector is the sheet-and-tube type, and the refrigerant working medium evaporates and collects heat in the tube, taking away the heat of the PV module. The experimental results showed that the thermal efficiency of the component fluctuates between 73.6% and 74.2%, while the electrical efficiency fluctuates between 12.2% and 12.5% under dynamic operating conditions. The COP of the system fluctuates between 7.07% and 7.10 and the power produced by the PV module could be used by the compressor in self-operating mode. Similarly, Shao et al . [ 88 ] also developed a building attached type direct expansion solar-assisted PVT heat pump system, using the components as building roofs to provide power and heat for the building. Figure 31b shows the building integrated PVT collector/evaporator, and the collector type is roll-bond panel [ 89 ]. The advantages of the roll-bond panel are stable performance and high thermal efficiency. According to the experimental results, the average electrical efficiency and thermal efficiency of the system are 11.67% and 60.17%, respectively, and the average COP of the system is 3.7.
Table 5 presents the summary of the direct expansion PVT module and the specific parameters of the solar-assisted PVT heat pump system.
A heat pipe encapsulates the working fluid (refrigerant) in the tube and the cold end would absorb heat through the evaporating process while the hot end would release the heat through the condensing process. The hot side is commonly linked to the heat exchanger and transfer the heat to heat storage material (water, air, PCM, etc.). The secondary heat exchange process would mildly decrease the thermal efficiency of the system. Notwithstanding, the useful heat could be used for space heating, domestic hot water usage, residential heating, etc. Moreover, few researchers have composed the heat pipe PVT module with the thermoelectric device for higher electricity output.
As shown in Fig. 32a , Wu et al . [ 93 ] developed a core type heat pipe-based PVT module, they attached the heat pipe to the absorb plate with thermal conductive glue, and the heat absorbed by the heat pipe was transferred through secondary heat exchange to realize heat generation. They developed a solution based on the Number of Transfer Units (NTU) (heat element) method and analysed the effects of medium inlet temperature, solar cells’ fill factor and mass flow rate of the medium inlet on system performance. The simulation results showed that the temperature difference between heat pipe-based PVT module and PV module is less than 2.5°C. Its thermal efficiency, electrical efficiency and exergy efficiency are 63.65%, 8.45% and 10.26%, respectively. Gang et al . [ 94 , 95 ] adopted a heat pipe with another structure as a primary heat collector, as shown in Fig. 32b . The thermal and electrical properties of the components under dynamic conditions were analysed by the finite element method and verified by experiments. They used water as the heat collecting medium for secondary heat transfer, and the results showed that the highest thermal and electrical efficiencies of its components are 41.9% and 9.4%, respectively. In addition, the components used in the system could also be integrated to the building [ 96 ].
This kind of heat pipe-based PVT module was coupled with PCM storage by Sweidan et al . [ 97 ] for water heating. They arranged the encapsulated PCM sphere in the water storage tank while the hot side of the heat pipe was also arranged in the tank. The working liquid in the heat pipe evaporates after collecting heat from the PV module and releases heat at the condensation end to heat the hot water in the water tank. The existence of PCM could stabilize the water temperature. They simulated the optimal number of PV modules and the quality of PCMs for building heating. The simulation results showed that the highest electrical efficiency is 12.23% and the highest thermal efficiency is 35.3% in January. Moreover, the payback period of the system is 13.7 years.
Moradgholi et al . [ 98 ] developed another kind of heat pipe-based PVT module and the structure has shown in Fig. 33 . Their siphon heat pipe absorbs the waste heat generated by a monocrystalline silicon solar cell module using a phase change process inside the pipe. In spring, the working medium with methanol as the system has a slope of 30°, and in summer, the working medium with acetone as the system has a slope of 40°. The temperature of the PV modules drops by up to 15°C in the developed heat pipe-based PVT system. The experimental results showed that the electrical efficiency and thermal efficiency are increased by 5.67% and 16.35% respectively in spring, and by 7.7% and 45.14% in summer. Compared with the single PV module system (the type of single PV module is the same as the PVT module), the total efficiency is 15.3% and 44.38% higher in spring and summer, respectively.
Hu et al . [ 99 ] experimentally studied the thermal and electrical properties of components at different inclinations for the performance of heat pipe-based PVT modules with wickless and wire-meshed heat pipes. Two heat pipe-based PVT systems were tested at inclination angles of 20° and 40°, as shown in Fig. 34 . The experimental results showed that under the angle of 20°, the heat transfer resistance of the wickless heat pipe is large, so its component performance is poor. The inclination angle has little effect on the performance of the PVT system with wire-meshed heat pipe. The thermal efficiency of PVT systems based on wickless heat pipe and PVT systems based on wickless heat pipe is 52.8% and 51.5%, respectively, when the tilt angle is 40°. The efficiency of the wickless heat pipe is higher at a latitude above 20°, and the efficiency of heat pipe with the core is higher at a latitude below 20°.
(a) Wickless heat pipe. (b) Wire-meshed heat pipe. [ 99 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Except for the conventional circular type heat pipe, Deng et al . [ 100 ] adopted the microchannel heat pipe to form the heat pipe-based PVT module as shown in Fig. 35 . The microchannel contains micro fins, and its upper and lower surfaces are relatively flat, making it easier to fit with the PV module. The acetone acts as the working fluid of the heat pipe-based PVT module. The performance of the developed PVT system was tested under typical working conditions for four days. The results showed that the maximum electrical efficiency, thermal efficiency and average total efficiency are 14.65%, 33.07% and 45.38%, respectively.
Microchannel heat pipe-based PVT module. [ 100 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The heat pipe-based PVT module could also be used for building integration. PVT component is combined with the building to form the building integrated heat pipe-based PVT module, which can not only be used as the building envelope but also increase the thermal power output of the building and realize energy self-supply. In this regard, Jouhara et al . [ 101 ] developed a building roof type heat pipe-based PVT module, as shown in Fig. 36 and the experimental tests were carried out. They tested the performance of the PVT system without PV, without cooling and with cooling. A mixture of 60% water and 40% ethylene glycol is used as the working liquid of the heat pipe. The thermal conversion rates were 50% and 64% for systems with and without PV layers, respectively, when tested on three identical systems. The electrical efficiency of the heat pipe-based PVT module was increased by 15%.
(a) Structure of the PVT heat mat. (b) Photograph of the roof-type heat pipe-based PVT module. [ 101 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Table 6 presents a summary of heat pipe-based PVT modules.
Summary of heat pipe-based PVT modules
No. . | Author/ref . | Year . | Type of heat pipe . | Research method . | Type of PV module . | Type of heat pipe working medium . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|---|
1 | Brahim . [ ] | 2021 | Wickless heat pipe | Simulation | Polycrystalline | Acetone | 12.52% | 43.75% | The overall efficiency could reach 56.27% |
2 | Zhang . [ ] | 2019 | Wickless heat pipe | Experiment and simulation | Monocrystalline | Water | 10.05–10.08% | 45.1–45.8% | The influence of different working fluids has been investigated |
3 | Long . [ ] | 2017 | Wickless heat pipe | Simulation | Monocrystalline | Water | 10% | 35% | Building-integrated heat pipe-based PVT module |
4 | Sweidan . [ ] | 2016 | Wickless heat pipe | Simulation | Monocrystalline | Methyltetra-hydrofuran | 10.22–11.64% | 12–35.3% | Phase change material is adopted for heat storage |
5 | Jouhara . [ ] | 2016 | Flat heat pipe | Experiment | / | / | 7.0% | 49.4% | Building roof type heat pipe-based PVT module for water heating |
6 | Hu . [ ] | 2016 | Wire-meshed heat pipe | Experiment | Monocrystalline | Water | / | 35–55% | Performance comparison of the wickless and wire-meshed heat pipe-based PVT module |
7 | Zhang . [ ] | 2015 | Wickless heat pipe | Experiment | / | Water | 14.59–14.92% | 48.43–50.07% | The influence of water tank capacity is studied |
8 | Deng . [ ] | 2015 | Micro heat pipe | Experiment | Monocrystalline | Acetone | 11.9–14.9% | 19.9–37.8% | A micro-fluid channel thermal absorber is used to form the heat pipe-based PVT module |
9 | Moradgholi . [ ] | 2014 | Thermosiphon heat pipe | Experiment | / | / | 12–15% | 40% | A thermosiphon type heat pipe-based PVT module is proposed and tested |
10 | Zhang . [ ] | 2013 | Loop type heat pipe | Experiment | Polycrystalline | Water/glycol mixture (95%/5%) | 9.13% | 48.37% | A loop type heat pipe-based PVT module is used for water heating |
No. . | Author/ref . | Year . | Type of heat pipe . | Research method . | Type of PV module . | Type of heat pipe working medium . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|---|
1 | Brahim . [ ] | 2021 | Wickless heat pipe | Simulation | Polycrystalline | Acetone | 12.52% | 43.75% | The overall efficiency could reach 56.27% |
2 | Zhang . [ ] | 2019 | Wickless heat pipe | Experiment and simulation | Monocrystalline | Water | 10.05–10.08% | 45.1–45.8% | The influence of different working fluids has been investigated |
3 | Long . [ ] | 2017 | Wickless heat pipe | Simulation | Monocrystalline | Water | 10% | 35% | Building-integrated heat pipe-based PVT module |
4 | Sweidan . [ ] | 2016 | Wickless heat pipe | Simulation | Monocrystalline | Methyltetra-hydrofuran | 10.22–11.64% | 12–35.3% | Phase change material is adopted for heat storage |
5 | Jouhara . [ ] | 2016 | Flat heat pipe | Experiment | / | / | 7.0% | 49.4% | Building roof type heat pipe-based PVT module for water heating |
6 | Hu . [ ] | 2016 | Wire-meshed heat pipe | Experiment | Monocrystalline | Water | / | 35–55% | Performance comparison of the wickless and wire-meshed heat pipe-based PVT module |
7 | Zhang . [ ] | 2015 | Wickless heat pipe | Experiment | / | Water | 14.59–14.92% | 48.43–50.07% | The influence of water tank capacity is studied |
8 | Deng . [ ] | 2015 | Micro heat pipe | Experiment | Monocrystalline | Acetone | 11.9–14.9% | 19.9–37.8% | A micro-fluid channel thermal absorber is used to form the heat pipe-based PVT module |
9 | Moradgholi . [ ] | 2014 | Thermosiphon heat pipe | Experiment | / | / | 12–15% | 40% | A thermosiphon type heat pipe-based PVT module is proposed and tested |
10 | Zhang . [ ] | 2013 | Loop type heat pipe | Experiment | Polycrystalline | Water/glycol mixture (95%/5%) | 9.13% | 48.37% | A loop type heat pipe-based PVT module is used for water heating |
Different from the conventional PVT module, the spectral beam splitting PVT module adopts the splitter to utilize solar irradiation in different wavelengths. The solar energy would convert to electricity and waste heat (accumulated in solar cells) simultaneously of conventional PVT module, then the thermal collector absorbs heat from the solar cells to realize cogeneration. However, the spectral beam splitting PVT module could generate electricity and useful heat without convert to waste heat. The solar irradiation that could not excite the photovoltaic effect would convert to useful thermal energy directly due to the spectral beam splitter. The spectral beam splitting PVT module could decouple the photovoltaic and photothermal conversion process and realize efficient solar cogeneration. The spectral beam splitter could be mainly separated into three categories: nanofluids-based spectral beam splitter, nano-film-based spectral beam splitter and semitransparent PV cell-based spectral beam splitter [ 106 ]. The schematic diagrams of different spectral beam splitting PVT modules are shown in Fig. 37 .
