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Auswahl der wissenschaftlichen Literatur zum Thema „PV GENERATION SYSTEM“
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Zeitschriftenartikel zum Thema "PV GENERATION SYSTEM"
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Zhou, Hua, Huahua Wu, Chengjin Ye, Shijie Xiao, Jun Zhang, Xu He und Bo Wang. „Integration Capability Evaluation of Wind and Photovoltaic Generation in Power Systems Based on Temporal and Spatial Correlations“. Energies 12, Nr. 1 (05.01.2019): 171. http://dx.doi.org/10.3390/en12010171.
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With the rapid growth of renewable energy generation, it has become essential to give a comprehensive evaluation of renewable energy integration capability in power systems to reduce renewable generation curtailment. Existing research has not considered the correlations between wind power and photovoltaic (PV) power. In this paper, temporal and spatial correlations among different renewable generations are utilized to evaluate the integration capability of power systems based on the copula model. Firstly, the temporal and spatial correlation between wind and PV power generation is analyzed. Secondly, the temporal and spatial distribution model of both wind and PV power generation output is formulated based on the copula model. Thirdly, aggregated generation output scenarios of wind and PV power are generated. Fourthly, wind and PV power scenarios are utilized in an optimal power flow calculation model of power systems. Lastly, the integration capacity of wind power and PV power is shown to be able to be evaluated by satisfying the reliability of power system operation. Simulation results of a modified IEEE RTS-24 bus system indicate that the integration capability of renewable energy generation in power systems can be comprehensively evaluated based on the temporal and spatial correlations of renewable energy generation.
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Huang, Ke, Xin Wang, Yi Hui Zheng, Li Xue Li und Yan Ling Liu. „Reliability Analysis of Distribution Network with Integrated Photovoltaic Power Generation“. Applied Mechanics and Materials 672-674 (Oktober 2014): 956–60. http://dx.doi.org/10.4028/www.scientific.net/amm.672-674.956.
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To analyze the influence of distribution network with grid-connected photovoltaic (PV) generation on the power supply reliability, in this paper it firstly regards interconnected PV generation as an equivalent generator with rated capacity as well as the island operation mode of PV to set up a model for reliability calculation and analysis. Based on the network equivalent method, the structure of distribution system with PV is simplified and then the reliability indexes of distribution system are worked out based on Failure Mode and Effects Analysis (FMEA). At last, a comparative calculation between the distribution network with incorporated PV generations and that without PV generations is made. After analyzing a real example, the results suggest that integrating PV power generations reasonably into the distribution network can enhance the reliability of whole distribution system.
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Lee, Seung-Min, Eui-Chan Lee, Jung-Hun Lee, Sun-Ho Yu, Jae-Sil Heo, Woo-Young Lee und Bong-Suck Kim. „Analysis of the Output Characteristics of a Vertical Photovoltaic System Based on Operational Data: A Case Study in Republic of Korea“. Energies 16, Nr. 19 (06.10.2023): 6971. http://dx.doi.org/10.3390/en16196971.
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The proliferation of renewable energy sources to achieve carbon neutrality has rapidly increased the adoption of photovoltaic (PV) systems. Consequently, specialized solar PV systems have emerged for various installation purposes. This study focuses on grid connecting vertically installed bifacial PV modules facing east and west by establishing a test bed within Republic of Korea. Based on weather and generation data collected in Republic of Korea, located in the middle of latitude 34.98° N, from January to July 2023, we analyzed and compared the generation patterns, peak generation, peak hours, and total generation of conventional and vertical PV systems. Moreover, PVsyst was used to model the solar PV generation and analyze the consistency and viability of vertical PV generation by comparing actual operational data with simulation results. The vertical PV system demonstrated a peak power generation of 89.1% compared with the conventional PV system with bifacial modules. Based on operational data from January to July, the power generation output of the vertical PV system decreased to 65.7% compared with that of the conventional system with bifacial modules. This corresponded to 78.8% to 80.2% based on the PVsyst simulation results. In particular, the investigations related to the peak generation levels and occurrence times of vertical PV systems provide insights into the practicality of vertical solar PV systems and their potential for improving the PV hosting capacity.
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Abedi, Sajjad, Gholam Hossein Riahy, Seyed Hossein Hosseinian und Arash Alimardani. „Risk-Constrained Unit Commitment of Power System Incorporating PV and Wind Farms“. ISRN Renewable Energy 2011 (19.12.2011): 1–8. http://dx.doi.org/10.5402/2011/309496.
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Wind and solar (photovoltaic) power generations have rapidly evolved over the recent decades. Efficient and reliable planning of power system with significant penetration of these resources brings challenges due to their fluctuating and uncertain characteristics. In this paper, incorporation of both PV and wind units in the unit commitment of power system is investigated and a risk-constrained solution to this problem is presented. Considering the contribution of PV and wind units, the aim is to determine the start-up/shut-down status as well as the amount of generating power for all thermal units at minimum operating cost during the scheduling horizon, subject to the system and unit operational constraints. Using the probabilistic method of confidence interval, the uncertainties associated with wind and PV generation are modeled by analyzing the error in the forecasted wind speed and solar irradiation data. Differential evolution algorithm is proposed to solve the two-stage mixed-integer nonlinear optimization problem. Numerical results indicate that with indeterminate information about the wind and PV generation, a reliable day-ahead scheduling of other units is achieved by considering the estimated dependable generation of PV and wind units.
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Jeong, Han Sang, Jaeho Choi, Ho Hyun Lee und Hyun Sik Jo. „A Study on the Power Generation Prediction Model Considering Environmental Characteristics of Floating Photovoltaic System“. Applied Sciences 10, Nr. 13 (29.06.2020): 4526. http://dx.doi.org/10.3390/app10134526.
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The main contents of this paper are to verify the environmental factors affecting the power generation of floating photovoltaic systems and to present the power generation prediction model considering environmental factors by using regression analysis and neural networks studied during the last decade. This study focused on a comparative analysis of which model is best suited for the power generation prediction of the floating photovoltaic (PV) system. To compare the power generation characteristics of a floating and a land-based PV system, two identical 2.5 kW PV systems were installed—one on the water surface in the Boryeong Dam, Korea, and the other nearby on dry land—and their performances were compared. The solar irradiance of the floating PV system was 1.1% lower than that of the land-based PV. Nevertheless, the floating PV module temperature was 4.9% lower than that of the land-based PV, generating approximately 3% more power. Using the correlation analysis of data mining techniques, environmental factors affecting the efficiency of the floating PV system were investigated. The correlation coefficient between the module temperature and water temperature was r = 0.6317 which proves that the high efficiency and low module temperature characteristics of the floating PV system, when compared with that of the land-based PV, are due to the water evaporation effect. Considering environmental factors, power-generation prediction models based on regression analysis and neural networks are presented, and their accuracies are compared. This comparison confirms that the accuracy of the power generation prediction model using neural networks was approximately 2.59% higher than that of the regression analysis method. As a result of adjusting the hidden nodes in the neural network algorithm, it was confirmed that a neural network algorithm with ten hidden nodes was most suitable for calculating the amount of power generation.
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Alsafasfeh, Qais. „An Efficient Algorithm for Power Prediction in PV Generation System“. International Journal of Renewable Energy Development 9, Nr. 2 (15.04.2020): 207–16. http://dx.doi.org/10.14710/ijred.9.2.207-216.
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Aiming at the existing photovoltaic power generation prediction methods, the modeling is complicated, the prediction accuracy is low, and it is difficult to meet the actual needs. Based on the improvement of the traditional wavelet neural network, a dual-mode cuckoo search wavelet neural network algorithm combined prediction method is proposed, which takes into account the extraction of chaotic features of surface solar radiation and photovoltaic output power. The proposed algorithm first reconstructs the chaotic phase space of the hidden information of each influencing factor in the data history of PV generation and according to the correlation analysis, the solar radiation is utilized as additional input. Next, the proposed algorithm overcomes the limitations of the cuckoo search algorithm such as the sensitivity to the initial value and searchability and convergence speed by dual-mode cuckoo search wavelet neural network algorithm. Lastly, a prediction model of the proposed algorithm is proposed and the prediction analysis is performed under different weather conditions. Simulation results show that the proposed algorithm shows better performance than the existing algorithms under different weather conditions. Under various weather conditions, the mean values of TIC, EMAE and ENRMSE error indicators of the proposed forecasting algorithm were reduced by 43.70%, 45.75%, and 45.41%, respectively. Compared with the Chaos-WNN prediction method, the prediction performance has been further improved under various weather conditions and the mean values of TIC, EMAE and ENRMSE error indicators have been reduced by 25.55%, 27.26%, and 36.83%, respectively. ©2020. CBIORE-IJRED. All rights reserved
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Adeiah James, Penrose Cofie, Anthony Hill, Olatunde Adeoye, Pam Obiomon, Charles Tolliver und Justin Foreman. „Alleviating power line congestion through the use of a renewable generation“. World Journal of Advanced Engineering Technology and Sciences 7, Nr. 2 (30.11.2022): 013–28. http://dx.doi.org/10.30574/wjaets.2022.7.2.0117.
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Over the past few decades, there has been an ever-increasing penetration of Renewable Energy Generation in the power grid. However, unlike in the past, where fossil fuel generating plants are mostly located in remote areas, and in the proximity of the source of energy, the most common of the renewable generations, such as solar power systems, are haphazardly sited close to the loads because the source of energy, the sun, exists almost everywhere. This unplanned siting of renewable generating systems aggravates the power distribution lines congestion that already exists due to the power distribution deregulation. This paper presents a procedure that takes advantage of utilization and proper placement of Photovoltaic (PV) power systems to alleviate power line congestion. In this procedure, the base case load flow, without the solar generating system, is performed on the distribution network. And the bus with the lowest voltage is identified; this low voltage bus is indicative of congestion in the lines connecting the identified bus. A PV power system is then tied to that bus; the capacity of the PV generation is varied heuristically to determine the optimality that mitigates the congestion on the lines. The procedure is followed to test a 9-bus IEEE power system, and the results are presented.
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Wynn, Sane Lei Lei, Terapong Boonraksa, Promphak Boonraksa, Watcharakorn Pinthurat und Boonruang Marungsri. „Decentralized Energy Management System in Microgrid Considering Uncertainty and Demand Response“. Electronics 12, Nr. 1 (03.01.2023): 237. http://dx.doi.org/10.3390/electronics12010237.
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Smart energy management and control systems can improve the efficient use of electricity and maintain the balance between supply and demand. This paper proposes the modeling of a decentralized energy management system (EMS) to reduce system operation costs under renewable generation and load uncertainties. There are three stages of the proposed strategy. First, this paper applies an autoregressive moving average (ARMA) model for forecasting PV and wind generations as well as power demand. Second, an optimal generation scheduling process is designed to minimize system operating costs. The well-known algorithm of particle swarm optimization (PSO) is applied to provide optimal generation scheduling among PV and WT generation systems, fuel-based generation units, and the required power from the main grid. Third, a demand response (DR) program is introduced to shift flexible load in the microgrid system to achieve an active management system. Simulation results demonstrate the performance of the proposed method using forecast data for hourly PV and WT generations and a load profile. The simulation results show that the optimal generation scheduling can minimize the operating cost under the worst-case uncertainty. The load-shifting demand response reduced peak load by 4.3% and filled the valley load by 5% in the microgrid system. The proposed optimal scheduling system provides the minimum total operation cost with a load-shifting demand response framework.