Schematic diagrams of different spectral beam splitting PVT modules [ 106 ]. (APPLICABLE SOCIETY COPYRIGHT OWNER)
As shown in Fig. 37a , the nanofluids are employed as the spectral beam splitter as well as the heat collecting fluid. The infrared band of the solar irradiation (1109–2500 nm) would directly be absorbed by the nanofluids while the visible light (400–1109 nm) could penetrate the nanofluids and excite the photovoltaic effect. The nanofluids are arranged on the top of the PV module and this structure would decrease the electrical efficiency of the solar cells. The nanoparticles used in the nanofluids would cause sedimentation, leakage and pipe plugging problems. In this regard, numerous studies have been conducted to overcome the demerits of the nanofluids-based spectral beam splitter.
The typical structure of the nanofluids-based spectral beam splitter for PVT usage is shown in Fig. 38 . Ramdani and Ould-Lahoucine [ 107 ] numerically investigated the energy and exergy performance of this kind of PVT module. In their study, the water is regarded as the natural filter which could absorb infrared radiation. They developed the CFD model and conducted parametric analysis, the simulation results indicated that the thermal efficiency of the proposed PVT module could reach 17–40% while the electrical efficiency could reach 11.6–12.4%.
Cross-section view of the nanofluids beam splitter-based PVT module. [ 107 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Moreover, Al-Shohani et al . [ 108 , 109 ] comparatively investigated the thermal and electrical performance of the PVT module with/without optical water filter as shown in Fig. 39 . Different thicknesses of the water filter would influence the energy efficiency of the PVT module. The experimental results showed that the thicker water filter could reduce the working temperature of the solar cells more remarkably, but also would cause higher optical loss. The electrical efficiency of the PVT module with a 5 cm water filter has the maximum thermal efficiency (42%), but its electrical efficiency is the minimum (8%) due to the absorption of visible light of the water filter, while the total efficiency could reach above 50%.
Photograph of the PVT module with and without an optical water filter. [ 108 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Experimental rig for testing the PVT module. [ 110 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Pure water is easy to attain but its optical characteristics are not suitable for PVT usage. Thus, Han et al . [ 110 ] proposed five categories of nanofluids including inorganic aqueous salt, glycol, silicone oil, synthetic oil and mineral oil to improve the optical performance of the PVT module. The experimental rig has shown in Fig. 40 . Moreover, they adopted two types of solar cells (silicon cell and GaAs cell) for the PVT module. It was found that the electrical efficiency of the GaAs cell-based PVT module (13.1%) is lower than that of the silicon cell-based PVT module (15.7%) while the thermal efficiency is around 41%.
The fluid channel structure would influence the performance of the PVT module, thus, Rosa-Clot et al . [ 111 ] experimentally studied the S-shaped fluid channel type nanofluids beam splitter-based PVT module (as shown in Fig. 41 ). The field test revealed that the thermal efficiency varies from 30–60% while the electrical efficiency is around 13.19%. This kind of structure could improve the thermal and electrical efficiencies significantly while the maximum outlet temperature of the working fluid could reach 50°C.
To further improve the performance of the PVT module, Xiao et al . [ 112 ] investigated the influence of the S-shaped fluid channel’s structure on the system performance and temperature uniformity as shown in Fig. 42 . Model A has the best temperature uniformity under the same working conditions while its electrical and thermal efficiencies are 9.36% and 77.6%, respectively. However, the electrical efficiency of model C is the highest, which is 12.64%, but its thermal efficiency is the lowest, which is 71.15%. Therefore, different structures are recommended regarding the demand (electricity or heat).
Structure of the S-shaped fluid channel type nanofluids beam splitter-based PVT module. [ 111 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a–b) Structure of the S-shaped PVT module. (c) Temperature distribution of different fluid channel structure-based PVT modules. [ 112 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Photograph of the nanofluids beam splitter-based PVT module. [ 113 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Prototype of the spectral splitting concentrating PVT system. [ 114 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The PCM/nanofluids beam splitter-based PVT module. [ 115 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
The system configuration of the nano-film-based solar power generation system. [ 116 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic diagram of the nano-film filter-based solar cogeneration system. [ 117 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic diagram of the concentrated nano-film splitter-based PVT system. [ 118 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic diagram of the solar CPVT system. [ 119 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
(a) Cross-section view of the nano-film beam splitter-based PVT system. (b) Photograph of the system configuration. [ 120 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Structure of the PV-TE system. [ 122 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Configuration of typical power cycle-based solar cogeneration system
The configuration of the ORC with regenerator. [ 125 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
ETC-FPC driven Rankine cycle-based solar cogeneration system. [ 128 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Two kinds of solar-driven ORC cogeneration systems. [ 130 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic of the proposed systems. (a) LHP-based solar CHP system with the single-stage turbine. (b) LHP-based solar CHP system with double stage turbine. [ 131 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Simplified schematic view of the three HPG configurations under comparison. [ 132 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic of the solar dish Stirling micro-CHP system. [ 133 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic layout of solar-powered Stirling engine for micro-cogeneration. [ 134 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic picture of the m-CHP system under development within the DiGeSPo project. [ 136 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Schematic diagram of the new CCHP system with transcritical CO2 driven by solar energy. [ 139 ] (APPLICABLE SOCIETY COPYRIGHT OWNER)
Comparison of the electrical and thermal efficiencies of different solar cogeneration approaches
Comparison of the exergy efficiency and temperature of supply heating of different solar cogeneration approaches
Joshi and Dhoble [ 113 ] experimentally investigated theperformance of water, silicon oil and coconut oil-basedbeam splitter for PVT application. The experiment rig is shown in Fig. 43 . The maximum averagethermal and electrical efficiencies are 79% and 14%,respectively. It was found that the optical and thermalperformance of these three filters is similar for the PVTmodule.
To further improve the electricity and heat output, Zhang et al . [ 114 ] proposed and manufactured the spectral splitting concentrating PVT system and experimentally studied its performance. The structure of this prototype is shown in Fig. 44 . The maximum thermal and electrical efficiencies are 52% and 9.6%, respectively, when the diffuse irradiance ratios are 15.0%. Moreover, the adoption of the beam flitter could reduce the solar cells’ temperature by about 12°C. The outlet fluid temperature could reach 70°C when the concentration ratio is 15.
In another case, Yazdanifard et al . [ 115 ] employed the PCM as the first optical filter while the absorptive liquid as the second optical filter. The multi-layer structure of the proposed PVT module is shown in Fig. 45 . The numerical results showed that the electrical efficiency of the PVT module could reach 14.5% while the thermal efficiency of the PVT module is 46.5%. The nanofluids could maintain the temperature of the solar cells around 27°C while the temperature increase of the nanofluids is 7.2°C.
Table 7 summarizes the specific parameters of the nanofluids beam splitter-based PVT module.