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Herez, Amal, Hassan Jaber, Hicham El Hage, Thierry Lemenand, Mohamad Ramadan und Mahmoud Khaled. „A review on the classifications and applications of solar photovoltaic technology“. AIMS Energy 11, Nr. 6 (2023): 1102–30. http://dx.doi.org/10.3934/energy.2023051.
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<abstract> <p>Our aim of this work is to present a review of solar photovoltaic (PV) systems and technologies. The principle of functioning of a PV system and its major components are first discussed. The types of PV systems are described regarding the connections and characteristics of each type. PV technology generations are demonstrated, including the types, properties, advantages and barriers of each generation. It was revealed that the first generation is the oldest among the three PV generations and the most commonly utilized due to its high efficiency in spite the high cost and complex fabrication process of silicon; the second generation is characterized by its low efficiency and cost and flexibility compared to other generations; and the third generation is not commercially proven yet in spite the fact that it has the highest efficiency and relatively low cost, its raw materials are easy to find and its fabrication process is easier than the other generations. It was shown that the target of all the conducted studies is to study the PV technology to enhance its performance and optimize the benefit from solar energy by reducing conventional energy dependence, mitigating CO<sub>2</sub> emissions and promote the economic performance.</p> </abstract>
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Han, Xian Sui, und Qi Hui Liu. „Modeling and Simulation of Grid-Connected Photovoltaic System Based on PSCAD“. Advanced Materials Research 986-987 (Juli 2014): 367–70. http://dx.doi.org/10.4028/www.scientific.net/amr.986-987.367.
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In order to investigate the impacts of large scale PV power plants on the stability of power system, dynamic PV models are of particular interest to the industry for simulating large-scale power systems. The transient model of large scale grid-connected PV generation system was given based on the model of each component of PV generation system. Response of the model was simulated respectively when the illumination changes. The methods proposed could be applied to the power grid with photovoltaic generation integration.
Dissertationen zum Thema "PV GENERATION SYSTEM"
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Makki, Adham. „Innovative heat pipe-based photovoltaic/thermoelectric (PV/TEG) generation system“. Thesis, University of Nottingham, 2017. http://eprints.nottingham.ac.uk/43330/.
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PV systems in practice experience excessive thermal energy dissipation that is inseparable from the photo-electric conversion process. The temperature of PV cells under continuous illumination can approach 40°C above ambient, causing a drop in the electrical performance of about 30%. The significance of elevated temperature on PV cells inspired various thermal management techniques to improve the operating temperature of the cells and hence their conversion efficiency. Hybrid PV/Thermal (PV/T) collectors that can supply both electrical and thermal energy are attractive twofold solution, being able to cool the PV cells and thus improving the electrical power output as well as collecting the thermal energy by-product for practical utilization. The challenges present on the performance of PV systems due to elevated operating temperature is considered the research problem within this work. In this research, an integrated hybrid heat pipe-based PV/Thermoelectric (PV/TEG) collector is proposed and investigated theoretically and experimentally. The hybrid collector considers modular integration of a PV absorber rated at 170W with surface area of 1.3 m2 serving as power generator as well as thermal absorber. Five heat pipes serving as the heat transport mediums were attached to the rear of the module to extract excessive heat accumulating on the PV cells. The extracted heat is transferred via boiling-condensation cycle within the heat pipe to a bank of TEG modules consisting of five 40 mm x 40 mm modules, each attached to the condenser section of each heat pipe. In principle, the incorporation of heat pipe-TEG thermal waste recovery assembly allow further power generation adopting the Seebeck phenomena of Thermoelectric modules. A theoretical numerical analysis of the collector proposed is conducted through derivation of differential equations for the energy exchange within the system components based on energy balance concepts while applying explicit finite difference numerical approach for solutions. The models developed are integrated into MATLAB/SIMULINK environment to assess the cooling capability of the integrated collector as well as the addition power generation through thermal waste heat recovery. The practical performance of the collector proposed is determined experimentally allowing for validation of the simulation model, hence, a testing rig is constructed based on the system requirements and operating principles. Reduction in the PV cell temperature of about 8°C, which account for about 16% reduction in the PV cell temperature response compared to a conventional PV module under identical conditions is attained. In terms of the power output available from the PV cells, enhanced power performance of additional 5.8W is observed, contributing to an increase of 4% when compared with a PV module. The overall energy conversion efficiency of the integrated collector was observed to be steady at about 11% compared to that of the conventional PV module (9.5%) even at high ambient temperature and low wind speeds. Parametric analysis to assess the performance enhancements associated to the number of heat pipes attached to the PV module is conducted. Increasing the number of heat pipes attached to 15 pipes permits improved thermal management of the PV cells realised by further 7.5% reduction in the PV module temperature in addition to electrical output power improvement of 5%.
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Carr, Anna J. „A detailed performance comparison of PV modules of different technologies and the implications for PV system design methods /“. Access via Murdoch University Digital Theses Project, 2005. http://wwwlib.murdoch.edu.au/adt/browse/view/adt-MU20050830.94641.