Summary of nanofluids beam splitter-based PVT modules
No. . | Author/ref . | Year . | Type of nanofluids beam splitter . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Xiao . [ ] | 2021 | Fe O /water | Simulation | / | 9.36–12.64% | 71.15–77.6% | Different fluid channel structures of the nanofluids beam splitter have been studied |
2 | Yazdanifard . [ ] | 2020 | Ag/Water | Simulation | / | 14.5% | 46.5% | PCM and nanofluids beam are both considered as the beam splitter |
3 | Ramdani . [ ] | 2020 | Water | Simulation | Monocrystalline | 11.6–12.4% | 17–40% | Overall energy and exergy efficiencies have been studied |
4 | Han . [ ] | 2019 | Inorganic aqueous salt, glycol, silicone oil, synthetic oil, mineral oil | Experiment | Monocrystalline | 15.7% | 41% | The spectral characterizations of five different materials have been investigated |
5 | Zhang . [ ] | 2018 | / | Experiment | Polycrystalline | 9.6% | 52% | A parabolic concentrator is used to booster the thermal and electrical energy output |
6 | Joshi and Dhoble [ ] | 2018 | Water, silicon oil, coconut oil | Experiment | Polycrystalline | 14% | 79% | Comparison analysis of different filters has been given |
7 | Rosa-Clot . [ ] | 2016 | Water | Experiment | Polycrystalline | 13.19% | 30–60% | The influence of the fluid channel structure on system performance has been studied |
8 | Al-Shohani . [ ] | 2016 | Water | Experiment | Monocrystalline | 8% | 42% | The thickness of the beam filter has been investigated |
No. . | Author/ref . | Year . | Type of nanofluids beam splitter . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Xiao . [ ] | 2021 | Fe O /water | Simulation | / | 9.36–12.64% | 71.15–77.6% | Different fluid channel structures of the nanofluids beam splitter have been studied |
2 | Yazdanifard . [ ] | 2020 | Ag/Water | Simulation | / | 14.5% | 46.5% | PCM and nanofluids beam are both considered as the beam splitter |
3 | Ramdani . [ ] | 2020 | Water | Simulation | Monocrystalline | 11.6–12.4% | 17–40% | Overall energy and exergy efficiencies have been studied |
4 | Han . [ ] | 2019 | Inorganic aqueous salt, glycol, silicone oil, synthetic oil, mineral oil | Experiment | Monocrystalline | 15.7% | 41% | The spectral characterizations of five different materials have been investigated |
5 | Zhang . [ ] | 2018 | / | Experiment | Polycrystalline | 9.6% | 52% | A parabolic concentrator is used to booster the thermal and electrical energy output |
6 | Joshi and Dhoble [ ] | 2018 | Water, silicon oil, coconut oil | Experiment | Polycrystalline | 14% | 79% | Comparison analysis of different filters has been given |
7 | Rosa-Clot . [ ] | 2016 | Water | Experiment | Polycrystalline | 13.19% | 30–60% | The influence of the fluid channel structure on system performance has been studied |
8 | Al-Shohani . [ ] | 2016 | Water | Experiment | Monocrystalline | 8% | 42% | The thickness of the beam filter has been investigated |
As shown in Fig. 37b , the nano-film could realize spectral beam splitting benefit from its structure, and it could be used to separate the solar irradiation. The visible light (400–1109 nm) would be reflected by the nano-film when it is incident while the infrared light could penetrate the nano-film. Thus, the reflected visible light is used to generate electricity while the transmitted infrared light is used to generate heat. The PV module and thermal collector should be installed separately, which would cause a complex system arrangement. In this regard, the nano-film-based PVT module is not suitable for large-scale utilization due to the size limitation of the nano-film. The manufacturing process of the nano-film is not mature while the cost is high, which leads to poor economic performance. However, this kind of PVT module could realize high comprehensive solar energy utilization efficiency, and it has its suitable applications.
Shou et al . [ 116 ] developed a broadband TiO 2 /SiO 2 optical thin-film filter for solar power generation, the system configuration is shown in Fig. 46 . The thin-film filter could split the solar irradiation and reflect the visible light while penetrating the infrared light. The visible light could be used to generate electricity for the PV module, and the infrared light is also designed to generate electricity through the thermoelectric device. The maximum electrical efficiency of this system could reach 17.0% when the heterostructure cell is adopted, and the thermoelectric device could improve the overall electrical efficiency by 4.15%.
Crisostomo et al . [ 117 ] experimentally tested the performance of the SiN x /SiO 2 thin-film filters for PVT application. The test rig is shown in Fig. 47 . The linear Fresnel mirror is adopted to concentrate the incoming solar irradiation. The arrangement degree of the nano-film filter would affect the electrical efficiency of the solar cells. The testing maximum electrical efficiency of the solar cells could reach about 25% under 45 degrees arrangement while it is only 17% with 20 degrees. The total solar energy utilization efficiency could reach 85.6% of this system.
A similar structure as shown in Fig. 48 has been developed by Ling et al . [ 118 ] to generate heat and power simultaneously. The CdTe solar cell is adopted to generate electricity and it shows outstanding solar-to-electricity efficiency (39%, including thermochemical contribution). The electrical efficiency of the PV module is 15.5–19.5% while the thermal efficiency is around 60%. The cost analysis revealed that the specific cost of solar electricity is $0.20/kWh.
In another case, Wang et al . [ 119 ] designed and analysed the nano-film beam splitter-based PVT system as shown in Fig. 49 in terms of the thermodynamic aspect. They concluded that the overall optical efficiency is 66.2%. The thermodynamic analysis results revealed that the electrical efficiency of the PVT module could reach 26.6% while the overall efficiency could reach 30.5%.
Except for the linear concentration type, the point concentration Fresnel lens is adopted by Liang et al . [ 120 ] for small-scale usage as shown in Fig. 50 . The SiO2/TiO2 nano-film is used to split the solar irradiation, the experimental results showed that the electrical efficiency of the PV module is 13–16%, which is 9.4% higher than the conventional PV module. The overall energy efficiency and exergy efficiency of this study are 15.95% and 20.3%, respectively. Moreover, they [ 121 ] designed the two-axis sun tracking system for the nano-film beam splitter PVT module. The nano-film achieved a high reflectance (≥96.8%) for the visible light and a high transmittance (85%) at 1100–2500 nm. In this system, the overall energy efficiency could reach 22.72%.
Summary of nano-film beam splitter-based PVT modules
No. . | Author/ref . | Year . | Material of nano-film beam splitter . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Wang . [ ] | 2020 | Ge/Nb O /Na AlF | Simulation | Monocrystalline | 26.6% | / | The overall efficiency of the novel CPVT system is 30.5% |
2 | Ling . [ ] | 2020 | / | Simulation | / | 15.5–19.5% | 60% | The heat is used for thermochemical reaction |
3 | Liang . [ ] | 2020 | SiO /TiO | Experiment | Polycrystalline | 13–16% | / | The total energy efficiency could reach 18.85%, which is 5.8% higher than conventional system |
4 | Liang . [ ] | 2019 | SiO /TiO | Experiment | Polycrystalline | 18.54% | 4.18% | The overall exergy efficiency could reach 18.81% |
5 | Crisostomo . [ ] | 2014 | SiN /SiO | Experiment | / | 25% | / | The total energy efficiency is about 85.6% |
6 | Shou . [ ] | 2012 | TiO2/SiO2 | Simulation | / | 17.0% | / | The thermoelectric device could improve the overall electrical efficiency by 4.15% |
No. . | Author/ref . | Year . | Material of nano-film beam splitter . | Research method . | Type of PV module . | Electrical efficiency . | Thermal efficiency . | Highlights . |
---|---|---|---|---|---|---|---|---|
1 | Wang . [ ] | 2020 | Ge/Nb O /Na AlF | Simulation | Monocrystalline | 26.6% | / | The overall efficiency of the novel CPVT system is 30.5% |
2 | Ling . [ ] | 2020 | / | Simulation | / | 15.5–19.5% | 60% | The heat is used for thermochemical reaction |
3 | Liang . [ ] | 2020 | SiO /TiO | Experiment | Polycrystalline | 13–16% | / | The total energy efficiency could reach 18.85%, which is 5.8% higher than conventional system |
4 | Liang . [ ] | 2019 | SiO /TiO | Experiment | Polycrystalline | 18.54% | 4.18% | The overall exergy efficiency could reach 18.81% |
5 | Crisostomo . [ ] | 2014 | SiN /SiO | Experiment | / | 25% | / | The total energy efficiency is about 85.6% |
6 | Shou . [ ] | 2012 | TiO2/SiO2 | Simulation | / | 17.0% | / | The thermoelectric device could improve the overall electrical efficiency by 4.15% |
Table 8 presents the summary of nano-film beam splitter-based PVT modules.
As shown in Fig. 37c , the semitransparent PV cell refers to the technology that utilizes PV cells with the transparent electrode (TCO) [ 106 ]. The semiconductor material shows transparent characteristics when the incoming photons could not excite the photovoltaic effect while it would strongly absorb the incident visible light and convert it to electricity. The long-wavelength spectrum of the incoming solar irradiation would transmit the semitransparent PV cell and be absorbed by the thermal collector. The initial cost of this kind of PVT module would significantly increase and the electrical efficiency of the solar cells could not maintain at a high level.
However, the research about the semitransparent PV cell-based spectral beam splitter is not rich. Several researchers coupled the semitransparent PV cell with the thermoelectric (TE) device to further improve the electrical efficiency of the system. For instance, Zhou et al . [ 122 ] proposed the concentrated PV-TE system as shown in Fig. 51 to realize power generation, and other researchers [ 123 , 124 ] have investigated the nano-structure of the PV module to improve the utilization efficiency of the incoming solar irradiation. Nevertheless, the usage of the semitransparent PV cell for PVT application is scarce.
Different from photovoltaics, CSP is another pathway using solar energy for electricity generation. Coupling CSCs with the boiler power cycle, typical CSP systems concentrate the solar irradiation to heat the working fluids. The heated working fluids (of which the temperature is higher than 100°C) directly or indirectly drive the power cycle to generate electricity. Besides, the lower-grade thermal energy released from the condenser can be retrieved for domestic or industrial uses, which enables solar cogeneration based on the power cycle.
As Fig. 52 illustrates, a typical power cycle-based solar cogeneration system consists of the solar field, thermal energy storage (TES) system and heat and power generation (HPG) section. The solar field is composed of an array of solar collectors to concentrate solar irradiation. TES system stores the thermal energy and conveys it to the HPG section, serving as an optional buffer to overcome the intermittency of solar irradiation. HPG sections, comprising power cycle and SPG subsections, generate thermal energy with lower grade (for direct use or driving absorption/adsorption heat pump) and electricity simultaneously.
The CSP systems differ in cycle type. The power cycles functioning in the power cycle-based solar cogeneration systems mainly include the Rankine cycle, Stirling cycle and Brayton cycle.
Rankine cycle, especially organic Rankine cycle (ORC), is the dominant type of thermodynamic cycle functioning in the power cycle-based solar cogeneration systems. The concentrated solar irradiation heats the working fluid directly or indirectly (through a heat exchanger) and drives the Rankine cycle to generate electricity and heat.
Several types of solar collectors can serve in the solar field of Rankine cycle-based solar cogeneration system. Do Ango [ 125 ] et al . proposed a small-scale (electricity output <3 kW) solar cogeneration system ( Fig. 53 ), combining linear Fresnel collectors (as a solar field) and ORC with regenerator (as HPG sections). The test bench was manufactured ( Fig. 54 ), and an experiment was implemented to investigate the performance of the cogeneration system. The system offered an electrical efficiency of about 5% in the test condition.
Freeman et al . [ 126 ] proposed a small-scale solar ORC system for CHP with evacuated flat-plate collectors (EFPCs) or evacuated tube heat pipe collectors (ETHPCs) as a solar field. Freeman et al . simulated this proposed system with a collector area of 15 m 2 to access and compare the performance of systems with different collectors. The results presented the superiority of EFPC over ETHPC as a solar field and reported overall electrical efficiencies of 4.4–6.4% in the UK and of 6.3–7.3% in Cyprus under the simulation conditions. The system with EFPC was expected to have the potential to provide 3 h continuous 1-kW electricity output in Cyprus in January.
Borunda et al . [ 127 ] proposed a direct-feed solar cogeneration system coupling ORC and parabolic trough solar power plant. A case study (based on the meteorological data from Almeria) was conducted by TYNSYS to access the performance under different configurations. Under the simulation conditions, the electrical/thermal efficiency was estimated to be 6.79–8.35%/48.64–59.80% for different configurations, the overall exergy efficiency was estimated to be 24.87–30.58%.
Bellos et al . [ 128 ] designed an ORC solar cogeneration system with the combination of ETCs (evacuated tube collectors) and FPCs (flat plate collectors) as the solar field ( Fig. 55 ). A thermodynamic model based on EES was developed to investigate the performance variation of the system with the variation of heat production power. When the heating production varies from 5 kW to 35 kW, the overall energy efficiency was estimated to vary from 7.51% to 23.47%, while the exergy efficiency was ranged from 4.34% to 4.6%, respectively.
Eterafi et al . [ 129 ] conceptualized a solar cogeneration system combining dish collectors solar field and ORC for solar CHP. A TYNSYS-based simulation was implemented to evaluate the operation of the system daily and monthly. The required lowest inlet temperature was calculated at 266.1°C. After optimization, the average thermal and electric efficiency of the integrated system in July could reach 62.53% and 12.88%, respectively.
Zhang et al . [ 130 ] conducted an exergy analysis of two kinds of the solar cogeneration system, namely series mode and parallel mode ( Fig. 56 ), in Lhasa. Besides, three different collectors were investigated respectively based on different modes: FPC, ETC and PTC. The analysis was performed by Matlab and REFPROP to determine the optimal operation mode and collectors under different conditions.
HPG sections with different configurations are expected to influence the performance of the Rankine cycle-based solar cogeneration system. Beygzadeh et al . [ 131 ] conducted a thermodynamic comparison between solar ORC cogeneration systems (solar field: heat pipe collectors) with single-stage and double-stage turbines ( Fig. 57 ). The one-stage system was estimated to present a thermal/electrical/exergy efficiency of 63.39%/8.37%/11.22% with n-hexane as the working fluid for the single-stage system, and 63.36%/8.4%/11.26% for double stage system.
Cocco et al . [ 132 ] performed an exergy analysis by Matlab-based simulation to compare three different configurations ( Fig. 58 ) of HPG sections of an ORC solar cogeneration system with Linear Fresnel collectors as a solar field. The results suggested the superiority of HPG-A configuration for a small power-to-heat ratio and higher outlet water temperature.
Stirling cycle, as a technology received renewed attention and investigation recently, also functions in some conception of power cycle-based solar cogeneration system. Stirling engine is especially suitable for distributed micro-CHP systems due to its advantages of miniaturization, adaptability to different heat sources and high efficiency.
Moghadam et al . [ 133 ] conceptualized a solar dish Stirling cogeneration system to provide energy demand for a residential building. Figure 59 briefly demonstrates the system configuration. 3E analysis was conducted to investigate and optimize the system performance. The conditions of fives Iran cities were discussed. The results estimated the highest electrical/overall efficiency of 34.5%/78.4% in Tabriz.
Ferreira et al . [ 134 ] proposed a micro solar cogeneration system equipped with a Stirling engine and dish collectors. Figure 60 briefly presents the system configuration. The proposed system was expected to output 1–5 kW of electricity and 2–35 kW of thermal power and to provide hot water with a temperature of 343 K. The system was estimated to offer an electrical/total efficiency of 26.2%/98.1% after optimization. Ferreira et al . [ 135 ] also proposed a solar-driven Stirling cycle cogeneration system for domestic use, reported an expected electrical/thermal efficiency of 23.91%/74.1%, with the output hot water temperature as 333 K.
Crema et al . [ 136 ] proposed and demonstrated a micro solar cogeneration system ( Fig. 61 ) combining parabolic trough collectors with a Stirling engine. Figure 61 presented the solar field and Stirling engine of the demonstration plant. The demonstration activities provided the best efficiency of 47%.
Brayton cycle with supercritical carbon dioxide has higher thermal efficiency compared with Rankine cycle and is also reported to function in the power cycle-based solar cogeneration systems. Brayton cycle-based solar cogeneration system is suitable for large-scale CHP systems given the large volume of the devices and high working pressure.
The Brayton cycle could be utilized as the power cycle of the solar-assisted power generation system. Wang et al . [ 137 ] reported a Dish Brayton system for power generation with solar energy serving on preheating. However, the solar-driven Brayton cycle providing CHP/CCHP was rarely reported. Sharan et al . proposed a solar-driven Brayton cycle providing cogeneration of electricity and heat-driven desalination [ 138 ]. Wang et al . [ 139 ] conceptualized a solar-driven Brayton cycle combined with ejector refrigeration ( Fig. 62 ) for CCHP. Driven by trough collectors, this system provided a thermal efficiency of 53.0%, and net electricity output of 0.109 kW (the input solar irradiation was 135.277 kW).
Table 9 presents the summary of power cycle-based solar cogeneration systems.
Summary of power cycle-based solar cogeneration systems
No. . | Author/ref . | Year . | Type of solar collector . | Type of power cycle . | Electrical efficiency . | Thermal efficiency . | Overall efficiency . | Exergy efficiency . | The temperature of supply heating . |
---|---|---|---|---|---|---|---|---|---|
1 | Do Ango . [ ] | 2019 | Linear Fresnel | Rankine cycle | −5% | / | / | 38°C | |
2 | Freeman . [ ] | 2017 | EFPC/ETHPC | Rankine cycle | 6.3–7.3% | / | / | / | |
3 | Borunda . [ ] | 2016 | Parabolic trough | Rankine cycle | 6.79–8.35% | 48.64–59.80% | 55.43–68.15% | 24.87–30.58% | 83.9°C |
4 | Bellos . [ ] | 2019 | ETC and FPC | Rankine cycle | / | / | 7.51–23.47% | 4.34–4.6% | 60°C |
5 | Eterafi . [ ] | 2021 | Dish | Rankine cycle | 12.88% | 62.53% | 75.41% | / | 50°C |
6 | Beygzadeh . [ ] | 2020 | Heat pipe collector | Double-stage Rankine cycle | 8.37% | 63.39% | 71.76% | 11.22% | 80.39°C |
7 | Moghadam . [ ] | 2013 | Dish | Stirling cycle | 34.5% | 43.9% | 78.4% | / | / |
8 | Ferreira . [ ] | 2016 | Dish | Stirling cycle | 26.2% | 71.9% | 98.1% | / | 70°C |
9 | Ferreira . [ ] | 2017 | Dish | Stirling cycle | 23.91% | 74.1% | 98.01% | / | 60°C |
10 | Wang . [ ] | 2012 | Compound parabolic | Brayton cycle | / | 53.0% | / | 28.8% | 70–159°C |
No. . | Author/ref . | Year . | Type of solar collector . | Type of power cycle . | Electrical efficiency . | Thermal efficiency . | Overall efficiency . | Exergy efficiency . | The temperature of supply heating . |
---|---|---|---|---|---|---|---|---|---|
1 | Do Ango . [ ] | 2019 | Linear Fresnel | Rankine cycle | −5% | / | / | 38°C | |
2 | Freeman . [ ] | 2017 | EFPC/ETHPC | Rankine cycle | 6.3–7.3% | / | / | / | |
3 | Borunda . [ ] | 2016 | Parabolic trough | Rankine cycle | 6.79–8.35% | 48.64–59.80% | 55.43–68.15% | 24.87–30.58% | 83.9°C |
4 | Bellos . [ ] | 2019 | ETC and FPC | Rankine cycle | / | / | 7.51–23.47% | 4.34–4.6% | 60°C |
5 | Eterafi . [ ] | 2021 | Dish | Rankine cycle | 12.88% | 62.53% | 75.41% | / | 50°C |
6 | Beygzadeh . [ ] | 2020 | Heat pipe collector | Double-stage Rankine cycle | 8.37% | 63.39% | 71.76% | 11.22% | 80.39°C |
7 | Moghadam . [ ] | 2013 | Dish | Stirling cycle | 34.5% | 43.9% | 78.4% | / | / |
8 | Ferreira . [ ] | 2016 | Dish | Stirling cycle | 26.2% | 71.9% | 98.1% | / | 70°C |
9 | Ferreira . [ ] | 2017 | Dish | Stirling cycle | 23.91% | 74.1% | 98.01% | / | 60°C |
10 | Wang . [ ] | 2012 | Compound parabolic | Brayton cycle | / | 53.0% | / | 28.8% | 70–159°C |
The different approaches to harvesting solar energy for cogeneration have various energy and exergy efficiencies. In this regard, the applications for each technology method are differed according to the output temperature range. Thus, the comparison of energy and exergy efficiencies and suitable system applications is introduced in this section.