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Simhadri, Arvind. „Impact of distributed generation of solar photovoltaic (PV) generation on the Massachusetts transmission system“. Thesis, Massachusetts Institute of Technology, 2015. http://hdl.handle.net/1721.1/98604.
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Thesis: S.M., Massachusetts Institute of Technology, Engineering Systems Division, 2015. In conjunction with the Leaders for Global Operations Program at MIT.Thesis: M.B.A., Massachusetts Institute of Technology, Sloan School of Management, 2015. In conjunction with the Leaders for Global Operations Program at MIT.
Cataloged from PDF version of thesis.
Includes bibliographical references (pages 73-76).
After reaching 250 megawatt direct current (MW dc) of solar photovoltaic (PV) generation installed in Massachusetts (MA) in 2013, four years ahead of schedule, Governor Deval Patrick in May of 2013 announced an increase in the MA solar PV goal to 1,600 MW by 2020 ([13]). However, integration of such significant quantities of solar PV into the electric power system is potentially going to require changes to the transmission system planning and operations to ensure continued reliability of operation ([14]). The objective of this project is to predict the distribution of solar PV in MA and to develop a simulation framework to analyze the impact of solar generation on the electric power system. To accomplish this objective, we first developed a prediction model for solar PV aggregate and spatial long term distribution. We collected solar PV installation data and electricity consumption data for 2004 to 2014 for each ZIP code in MA. Additional information such as population, land availability, average solar radiance, number of households, and other demographic data per ZIP code was also added to improve the accuracy of the model. For example, ZIP codes with higher solar radiance are more likely to have solar PV installations. By utilizing machine learning methods, we developed a model that incorporates demographic factors and applies a logistic growth model to forecast the capacity of solar PV generation per ZIP code. Next we developed an electrically equivalent model to represent the predicted addition of solar PV on the transmission system. Using this model, we analyzed the impact of solar PV installations on steady-state voltage of the interconnected electric transmission system. We used Siemens PTI's PSS/E software for transmission network modeling and analysis. Additionally, we conducted a sensitivity analysis on scenarios such as peak and light electricity consumption period, different locations of solar PV, and voltage control methods to identify potential reliability concerns. Furthermore, we tested the system reliability in the event of outages of key transmission lines, using N-1 contingency analysis. The analysis identified that the voltage deviation on transmission system because of adding 1,600 MW dc of distributed solar PV is within +/- 5% range. Based on the analysis performed in this thesis, we conclude that the current MA transmission system can operate reliably after the addition of the expected 1,600 MW dc of solar PV. As National Grid acquires information on solar installations, new data will improve the ability and accuracy of the prediction model to predict solar PV capacity and location more accurately. The simulation framework developed in this thesis can be utilized to rerun the analysis to test the robustness of the electric transmission system at a future date.
by Arvind Simhadri.
S.M.
M.B.A.
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Ahmed-Mahmoud, Ashraf. „Power conditioning unit for small scale hybrid PV-wind generation system“. Thesis, Durham University, 2011. http://etheses.dur.ac.uk/580/.
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Small-scale renewable energy systems are becoming increasingly popular due to soaring fuel prices and due to technological advancements which reduce the cost of manufacturing. Solar and wind energies, among other renewable energy sources, are the most available ones globally. The hybrid photovoltaic (PV) and wind power system has a higher capability to deliver continuous power with reduced energy storage requirements and therefore results in better utilization of power conversion and control equipment than either of the individual sources. Power conditioning units (p.c.u.) for such small-scale hybrid PV-wind generation systems have been proposed in this study. The system was connected to the grid, but it could also operate in standalone mode if the grid was unavailable. The system contains a local controller for every energy source and the grid inverter. Besides, it contains the supervisory controller. For the wind generator side, small-scale vertical axis wind turbines (VAWTs) are attractive due to their ability to capture wind from different directions without using a yaw. One difficulty with VAWTs is to prevent over-speeding and component over-loading at excessive wind velocities. The proposed local controller for the wind generator is based on the current and voltage measured on the dc side of the rectifier connected to the permanent magnet synchronous generator (PMSG). Maximum power point tracking (MPPT) control is provided in normal operation under the rated speed using a dc/dc boost converter. For high wind velocities, the suggested local controller controls the electric power in order to operate the turbine in the stall region. This high wind velocity control strategy attenuates the stress in the system while it smoothes the power generated. It is shown that the controller is able to stabilize the nonlinear system using an adaptive current feedback loop. Simulation and experimental results are presented. The PV generator side controller is designed to work in systems with multiple energy sources, such as those studied in this thesis. One of the most widely used methods to maximize the output PV power is the hill climbing technique. This study gives guidelines for designing both the perturbation magnitude and the time interval between consecutive perturbations for such a technique. These guidelines would improve the maximum power point tracking efficiency. According to these guidelines, a variable step MPPT algorithm with reduced power mode is designed and applied to the system. The algorithm is validated by simulation and experimental results. A single phase H-bridge inverter is proposed to supply the load and to connect the grid. Generally, a current controller injects active power with a controlled power factor and constant dc link voltage in the grid connected mode. However, in the standalone mode, it injects active power with constant ac output voltage and a power factor which depends on the load. The current controller for both modes is based on a newly developed peak current control (p.c.c.) with selective harmonic elimination. A design procedure has been proposed for the controller. Then, the method was demonstrated by simulation. The problem of the dc current injection to the grid has been investigated for such inverters. The causes of dc current injection are analyzed, and a measurement circuit is then proposed to control the inverter for dc current injection elimination. Characteristics of the proposed method are demonstrated, using simulation and experimental results. At the final stage of the study, a supervisory controller is demonstrated, which manages the different operating states of the system during starting, grid-connected and standalone modes. The operating states, designed for every mode, have been defined in such a hybrid model to allow stability and smooth transition between these states. The supervisory controller switches the system between the different modes and states according to the availability of the utility grid, renewable energy generators, the state of charge (SOC) of energy storage batteries, and the load. The p.c.u. including the supervisory controller has been verified in the different modes and states by simulation.