Figure 63 illustrates the comparison results of the electrical and thermal efficiencies of different solar cogeneration approaches. The thermal efficiency of the liquid, air and spectral beam splitter-based PVT modules varies from 20% to 80% while the electrical efficiency is in the range of 5–18%, which is determined by the solar cells’ type and operating temperature. The liquid, air and spectral beam splitter-based PVT modules commonly adopt the working fluids that use sensible heat to collect heat. Thus, the heat transfer coefficient would be limited by the temperature difference between the solar cells and the working fluids. In this regard, the refrigerant-based PVT module that uses latent heat as a major method to extract heat performs better in thermal efficiency. Therefore, the higher thermal efficiency that is above 100% could be attained when the refrigerant evaporating temperature is lower than the ambient temperature. The electrical efficiency according to the field tests of the photovoltaic effect-based solar cogeneration system is generally below 20%. The conversion efficiency of the photovoltaic effect would limit the electrical efficiency of the PVT module, and the high operating temperature of the solar cells would have an adverse effect on its efficiency. In this regard, the power cycle-based solar cogeneration system shows better performance in electrical efficiency. For instance, the electrical efficiency of the Stirling cycle-based solar cogeneration system and Brayton cycle-based solar cogeneration system could reach around 35% and 42%, respectively, but the electrical efficiency of the Rankine cycle-based solar cogeneration system is around 12%. The thermal efficiency of the power cycle-based solar cogeneration system is around 50%. To be noted, the thermal efficiency of the Brayton cycle-based solar cogeneration system has not been reported clearly. Not all points within the rectangle range could be obtained. The rectangle range exists only to better demonstrate the electrical and thermal efficiencies of each technology.
The exergy efficiency and temperature of supply heating are shown in Fig. 64 . The power cycle-based solar cogeneration system has higher exergy efficiency than most photovoltaic effect-based solar cogeneration systems. Nevertheless, the exergy efficiency of the PVT module using CSC could be improved. The temperature of supply heating of power cycle-based solar cogeneration system could reach above 100°C while the outlet temperature of PVT module is generally below 80°C due to the limitation of the solar cells’ temperature. In this regard, the power cycle-based solar cogeneration system has better performance; however, the construction, initial cost and maintenance of this kind of system are much higher than the photovoltaic effect-based solar cogeneration system. To be noted, not all points within the rectangle range could be obtained. The rectangle range exists only to better demonstrate the exergy efficiency and temperature of supply heating of each technology.
The system applications would differ considering the system scale, installation area, temperature of thermal energy output, usage requirement, etc. Table 10 summarizes the system applications (focus on thermal energy usage) of different solar cogeneration approaches. Small scale system is suitable for household usage, while middle scale system is preferable for public buildings, factories, schools, etc., and a large-scale system is recommended for a district, village, community, etc.
Summary of system applications of various solar cogeneration approaches [ 11 ]
System classification . | Approach . | System scale . | Applications . |
---|---|---|---|
Photovoltaic effect-based solar cogeneration | Liquid-based PVT module | Small scale; middle scale | Domestic hot water; residential, pool heating; pre-heating for desalination, industry |
Air-based PVT module | Small scale; middle scale | Space heating; solar dryers; pre-heating for desalination, industry | |
Refrigerant-based PVT module | Small scale | Domestic hot water; residential heating | |
Spectral beam splitting PVT module | Small scale | Domestic hot water; residential heating | |
Power cycle-based solar cogeneration | Brayton cycle-based solar cogeneration | Large scale | District heating; hot water supply; industry heating process |
Stirling cycle-based solar cogeneration | Small scale | Domestic hot water; residential heating | |
Rankine cycle-based solar cogeneration | Small scale; middle scale | Domestic hot water; residential heating; pre-heating for desalination, industry |
System classification . | Approach . | System scale . | Applications . |
---|---|---|---|
Photovoltaic effect-based solar cogeneration | Liquid-based PVT module | Small scale; middle scale | Domestic hot water; residential, pool heating; pre-heating for desalination, industry |
Air-based PVT module | Small scale; middle scale | Space heating; solar dryers; pre-heating for desalination, industry | |
Refrigerant-based PVT module | Small scale | Domestic hot water; residential heating | |
Spectral beam splitting PVT module | Small scale | Domestic hot water; residential heating | |
Power cycle-based solar cogeneration | Brayton cycle-based solar cogeneration | Large scale | District heating; hot water supply; industry heating process |
Stirling cycle-based solar cogeneration | Small scale | Domestic hot water; residential heating | |
Rankine cycle-based solar cogeneration | Small scale; middle scale | Domestic hot water; residential heating; pre-heating for desalination, industry |
In this article, efficient approaches to harvesting solar energy for cogeneration have been reviewed. The photovoltaics-based solar cogeneration systems and power cycle-based solar cogeneration systems have been introduced, classified and analysed. Furthermore, the comparison of energy and exergy efficiencies and system applications identified suitable applications for each technology analysed.
The power cycle-based solar cogeneration system could reach higher exergy efficiency with high-grade thermal energy output. However, the initial cost, system installation, system safety and maintenance difficulty would limit the application of this technology. Therefore, the power cycle-based solar cogeneration system is recommended for middle and large-scale applications such as district heating, power supply, etc. On the contrary, the photovoltaic-based solar cogeneration systems (known as PVT) are more applicable for small-scale use. The compact system arrangement and flexible installation area make the PVT system a promising application in distributed use systems (households, single buildings, etc.). In terms of delivery temperature, the power cycle-based solar cogeneration system has a higher outlet temperature (>100°C) while the temperature of supply of the PVT system is generally below 80°C. Thus, the power cycle-based solar cogeneration system is more versatile and the high-grade thermal energy could also be used for industrial pre-heating, desalination, district heating, etc. The photovoltaic-based solar cogeneration system is more preferable for domestic hot water supply, residential heating, spacing heating, etc.
The photovoltaics-based solar cogeneration system is suitable for urban areas while the power cycle-based solar cogeneration system is preferable in suburbs, but each technology has its merits, depending on the perspective chosen. In the future, more efficient and lower-cost technologies could be developed to realize solar cogeneration, for instance, higher efficiency PV modules, efficient solar thermal systems, etc. Distributed solar energy utilization technologies could be further expanded in cities. Therefore, efficient solar cogeneration methods could significantly reduce the demand for fossil fuels usage, decrease carbon emissions and contribute to sustainable development.
STUDY FUNDING
This publication has been jointly written within the cooperative project ‘Key technologies and demonstration of combined cooling, heating and power generation for low-carbon neighborhoods/buildings with clean energy—ChiNoZEN’. The authors gratefully acknowledge the funding support from the Ministry of Science and Technology of China (MOST project number 2019YFE0104900) and from the Research Council of Norway (NRC project number 304191—ENERGIX).
CONFLICT OF INTEREST
None declared.
Jian Yao is responsible for the methodology, investigation, data collation and plotting and writing of the original draft. Wenjie Liu is responsible for the methodology, investigation and data collation and plotting. Yifan Jiang is responsible for the methodology and data collation and plotting. Sihang Zheng is responsible for the methodology and data collation and plotting. Yao Zhao is responsible for the methodology, investigation and data collation and plotting. Yanjun Dai is responsible for the conceptualization, supervision, funding acquisition and writing of the review and editing. Junjie Zhu is responsible for the supervision, methodology and writing of the review and editing. Vojislav Novakovic is responsible for the supervision, methodology and writing of the review and editing.
The data used to support the findings of this study are available from the corresponding author upon request.
Congress TtSMPs The Fourteenth Five-Year Plan of Shanghai Municipality for National Economic and Social Development and the Outline of the 2035 Long-Term Goals . China : Shanghai Municipal Government , 2021
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Solar panels are widely used nowadays to capture solar radiation and generate voltage, so they are being used for Energy Harvesting applications. The present work carries out the study of low power solar panels for energy storage applications, together with the DC-DC conversion and storage stage. The methodology carried out has been the design, simulation, fabrication and characterization of the elements that form the system. The elements that make up the system are 4 solar panels of 2.4 V and 80 mA, a voltage regulator element and rechargeable batteries. As a result, both in simulation and measurement, the mixed configuration (series-parallel) is the one that provides the best characteristics for its use, with a voltage of 4.57 V and a current of 127.3 mA, obtaining at the converter output a voltage of 19.44 V, concluding that the system meets the design expectations with which it was made, collecting energy, raising it and storing it, providing promising results for future applications.
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Ecofly-power store - monocrystalline solar panel (2022). https://es.aliexpress.com/item/1005003206041039.html
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The authors thank the invaluable contribution of the Technological University Indoamerica, for his support in conducting the research project “ESTUDIO DE ALGORITMOS HIBRIDOS DE APRENDIZAJE AUTOMATICO PARA LA PREDICCIÓN DE GENERACIÓN DE ENERGÍAS RENOVABLES”, Project Code: 281.230.2022. Also, the authors thank the Technical University of Ambato and the “Dirección de Investigación y Desarrollo” (DIDE) for their support in conducting this research, in the execution of the project “Captación de Energía Limpia de Baja Potencia para Alimentación de Dispositivos de Quinta Generación (5G)”, approved by resolution “Nro. UTA-CONIN-2022-0015-R”. Project code: SFFISEI 07.
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Nuñez, M., Gordón, C., Sánchez, C., Cumbajín, M. (2023). Solar Panels for Low Power Energy Harvesting. In: Garcia, M.V., Gordón-Gallegos, C. (eds) CSEI: International Conference on Computer Science, Electronics and Industrial Engineering (CSEI). CSEI 2022. Lecture Notes in Networks and Systems, vol 678. Springer, Cham. https://doi.org/10.1007/978-3-031-30592-4_21
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Policies and ethics
At a glance, key challenge, policy insight, introduction.
By 2040, the amount of land needed to meet the United States’ growing energy requirements will increase by 27%, directly affecting an estimated 200,000 square kilometers (sq. km.) of land with new energy development (Trainor et al. 2016, 1-16). This is the projected result of both a changing energy portfolio and increasing demand.
Over the last decade, for example, advances in drilling technology have unlocked considerable energy potential from 1.3 million sq. km. of land—roughly twice the size of Alaska—that had previously been ill-suited for conventional oil and gas development. Fossil fuel production demands constant land expansion as available resources are depleted. Production will continue to encroach on new land for as long as demand for these fuels persists.