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Deng, Wenpeng. „A solar PV-LED lighting system with bidirectional grid ballasting“. Thesis, University of Cambridge, 2015. https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.709190.
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SONG, CONGCONG. „Electricity generation from hybrid PV-wind-bio-mass system for rural application in Brazil“. Thesis, KTH, Energiteknik, 2017. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-211794.
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Electrification of households in rural area and isolated regions plays a significant impact on the balanced economic development. Brazil grows with a high population growth rate, but still parts of rural area and isolated regions do not have the accessibility of electric power. This study focuses on the feasibility study of a hybrid PV-wind-biomass power system for rural electrification at Nazaré Paulista in southeast Brazil. This study was performed by using the hybrid renewable energy system software HOMER. The wind and solar data was collected from Surface meteorology and Solar Energy-NASA, and the biomass data was collected and estimated from other previous studies. The result shows, the hybrid PV-wind-biomass renewable system can meet 1,601 kWh daily demands and 360 kW peak load of the selected rural area. The power system composed of 200 kW PV panels, 200 kW biomass generator, 400 battery banks, and 200 kW converter. All the calculations were performed by Homer and the selection were based on the Net Present Cost (NPC) and Levelized cost of energy (COE). Because of the fossil fuels’ negative impacts on human health and environment, all the energy sources for this system are renewable energies which have less pollution.
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Agalgaonkar, Yashodhan Prakash. „Control and operation of power distribution system for optimal accommodation of PV generation“. Thesis, Imperial College London, 2014. http://hdl.handle.net/10044/1/24954.
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The renewable policies in various countries are driving significant growth of grid connected renewable generation sources such as the Photovoltaics (PVs). Typically a PV generation is integrated into power systems at the low and the medium voltage distribution level. The uptake of an intermittent power from the PVs is challenging the power system operation and control. The network voltage control is one of the major challenges during the operation of the distribution connected PVs. The active power injection from a PV plant causes variable voltage rise. This forces the existing voltage control devices such as on-load tap-changer (OLTC) and voltage regulator (VR) to operate continuously. The consequence is the reduction of the operating life of the voltage control mechanism. Also, the conventional non-coordinated reactive power control results in the operation of the VR at its control limit (VR runaway condition). This research focuses on the distribution voltage control in the presence of PV generation and helps to establish detailed insights into the various associated challenges. Firstly, the typical grid integrated PV topologies are discussed. The existing power system operational practices are presented and their limitations are identified. A voltage control methodology to tackle challenges such as over-voltage, excessive tap counts and VR runaway is presented. These challenges are alleviated through the coordinated reactive power control. The reactive power coordination is achieved through the deterministic distribution optimal power flow solved through the interior point technique. The irradiance and the load forecasting errors are another set of challenges from the distribution network operators' perspective. The stochastic optimal voltage control strategy is proposed to tackle the element of randomness associated with the forecast errors. The stochastic operational risks such as an over- voltage and a VR runaway are defined through a chance constrained optimization problem. The simulation study is performed using a realistic 95-bus UK generic distribution network model and a practically measured irradiance to demonstrate the effectiveness of the proposed control strategies. The thesis makes an effort to offer an insight into the operational challenges and propose strategies to achieve a seamless integration of the PVs into the power systems.
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Sahoo, Smrutirekha. „Impact Study: Photo-voltaic Distributed Generation on Power System“. Thesis, Mälardalens högskola, Akademin för ekonomi, samhälle och teknik, 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:mdh:diva-32369.
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The grid-connected photo-voltaic (PV) system is one of the most promising renewable energy solutions which offers many benefits to both the end user and the utility network and thus it has gained the popularity over the last few decades. However, due to the very nature of its invariability and weather dependencies, the large scale integration of this type of distributed generation has created challenges for the network operator while maintaining the quality of the power supply and also for reliable and safe operations of the grids. In this study, the behavioral impact of large scale PV system integration which are both steady and dynamic in nature was studied. An aggregate PV model suited to study the impacts was built using MATLAB/Simulink. The integration impacts of PV power to existing grids were studied with focus on the low voltage residential distribution grids of Mälarenergi Elnät AB (10/0.4 kV). The steady state impacts were related to voltage profile, network loss. It was found that the PV generation at the load end undisputedly improves the voltage profile of the grid especially for the load buses which are situated at farther end of the grid. Further, with regard to the overvoltage issue, which is generally a concern during the low load demand period it was concluded that, at a 50% PV penetration level, the voltage level for the load buses is within the limit of 103% as prescribed by the regulator excepting for few load buses. The voltage level for load buses which deviate from the regulatory requirement are located at distance of 1200 meter or further away from the substation. The dynamic impact studied were for voltage unbalancing in the grid, which was found to have greater impact at the load buses which is located farther compared to a bus located nearer to the substation. With respect to impact study related to introduction of harmonics to the grid due to PV system integration, it was found that amount of harmonic content which was measured as total harmonic distortion (THD) multiplies with integration of more number of PV system. For a 50 % penetration level of PV, the introduced harmonics into the representative network is very minimal. Also, it was observed from the simulation study that THD content are be less when the grid operates at low load condition with high solar irradiance compared to lower irradiance and high load condition.
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Abdalla, Imadeddin Abdalla. „Integrated PV and multilevel converter system for maximum power generation under partial shading conditions“. Thesis, University of Leeds, 2013. http://etheses.whiterose.ac.uk/4603/.
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The emerging trend towards the harnessing of the electrical power from solar energy has increased the research effort in power electronics applications. To achieve the required voltage level, a number of photovoltaic PV sources (cells/modules) are connected in series. The major challenge here is to deal with the partial shading problem, where the series connected PV sources are exposed to different insolation. The generated current is limited by the current of the shaded PV sources unless those sources are bypassed by diodes, in which case the total DC voltage is reduced and the shaded sources do not contribute to the generated output power. A power electronics approach can be employed to overcome the problem, by enabling both shaded and non-shaded sources to generate their maximum power, thereby and delivering the total generated power to the load. Thus no shaded PV source is bypassed or degrades the power extraction from the other PV sources. This thesis investigates the PV partial shading problem of individual PV sources which are connected in series. After the review and evaluation of existing methods to overcome this problem, the thesis employs for the first time the multilevel DC-Link inverter to deal with the problem of partial shading by using a novel control algorithm called PV permutation algorithm. The thesis also develops a simplified generalized Integration PWM (IPWM) algorithm which can be used to control higher level inverters. An improved maximum power point algorithm “voltage-hold perturbation and observation (VH-P&O)”, which overcomes the major tracking limitations, is developed from the basic P&O algorithm. Experimental systems of five and seven level DC-link inverters with a DC-DC buck converter system have been implemented. The digital processing unit eZdspTM F28335 is used to control the PV systems in real time, and Matlab-Simulink Real Time Data Exchange (RTDX) is employed to display the extracted power and to control the system parameters via a designed Graphical User Interface (GUI) window. The simulation and experimental results showed that the series connected PV sources operate at their maximum power points under partial shading conditions without affecting each other.
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VERMA, PALLAVI. „CONTROL OF SOLAR PV SYSTEM BASED MICROGRID FOR ENHANCED PERFORMANCE“. Thesis, DELHI TECHNOLOGICAL UNIVERSITY, 2021. http://dspace.dtu.ac.in:8080/jspui/handle/repository/18879.
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With the depletion of non-renewable resources and growing public awareness about the
advantages of green energy, alternative renewable sources are evolving as a significant
source of energy since past few years. Furthermore, the electrical grid is on the verge
of a paradigm shift, from centralized power generation, transmission, and huge power
grids towards distributed generation (DG). DG fundamentally uses small-scale
generators like photovoltaic (PV) panels, wind turbine, fuel cells, small and micro
hydropower, diesel generator set, etc., and is limited to small distribution networks to
produce power close to the end users. Renewable energy sources (RES) are essential
components of DG because they are more environment friendly than conventional
power generators and once established maintenance cost is also low. One of the most
popular renewable energy source is solar energy because it is abundant, accessible and
can be easily converted into electricity. The electricity produced from SPV system can
be utilized by the local loads within the microgrid or it can be integrated with
conventional grid.
Microgrid (MG), which is a cluster of distributed generation, renewable sources, and
local loads connected to the utility grid provides solution to manage local generations
and loads as a single grid level entity. It has the potential to maximize overall system
efficiency, power quality, and energy surety for critical loads. A microgrid can operate
either in stand-alone mode or grid connected mode. Due to abundant availability of
solar energy, an SPV based microgrid is widely used around the world. Due to
intermittent nature of solar energy, stand-alone SPV based microgrid needs an energy
storage system also, whereas in grid connected system, the microgrid is connected to
conventional grid which takes care of the solar intermittency by having bi-directional
flow of power. Depending on the technical specifications, grid-connected solar PV-
based microgrid can be single-stage or double-stage. In single stage configuration, PV
array is directly connected to a DC/AC converter whereas in double-stage
configuration, DC/DC converter is coupled in between the solar PV array and PV
inverter and provides the desired fixed DC voltage to the inverter.
The present work aims at modelling, design, development and control of a solar PV
vii
based microgrid for enhanced performance. Also, the characterization studies of the
developed system have been carried out. Modeling of the system is required in order to
predict its behaviour under both steady and dynamic states. Characterization studies
such as sensitivity and reliability analysis are used to evaluate the performance of the
system. Sensitivity analysis is the performance evaluation technique for evaluating the
change in the system’s performance with respect to the change in its parameters. The
sensitivity functions for solar cell and boost converter with respect to influential
parameters have been developed using first derivative of Taylor’s series. Reliability
analysis for electrical and electronic components of the system have been performed
using pareto analysis and reliability model of the PV based microgrid has been
developed using reliability block diagram for different PV array configurations. The
Fault tree analysis (FTA) model of the system has been developed to find the cause of
failure and to step the events leading to failure serially. Further, Markov’s model has
been used to develop the reliability functions of individual components and hence, the
reliability of complete grid connected PV system has been calculated.
Solar PV system gives maximum power under uniform shading. But many a times PV
panels are non-uniformly irradiated and this condition is known as called partial
shading condition (PSC). PSC occur due to shadow of big trees, nearby buildings and
dense clouds etc. PSC in PV system is an inevasible situation and exhibits multiple
peaks, consisting of a single global maximum power point and many local maximum
power points, in its power-voltage curve. PSC makes tracking of global maximum
power point more difficult and also reduces the efficiency of the system. The
conventional MPPT control algorithms work well under uniform shading condition but
under partial shading scenario, they may not be able to track global peak out of multiple
peaks. Therefore, an efficient controller is required to overcome the raised issue.