If the U.S. sets ambitious targets for renewable energy development, with the ultimate goal of reaching net-zero carbon emissions from energy by 2050, the share of land directly affected by new renewable energy infrastructure would increase dramatically (Larson et al. 2020, 1-345). Just meeting existing electricity demand with photovoltaics would require approximately 290,000 sq. km. of land, assuming 150 MW/ sq. km. of electricity generation, a capacity factor of 25%, as well as perfect load balancing (U.S. Energy Information Administration, n.d.). 1
In the lower 48 states, 63% of land is used for agricultural purposes (Economic Research Service, U. S. Department of Agriculture). As demand for energy infrastructure increases, land competition between energy and agricultural production will inevitably grow—as will the potential advantages of co-locating these land uses where possible.
We have already seen the shale boom drive mineral developers to many agricultural regions, and the result has been a surge in domestic fuel production and a significant secondary source of income for many farm operators (Hitaj and Suttles 2016, 1-47). In some states, like Oklahoma and Pennsylvania, oil and gas development leases provide up to 6% of gross cash farm income, and an even greater share of net income.
In 2014, more than 10% of farms in 9 American states received energy production-related payments. Average payments can be sizable, exceeding $150,000 in Pennsylvania and North Dakota. These leases can be immensely valuable to farm owners, since most American farms are small and depend on off-farm sources of income to remain operational (Economic Research Service, n.d; U. S. Department of Agriculture, n.d.).
Although the co-location of energy infrastructure on farmland has historically been mostly limited to oil and gas development, on-farm solar development is increasingly becoming a financially viable and environmentally friendly alternative on American farmland. On-farm solar development can help meet the country’s swelling demand for carbon-free energy, offer farmers and rural communities a consistent and long-term stream of income, and even boost agricultural productivity under the right circumstances.
However, realizing these co-benefits at scale will require a long-term commitment and innovative solutions from local, state, and federal policymakers. In this policy digest, we lay out why farmers choose to lease their mineral rights, the unpredictable costs of on-farm oil and gas development, and why solar could be a better alternative.
In the United States, most subsurface rights—the rights to minerals beneath the ground—are privately owned by individuals (Fitzgerald 2014, 1-7). Typically, energy companies interested in extracting minerals will lease land from owners rather than purchase the land outright. This is an effective way for the development companies to reduce capital expenses – reflecting their singular and short-term interest in the land.
The compensation structure for these land leases typically includes an upfront payment as well as a royalty, which reflects a share of the gross revenue of any oil or gas that is ultimately extracted (typically between 13 to 21%) (Brown et al. 2016, 23-38). Crucially, energy development companies can deduct expenses associated with transportation and processing from landowners’ royalty payments (Fitzgerald 2014, 1-7).
As one might expect, there is a substantial amount of information asymmetry between the lessee and the lessor in these arrangements. Company representatives have extensive experience negotiating agreements, while farm owners may only negotiate a mineral lease once in a lifetime. In addition, because oil and gas resources at a given site require expert analysis to approximate, the energy company generally has a more complete understanding of expected production than the mineral rights owner.
Fuel prices are also a considerable source of revenue variability. In 2020, for example, the U.S. government saw its royalties from mineral rights fall from $2 billion between March and June, compared to $4 billion in the same period last year, because of the precipitous drop in fuel prices and production induced by the COVID-19 pandemic (Knight 2020).
Landowners have little recourse in response to disruptions in expected revenue since contracts can last for many years. And when prices fall, the post-production costs deducted by developers can eat into farmers’ royalty checks, especially if their lease agreements do not address allowable deductions (Cusick and Sisk 2018).
Not only are oil and gas leases often uncertain value propositions, they also come with a number of serious economic and environmental risks for farmers (U.S. Geological Survey, n.d.). At best, development leads to increased traffic and noise pollution, and places increased demands on local water resources. At worst, oil and gas development leads to water and soil contamination and reduced land productivity (Environmental Protection Agency 2015, 1-25).
A typical shale gas well can use 2 to 4 million gallons of water during fracturing, the process by which gas resources are extricated from subterranean rock formations (U.S. Department of Energy 2009, 1-98). Wells can drive-up local water prices or compel farmers to modify their operations (Dutzik et al. 2012, 1-43).
Accidental water contamination or improper gas flaring can sicken or even kill livestock. Furthermore, according to a 2019 Energy Research & Social Science study that surveyed farmers in four midwestern states, many respondents reported relying on themselves or family to complete land reclamation efforts following oil or gas development (Haggerty et al. 2019, 84-92).
For farmers who own their mineral rights and are approached by a developer, the security of a secondary source of income—even one that comes with the uncertainties of energy land leases—can be attractive. The promise of additional revenue often outweighs the environmental risks, an indication of the substantial economic pressures many farmers face.
Yet for many rural communities, mineral leases may fail to provide much long-term benefit. The precise economic effect of natural gas development remains an area of active research. A 2016 study found that employment and wages can grow in the first four years of gas development, but decline to pre-boom levels over time (Komarek 2016, 1-17).
A 2014 study of the oil and gas boom in the American West in the 1970s and 1980s actually found that per capita incomes, following the bust, were 6% lower than pre-boom levels and that unemployment compensation remained elevated throughout the post-bust period (Jacobsen and Parker 2016, 1092-1128). The authors suggest that overspecialization in infrastructure and skills specific to the boom limited market participants’ ability to find new business and employment opportunities once the demand for extraction services receded and economic fundamentals changed.
Perhaps most importantly, a closer look at payment statistics reveals that the financial rewards of oil and gas development are not equally available to all American farmers, and instead largely accrue to a small subset (Hitaj et al. 2018, 1-31). In 2014, the top 10% of farmers receiving oil and gas payments received 18 times more money than the bottom 50% of farmers receiving payments. The mean payment to all farmers receiving oil and gas royalties was $43,736, dwarfing the median payment of just $6,600.
For all of their economic risks and environmental harms, mineral leases demonstrate an opportunity for the co-location of energy and agricultural production. On-farm solar (or agrivoltaics) can offer farmers and rural landowners a smaller environmental footprint and fewer economic risks than oil and gas development, while still providing a reliable secondary source of income. As the country’s energy demand affects more and more land, agrivoltaics can also play a crucial role in accelerating the transition to renewables.
First and foremost, solar panels present almost no risk of soil or water contamination when installed and maintained properly. In terms of water consumption, photovoltaic maintenance only requires enough water to occasionally wash dust and grime from panel surfaces (Clarke 2014). Compared to an oil or gas well, this water use is negligible.
Further, solar panels produce no additional toxic waste, and aside from soil disturbance during installation or removal, they have little long-term impact on the productivity of the land on which they are sited. While larger solar installations can have negative effects on soil and vegetation, there are a number of measures—like careful siting, prudent landscaping, and re-vegetation—that can mitigate these concerns (Dhar et al. 2020, 134602). In general, solar panels have a dramatically more favorable environmental profile than traditional sources of power generation (Turney and Fthenakis 2011, 3261-3270).
Solar power is also a flexible, reliable, and scalable source of energy, especially on agricultural land. Whereas oil and gas wells require a minimum of 5-10 acres of land, solar can be deployed to whatever scale a farm owner desires or is able to accommodate (MineralWise, n.d.). This means that solar can be developed on land that is already unused or unirrigated by farmers, minimizing disruptions to existing farm production.
In 2011, the National Renewable Energy Laboratory estimated that Colorado had over 1,200 sq. km. of non-irrigated corners of center-pivot irrigation fields (Roberts 2011, 1-11). This land could, in theory, support 890 sq. km. of solar fields without compromising agricultural productivity.
While a farmer’s opportunity to capitalize on mineral rights is entirely dependent on whether or not there is an accessible oil or gas basin, photovoltaics are an economically viable investment for landowners across the country, and solar power is at its most productive (Adeh et al. 2019, 11442) when installed on croplands (McDonnell 2020). While temperature and average cloud cover determine the capacity factor of cells, solar is already being successfully deployed from Arizona to Maine.
Solar power is also immune to hyperbolic declines in production, as is possible with oil and gas drilling (see Figure 1) (U.S. Energy Information Administration 2020). Instead, solar leases are long-term (Moore 2017), typically lasting around 20 years, with fixed rental contracts instead of royalties (White). This reduces the economic risk borne by landowners, and while there is certainly risk associated with long-term agreements, the fixed payment structure—as well as fairly predictable life-cycle costs—can help farmers avoid imbalanced negotiations with developers and plan for the future (Xiarchos and Vick 2011, 1-86).
In some cases, revenue from solar development can eclipse the revenue generated by harvest yields (Bookwalter 2019), though other studies have suggested that payback periods for on-farm solar projects are still too long (Colorado State University Extension, n.d., 45-48).
Still, the benefits of solar panels on farmland could extend far beyond simply providing a supplementary income source; they can, in the best case, actively enhance farm operations and improve agricultural yield. Agrivoltaics—the siting of elevated solar panels above crops, which continue to be cultivated—can confer a number of synergistic benefits, which oil and gas development cannot emulate (Barron-Gafford et al. 2019, 848-855).
Agrivoltaics are capable of reducing transpiration of water from plants and the evaporation of water from soil, thereby reducing farmers’ water use. Solar panels can also mitigate some of the light and heat stress that can have an adverse effect on crop photosynthesis.
Finally, transpired water has a cooling effect on solar panels, improving their efficiency by at least 1% (Tricoles 2017). While the effects of agrivoltaics on crop yield varies by species, some study results have shown a doubling in total fruit production and water efficiency in shade-tolerant and temperature-sensitive crops (Barron-Gafford et al. 2019, 848-855).
In the context of the wider economy, agrivoltaics can serve as a mitigant (Agostini et al. 2021, 116102) against market shocks or crop shortages and can help meet the energy demands of several farm operations such as pumping water, refrigeration, lighting, and sprinkler systems (Xiarchos and Vick 2011, 1-86). The benefits of agrivoltaics extend to livestock farming as well. The co-siting of photovoltaics on a rabbit farm, for example, was recently shown to reduce operating costs by up to 8%, increase revenue by 17%, and cut fencing-related costs (Lytle et al. 2021, 124476).