Further, various PV array configurations such as series, series-parallel, total cross tied,
bridge linked etc. may be used to improve the system efficiency. In the present work,
novel maximum power point control algorithms viz. an asymmetrical fuzzy logic
control (AFLC) and asymmetrical interval type-2 FLC (AIT-2 FLC) are developed for
stand-alone PV system under partial shading condition. The developed algorithms are
tested for different PV array configurations.
viii
In stand-alone PV system, the power supplied to the load depends upon the available
solar energy. The output of SPV is intermittent in nature as it depends on the
environmental conditions. This intermittency problem can be addressed by adding an
energy storage system along with PV system. Battery is the most commonly used
energy storage device and is very pivotal in maintaining continuity of power to the load.
But when two or more energy sources are connected, then control of dc link voltage at
common coupling point (CCP) is an area of concern. Therefore, in a SPV system with
BESS a controller is required which can maintain constant DC link voltage irrespective
of system transients. The PI controller is commonly used controller for controlling dc-
link voltage, but it cannot regulate DC-link voltage under dynamic operating conditions
and have overshoots and long settling time in its response. Suitable intelligent
controllers are designed to replace the conventional PI controller, as they provide a
better transient response. In order to overcome the drawbacks of the conventional PI
control algorithm, nonlinear autoregressive moving average-L2 (NARMA-L2) control
algorithm is proposed and developed for the stand-alone PV system with BESS. The
proposed control scheme maintains the voltage across DC-link under change in
irradiation and load condition.
In a grid connected SPV based microgrid, the output of boost converter i.e., DC link is
connected to voltage source inverter which is connected to grid at the point of common
coupling (PCC). Voltage source inverter converts the generated DC power from PV
system to AC of required voltage and frequency, as well as maintains the balance of
power between the SPV system, load, and grid. The inverter is regulated by the
interfacing controllers for effective operation and grid synchronization. The interfacing
controllers are used to control the output of PV inverter for its efficient utilization and
for improving power quality at PCC by providing reactive power compensation,
harmonics compensation and load balancing. Conventional control algorithm like
synchronous reference frame theory (SRFT) uses proportional integral (PI) controller
for DC-link voltage regulation. These controllers are not best suited for SPV based
microgrid as the overshoots and long settling time in their response are inevitable. In
order to overcome this, novel smooth Least Mean Square (SLMS), improved zero
attracting LMS (IZALMS) and reweighted L0 norm variable step size continuous mixed
p-norm (RL0-VSSCMPN) based adaptive interfacing control algorithms are proposed
ix
and developed for the PV based microgrid. The efficacy of the proposed control
algorithms has been tested on hardware prototype developed in the laboratory using
MicroLab box (dSPACE 1202). The developed prototype system acts as distribution
static compensator (DSTATCOM) and consists of inverter that is tied in parallel to the
grid at the point of common coupling. FLUKE power analyzer has been used to measure
the response of the system.
The research work presented in the thesis is expected to provide good exposure to
design, development and control of the solar PV based microgrid.
Bücher zum Thema "PV GENERATION SYSTEM"
1
Coddington, Michael H. Updating interconnection screens for PV system integration. Golden, CO: National Renewable Energy Laboratory, 2012.
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Goodrich, Alan C. Solar PV manufacturing cost model group: Installed solar PV system prices. Golden, Colo.]: National Renewable Energy Laboratory, 2011.
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3
Emery, K. Monitoring system performance: Venue: PV Module Reliability Workshop. Golden, Colo.]: National Renewable Energy Laboratory, 2011.
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Coddington, Michael H. Solutions for deploying PV systems in New York City's secondary network system. Golden, Colo.]: National Renewable Energy Laboratory, 2010.
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5
Hacke, Peter. System voltage potential-induced degradation mechanisms in PV modules and methods for test: Preprint. Golden, CO]: National Renewable Energy Laboratory, 2011.
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(Organization), IT Power, Hrsg. Solar photovoltaic power generation using PV technology. [Manila?]: Asian Development Bank, 1996.
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Lowder, Travis. The potential of securitization in solar PV finance. Golden, CO: National Renewable Energy Laboratory, 2013.
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8
National Renewable Energy Laboratory (U.S.), Hrsg. Future of grid-tied PV business models: What will happen when PV penetration on the distribution grid is significant? : preprint. Golden, CO: National Renewable Energy Laboratory, 2008.
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9
Munro, Donna. Trends in PV power applications in selected IEA countries between 1992 and 1997\. Paris: International Energy Agency, 1998.
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Goodrich, Alan C. Solar PV manufacturing cost analysis: U.S. competitiveness in a global industry. Golden, Colo.]: National Renewable Energy Laboratory, 2011.
Den vollen Inhalt der Quelle findenBuchteile zum Thema "PV GENERATION SYSTEM"
1
Mwango, Manish, Yugvansh Shrey, Harpreet Singh Bedi und Javed Dhillon. „PV System Design and Solar Generation Implementation“. In Studies in Infrastructure and Control, 63–69. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-19-8963-6_6.
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2
Mandi, Rajashekar P. „Solar PV System with Energy Storage and Diesel Generator“. In Handbook of Distributed Generation, 749–90. Cham: Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-51343-0_22.
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3
Shadoul, Myada, Hassan Yousef, Rashid Al-Abri und Amer Al-Hinai. „Intelligent Control Design for PV Grid-Connected Inverter“. In Energy Management System for Dispatchable Renewable Power Generation, 79–118. Boca Raton: CRC Press, 2022. http://dx.doi.org/10.1201/9781003307433-3.