The opportunities offered by on-farm solar development are considerable, especially when compared to mineral leases. However, there are some remaining economic and policy challenges that demand policy solutions before the full potential of co-locating agriculture and solar generation can be fully realized. These solutions would promote the (a) provision of public funds for rural energy development and incentive programs, (b) the circulation of tools and information that can help farmers make financially sound decisions, and (c) the implementation of streamlined land use policies to facilitate solar development and protect crop yields.
Continued public funding is necessary to encourage the adoption of solar resources and ensure that such projects make financial sense for farm operators . There are already a number of (Tennessee Department of Energy and Conservation 2020; Massachusetts Farm Energy Program, n.d.) state and federal funding opportunities for farmers interested in investing in on-farm renewable energy projects, including a 30% federal business energy investment tax credit and a 25% Rural Energy for America Program grant from the U.S. Department of Agriculture (neither of which are available to oil and gas developers) (Hay 2016, 1-27).
However, for agricultural land to host meaningful solar generation capacity and support a rapid transition to renewables, these funding opportunities ought to be accessible to a much wider community of farmers. Specifically, federal agencies, like the USDA, should direct greater public funding toward on-farm solar deployment. The availability of external funding is a significant determinant of the ultimate profitability and size of renewable energy systems adopted by farmers (Bazen and Brown 2009, 748-754; Beckman and Xiarchos 2013, 322-330).
In recent years, the federal government has aggressively stepped up its support of solar projects in rural America. Between 2002 and 2019, the USDA distributed over $7.7 billion in grant aid to support renewable energy development in rural communities (USDA, n.d.). Along with anaerobic digesters, solar projects have been the largest recipients of this USDA support in the past five years.
These targeted grants and loan guarantees have helped small businesses cut their energy costs and energy consumption (USDA 2019). In 2015 alone, solar projects financed by the USDA’s Rural Energy for America Program generated 530,000 MWhs of electricity (Hitaj and Suttles 2016, 1-47). Still, federal support for investment in agricultural infrastructure remains relatively modest and should be significantly expanded in order to meet changing energy demands.
Federal loan and grant programs still play a critical role in making solar development a profitable proposition for farm operators and in sustaining investor interest (Petrovich et al. 2021, 106856). In 2015 and 2016, Colorado State University conducted 30 solar assessments for farmers interested in renewable systems deployment in pivots—land left unused owing to center-pivot irrigation (Colorado State University Extension, n.d. 45-48). Those researchers found that the average solar array would have generated lifetime energy savings of $156,000, in addition to $23,000 in payments for excess electricity sold back to the grid. The up-front cost of the average solar array was $137,000, before incorporating any federal grants and tax credits. Accounting for such credits, the total cost would fall to $71,000, significantly reducing the payback period and resulting in a return on investment of 4.7%.
Farm operators and rural communities need to be empowered with the information to make financially and environmentally sound decisions regarding on-farm energy development. One of the central goals of policymakers interested in facilitating on-farm solar development should be to help clarify the full financial picture of a proposed project. Absent such support, it would be easy to discount on-farm renewable energy based on revenue figures alone: According to a USDA. analysis, in 2014, the average payment to farm operators for leasing wind rights was $8,287, substantially less than the average payment of $43,736 from oil and gas (Hitaj et al. 2018, 1-31). While the USDA did not consider revenues associated with on-farm solar projects in that study, modern solar and wind installations have similar costs/kW and capacity factors in the same ballpark, so landowners can expect lease revenue from solar projects to be similarly modest (Mey 2020; SolarLandLease, n.d.). It is worth noting, however, that wind power is significantly less energy dense than photovoltaic power in terms of kW/acre. This means that while costs/kW and capacity factors may be similar across both technologies, photovoltaics may offer farmers and developers the flexibility to generate more electricity from the same acreage.
Sound information and technical guidance, however, could allow on-farm solar projects to be financially viable investments that circumvent many of the risks associated with traditional oil and gas development. A key advantage of solar development, over oil or gas, is that solar radiation is much easier to estimate than subsurface mineral availability.
Whereas oil and gas are found in relatively dense pockets of geological formations and require extensive site exploration to uncover and approximate, solar radiation is easily mappable based on geographic location, local topography, and surrounding vegetation. In fact, the National Renewable Energy Laboratory offers a solar calculator tool online that allows users to estimate the performance of solar facilities, based on their location and other variables (National Renewable Energy Laboratory, n.d.).
But solar radiation is just one of several inputs. For farmers considering leasing their land for solar development, the value of their land and the range of possible per-acre rental fees they could collect is essential information needed for negotiations with developers. According to Strategic Solar Group, annual per-acre rents for larger tracts of solar land can range from $300 to $800 depending on a state’s average capacity factor and land availability (White).
To help farmers navigate these financial considerations—for land leases and personal projects alike—federally-supported, no-cost energy audits should be made available to all farm owners (New York State Energy Research and Development Authority, n.d.). These audits would help operators identify possible applications of solar power and understand the costs, savings, and payback periods of possible solar development (among other energy-saving and emissions-reducing measures).
Between 2016 and 2019, CSU Rural Energy Center administered its Farm Assessments for Solar Energy program, which provided 60 free evaluations to farmers about the feasibility of solar installations on their properties (Colorado State University Extension, n.d.). Colorado’s Energy Office also administers an Agricultural Energy Efficiency program, which provides free audits for eligible farms seeking to reduce energy expenses and implement cost-saving measures (Colorado Energy Office, n.d.).
Further expanding the reach of such programs—and leveraging emerging technologies such as LiDAR to improve and streamline auditing—could protect rural landowners in negotiations in a way that has never really been possible with oil and gas leases. These audits could give landowners confidence in moving forward with rental agreements or personal development projects—lending assurance that their investments are sound and ultimate revenues are fair, even if those revenues are relatively modest.
Land use, planning, and energy policies need to be clarified and made more consistent. On-farm solar development has the potential to directly compete with existing cropland if not planned and developed with sustained or improved agricultural productivity in mind. Finding this balance remains a major focus for state and local officials and policymakers (Bergan and Braun 2019).
The Grow Solar Initiative, a USDA-funded effort to boost the solar production potential of three Midwestern states, observes that regulatory and statutory inconsistencies for siting projects can be major obstacles to the growth of the solar industry (Grow Solar 2015). As the opportunities for shared land use become better understood, local and state governments need to outline clear and detailed guidelines for what constitutes appropriate and allowable shared use of agricultural land.
In 2019, for example, North Dakota’s Public Service Commission approved the construction of a 200 MW utility-scale project on 1,600 acres of prime farmland (Lee 2019). Under existing North Dakota laws, this land would have been excluded from development if the overall effect on agricultural yields was perceived to be too large. Existing laws, however, did not specifically prescribe what constituted a large effect on agricultural yields, so the commission had to deliberate (unearthing microform documents from the 1970s in the process) before reaching a decision.
Like North Dakota, Michigan has had to wrestle with decades-old laws blocking more rapid solar development. The state’s Farmland and Open Space Preservation Program, passed in 1975, requires participating farmers to maintain their farmland for agricultural uses in exchange for tax incentives and exemptions (Michigan Department of Agriculture and Rural Development). But the state decided in 2017 that commercial solar development was not a permissible activity on land preserved by the program, excluding one-third of the state’s farmland from solar electricity generation (the program covered 3 million acres in 2020) (Malewitz 2019; Michigan Department of Agriculture & Rural Development 2020, 1-20).
Farmers interested in solar development could have exited the program, but they would have had to pay back the previous seven years of tax credits along with 6% interest—a prohibitive barrier (Malewitz 2019). It took another two years before the state revised its policy, allowing solar development for commercial and personal purposes on preserved farmland (Michigan Department of Agriculture & Rural Development 2019).
The use of agricultural land for solar electricity generation can support the U.S. farm sector, strengthen rural economies, and facilitate the country’s energy transition. The shale gas revolution of the last decade has offered valuable lessons for farmers and energy developers about how energy lease agreements should be structured in order to both promote energy development and protect farmers, local resources, and surrounding ecosystems. On-farm solar power eliminates many of the most serious environmental risks of oil and gas development and can, if deployed correctly, increase the productivity of crops and livestock.
However, inconsistent regional land use policies, insufficient federal funding for development and research, and the inadequate availability of information mean that the full potential of solar development on American farmland has yet to be realized. The abundance of agricultural land in the United States could be a competitive advantage in national efforts to decarbonize, but until the necessary policy tools are leveraged, it is more likely to create unnecessary land competition.
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Associate Professor of Materials, University of Oxford
Sebastian Bonilla receives funding from UK Research and Innovation, The Royal Academy of Engineering, and The Leverhulme Trust.
University of Oxford provides funding as a member of The Conversation UK.
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The sight of solar panels installed on rooftops and large energy farms has become commonplace in many regions around the world. Even in grey and rainy UK, solar power is becoming a major player in electricity generation.
This surge in solar is fuelled by two key developments. First, scientists, engineers and those in industry are learning how to make solar panels by the billions. Every fabrication step is meticulously optimised to produce them very cheaply. The second and most significant is the relentless increase in the panels’ power conversion efficiency – a measure of how much sunlight can be transformed into electricity.
The higher the efficiency of solar panels , the cheaper the electricity. This might make you wonder: just how efficient can we expect solar energy to become? And will it make a dent in our energy bills?
Current commercially available solar panels convert about 20-22% of sunlight into electrical power. However, new research published in Nature has shown that future solar panels could reach efficiencies as high as 34% by exploiting a new technology called tandem solar cells. The research demonstrates a record power conversion efficiency for tandem solar cells.
Traditional solar cells are made using a single material to absorb sunlight. Currently, almost all solar panels are made from silicon – the same material at the core of microchips. While silicon is a mature and reliable material, its efficiency is limited to about 29%.
To overcome this limit, scientists have turned to tandem solar cells, which stack two solar materials on top of each other to capture more of the Sun’s energy.
In the new nature paper, a team of researchers at the energy giant LONGi has reported a new tandem solar cell that combines silicon and perovskite materials. Thanks to their improved sunlight harvesting, the new perovskite-silicon tandem has achieved a world record 33.89% efficiency.
Perovskite solar materials, which were discovered less than two decades ago , have emerged as the ideal complement to the established silicon technology. The secret lies in their light absorption tuneability . Perovskite materials can capture high energy, blue light more efficiently than silicon.
In this way, energy losses are avoided and the total tandem efficiency increases. Other materials, called III-V semiconductors, have also been used in tandem cells and achieved higher efficiencies. The problem is they are hard to produce and expensive, so only small solar cells can be made in combination with focused light.
The scientific community is putting tremendous effort into perovskite solar cells. They have kept a phenomenal pace of development with efficiencies (for a single cell in the lab) rising from 14% to 26% in only 10 years. Such advancements enabled their integration into ultra-high-efficiency tandem solar cells, demonstrating a pathway to scale photovoltaic technology to the trillions of Watts the world needs to decarbonise our energy production.
The new record-breaking tandem cells can capture an additional 60% of solar energy. This means fewer panels are needed to produce the same energy, reducing installation costs and the land (or roof area) required for solar farms.
It also means that power plant operators will generate solar energy at a higher profit. However, due to the way that electricity prices are set in the UK , consumers may never notice a difference in their electricity bills. The real difference comes when you consider rooftop solar installations where the area is constrained and the space has to be exploited effectively.
The price of rooftop solar power is calculated based on two key measures. First, the total cost to install solar panels on your roof, and second, how much electricity they will generate over their 25 years of operation. While the installation cost is easy to obtain, the revenues from generating solar electricity at home are a bit more nuanced. You can save money by using less energy from the grid, especially in periods when it is costly, and you can also sell some of your surplus electricity back to the grid.
However, the grid operators will pay you a very small price for this electricity, so sometimes it is better to use a battery and store the energy so you can use it at night. Using average considerations for a typical British household, I have calculated the cash savings consumers would gain from rooftop solar electricity depending on the efficiency of the panels.
If we can improve panel efficiency from 22% to 34% without increasing the installation cost, savings in electricity bills will rise from £558ְ/year up to £709/year. A 27% bump in cash savings that would make solar rooftops extremely attractive, even in grey and cloudy Britain.
As research continues, considerable efforts are being made to scale up this technology and ensure its long-term durability. The record breaking tandem cells are made in laboratories and are smaller than a postage stamp. Translating such high performance to metre-square areas remains a vast challenge.
Yet, we are making progress. Earlier this month, Oxford PV, a solar manufacturer at the forefront of perovskite technology, announced the first sale of its newly developed tandem solar panels. They have successfully tackled the challenges of integrating two solar materials and making durable and reliable panels. While they are still far from 34% efficiencies, their work shows a promising route for next generation solar cells.
Another consideration is the sustainability of the materials used in tandem solar panels. Extracting and processing some of the minerals in solar panels can be hugely energy intensive . Besides silicon, perovskite solar cells require the elements lead, carbon, iodine and bromine as components to make them work properly. Connecting perovskite and silicon also requires scarce materials containing an element called indium , so there is plenty of research still required to address these difficulties.
Despite the challenges, the scientific and industrial community remains committed to developing tandem solar devices that could be integrated into almost anything: cars, buildings and planes.
The recent developments toward high efficiency perovskite-silicon tandem cells indicate a bright future for solar power, ensuring solar continues to play a more prominent role in the global transition to renewable energy.
Lecturer / senior lecturer in construction and project management.
First published on 16th September 2024
Results and discussion.
Schematic representation of the synthesis of . |
(A) UV-Vis and (B) emission spectra of in THF and different THF:water mixtures. (C) Photographs showing the change in fluorescence colours of upon irradiation with 365 nm light at different ratios of the THF:water mixtures. |
HR-SEM micrographs of the self-assembled structures formed by in THF were obtained in THF building block in THF:water mixtures of varying polarity. |
(A) and (B) FT-IR spectra of the dried mass of obtained with a THF obtained with (C) THF (via J-aggregation) through intermediate lamellar molecular arrangement followed by layer closure or a scroll-up process in THF:water mixtures with varied polarity. |
To verify the hydrolytic stability of L1 , we recorded the UV-Vis absorption and steady-state emission spectra of the precursors imidazole-based aldehyde (A1) and naphthalene diamine (B1) in THF:water mixtures of varying polarity. Noticeable differences in the electronic spectral pattern of the starting aldehyde (A1) and diamine (B1) of L1 suggest that L1 is stable in aqueous media (Fig. S7, ESI † ). Furthermore, the emission colour of the parental aldehyde (A1) and the diamine (B1) in a THF:water mixture with varied polarity (Fig. S8, ESI † ) confirmed that the visually detectable changes in the emission colour of L1 upon altering the polarity of the medium are due to aggregation induced by changing the medium polarity and not due to hydrolytic decomposition.
Optimized geometries of the calculated minima structure of the monomer are shown in two orientations: (a) open (S1) and (b) stacked (S2). The corresponding dimer is also depicted in two orientations: (c) S1 dimer and (d) S2 dimer. [C: grey, N: blue, H: white]. |
Frontier molecular orbitals of the calculated minima structure of the dimer involved in the main absorption peak at wB97XD/def2-TZVPP in a THF |
Medium | Excitation energy (eV) | Wavelength (nm) | Oscillator strength (f) | Key transitions | |
---|---|---|---|---|---|
(S1-dimeric form) | THF | 3.476 | 356.66 | 4.859 | HOMO−2 → LUMO |
HOMO−1 → LUMO | |||||
HOMO → LUMO+1 | |||||
(S2-dimeric form) | 100% THF | 3.778 | 328.19 | 1.081 | HOMO → LUMO+3 |
HOMO−2 → LUMO | |||||
HOMO−2 → LUMO+1 | |||||
3.798 | 326.46 | 1.002 | HOMO → LUMO+1 | ||
HOMO−1 → LUMO | |||||
HOMO−1 → LUMO+1 |
Snapshots taken at a simulation time of 5 ps for (a) the S1 dimeric form of with water, and (b) the S2 dimeric form of with THF. [C: green, C(THF): cyan, O: red, H: white]. |
(A) Absorption spectra of (blue) and RhB (black) and emission spectra of (red) and RhB (pink) in the THF (20 μM, blue), RhB (200 nM, pink) and (20 μM) + RhB (200 nM) (red; λ = 382 nm); inset: photograph of the emission colour of (20 μM), RhB (200 nM) and (20 μM) +RhB (200 nM). (C) Emission spectra of (20 μM) in the THF + RhB and 580 nm of RhB. |
(A) Fluorescence lifetime decay profiles (λ = 382 nm, monitored at 539 nm) of upon the addition of different concentrations of RhB (0–200 nM). IRF – instrument response time. (B) Energy transfer efficiency as a function of [RhB]. (C) Schematic representation of the self-assembled /RhB-based light-harvesting system. |
η = 1 − (F /F ) | (1) |
AE = F /F | (2) |
Synthesis of l1, self-assembly of l1, high-resolution scanning electron microscopy (hr-sem), dynamic light scattering (dls) analysis, fourier transform infrared spectroscopy (ft-ir), uv-vis spectroscopy, fluorescence spectroscopy, x-ray diffraction (xrd) analysis, dft calculations.
Time-dependent (TD)-DFT calculations of the complex geometries were performed at the ωB97XD/def2-TZVPP level. The hybrid meta-GGA functional ωB97XD has a 100% fraction of HF exchange at long-range in addition to about 22% at short-range and also contains empirical dispersion terms. 64 Unlike PBE0, the long-range-corrected functional ωB97XD properly describes the ground and excited state properties of complex molecules. 68 The importance of long-range corrected functionals for charged systems and for describing CT states is explained in previous studies. 69,70 The ten lowest vertical excitation energies were calculated based upon time-dependent density functional theory (TDDFT), utilizing optimized geometries.
Periodic boundary condition calculations were performed using the Vienna Ab initio Simulation Package (VASP) using the plane-wave basis set. 71,72 All calculations were done on the PBE level of theory using Grimme empirical dispersion. 73 Ab initio MD simulations were performed using the isothermal–isobaric (NPT) ensemble until equilibrium was achieved. 74,75 The MD simulation was performed at 300 K using the Langevin thermostat and standard pressure, and the timestep was set to 1 fs.
Data availability, conflicts of interest, acknowledgements.
† Electronic supplementary information (ESI) available: UV spectra, emission spectra, length and width distribution graph, fluorescence colour photographs, minima structure of dimers, and bond length variations in monomers. See DOI: |
‡ Equal contribution |
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Advancements and future prospects in ocean wave energy harvesting technology based on micro-energy technology.
Yang, W.; Peng, J.; Chen, Q.; Zhao, S.; Zhuo, R.; Luo, Y.; Gao, L. Advancements and Future Prospects in Ocean Wave Energy Harvesting Technology Based on Micro-Energy Technology. Micromachines 2024 , 15 , 1199. https://doi.org/10.3390/mi15101199
Yang W, Peng J, Chen Q, Zhao S, Zhuo R, Luo Y, Gao L. Advancements and Future Prospects in Ocean Wave Energy Harvesting Technology Based on Micro-Energy Technology. Micromachines . 2024; 15(10):1199. https://doi.org/10.3390/mi15101199
Yang, Weihong, Jiaxin Peng, Qiulin Chen, Sicheng Zhao, Ran Zhuo, Yan Luo, and Lingxiao Gao. 2024. "Advancements and Future Prospects in Ocean Wave Energy Harvesting Technology Based on Micro-Energy Technology" Micromachines 15, no. 10: 1199. https://doi.org/10.3390/mi15101199
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The results showed that the system can generate 3-4 mW power, which is sufficient for low-power applications such as sensors. Also, the system was capable of generating electricity at wind speeds of 0-26 m/s. Zheng et al. [47] reported a hybrid energy system for harvesting solar, raindrops, and wind energy. Piezoelectric strips were used to ...
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