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4
Sudhakar, T. D., K. N. Srinivas, M. Mohana Krishnan und R. Raja Prabu. „Design and Analysis of Grid Connected PV Generation System“. In Proceedings of 2nd International Conference on Intelligent Computing and Applications, 413–22. Singapore: Springer Singapore, 2016. http://dx.doi.org/10.1007/978-981-10-1645-5_35.
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Hu, Xuefeng, Zikang Long, Chenjin Fei, Zhenhai Yu und Kunshu Mu. „An Integrated Boost Micro-inverter for PV Generation System“. In Lecture Notes in Electrical Engineering, 708–15. Singapore: Springer Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-1528-4_72.
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Priyadarshi, Neeraj, Kavita Yadav, Vinod Kumar und Monika Vardia. „An Experimental Study on Zeta Buck–Boost Converter for Application in PV System“. In Handbook of Distributed Generation, 393–406. Cham: Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-51343-0_13.
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Karthik, M., und N. Divya. „Assessment of different MPPT techniques for PV system“. In Machine Learning and the Internet of Things in Solar Power Generation, 157–72. Boca Raton: CRC Press, 2023. http://dx.doi.org/10.1201/9781003302964-9.
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Panigrahi, Basanta K., Anshuman Bhuyan, Arpan K. Satapathy, Ruturaj Pattanayak und Bhagyashree Parija. „Fault Analysis of Grid Connected Wind/PV Distributed Generation System“. In ICICCT 2019 – System Reliability, Quality Control, Safety, Maintenance and Management, 47–54. Singapore: Springer Singapore, 2019. http://dx.doi.org/10.1007/978-981-13-8461-5_6.
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Prajapati, Sandhya, und Eugene Fernandez. „Fuzzy Model for Efficiency Estimation of Solar PV Based Hydrogen Generation Electrolyser“. In Control Applications in Modern Power System, 251–60. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-8815-0_22.
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Mansouri, Nouha, Chokri Bouchoucha und Adnen Cherif. „Modeling and Simulation of Renewable Generation System: Tunisia Grid Connected PV System Case Study“. In Proceedings of the 1st International Conference on Smart Innovation, Ergonomics and Applied Human Factors (SEAHF), 316–22. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-22964-1_36.
Der volle Inhalt der QuelleKonferenzberichte zum Thema "PV GENERATION SYSTEM"
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Bhat, Rajatha, Miroslav Begovic, Insu Kim und John Crittenden. „Effects of PV on Conventional Generation“. In 2014 47th Hawaii International Conference on System Sciences (HICSS). IEEE, 2014. http://dx.doi.org/10.1109/hicss.2014.299.
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2
Chen, C. S., C. H. Lin, W. L. Hsieh, C. T. Hsu und T. T. Ku. „Advanced distribution automation system for control of PV inverters to enhance PV penetration“. In 2013 2nd International Symposium on Next-Generation Electronics (ISNE 2013). IEEE, 2013. http://dx.doi.org/10.1109/isne.2013.6512406.
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3
da Rocha, N. M., J. C. Passos, D. C. Martins und R. F. Coelho. „Suggestion of Associating a PV MPPT Algorithm Based on Temperature Control with a PV Cooling System“. In 3rd Renewable Power Generation Conference (RPG 2014). Institution of Engineering and Technology, 2014. http://dx.doi.org/10.1049/cp.2014.0890.
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Chen, Lei, Fan Wu, Zhang Sun, Jun Wang, Xiaoyan Han und Gang Chen. „An new method of PV generation fluctuation suppression for cascade hydro-pv-pumped storage generation system“. In 2019 IEEE Innovative Smart Grid Technologies - Asia (ISGT Asia). IEEE, 2019. http://dx.doi.org/10.1109/isgt-asia.2019.8881429.
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Lilly, Patrick, und George Simons. „California’s Self-Generation Incentive Program Nonresidential PV Systems: Measured System Performance and Actual Costs“. In ASME 2006 Power Conference. ASMEDC, 2006. http://dx.doi.org/10.1115/power2006-88228.
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More than two hundred sixty grid-tied photovoltaic (PV) systems sized 30 kW to 1.1 MW installed in California during 2002 through 2004 received partial funding through the Self-Generation Incentive Program (SGIP). The SGIP is administered statewide by PG&E, SCE, SoCalGas, and the San Diego Regional Energy Office. The incentive is structured as a one-time capacity based payment made at the time of system completion. The first PV system incentive was paid in Summer 2002. Through the end of 2004, a total of 269 PV systems had received financial support through the program. The cumulative generation capacity of these systems exceeded 30 MW and corresponded to $101 million of incentives paid. While originally slated to run through 2004, recently the program was modified and extended through the end of 2007. PV systems participating in the program are being monitored to support evaluation of the program. These data have been used to assess impacts of the Program on peak demand and energy consumption. These data have also been incorporated into the Program’s cost-effectiveness assessment. Well over one-half of the PV systems have already been subject to metering yielding 15-minute interval generator output data. The cumulative size of the directly monitored PV systems currently exceeds 33 MW as of late 2005. In 2004, the statewide California Independent System Operator (ISO) electrical system peak occurred on September 8 during the 16th hour (from 3 to 4 PM PDT). During this hour the electrical demand for the California ISO reached 45,562 MW. On this day, there were 235 PV systems funded under the SGIP installed and operating; interval-metered data are available for 107 of these projects. The resulting estimate of peak demand impact coincident with the ISO peak load totals 9,938 kW. The estimated peak demand impact corresponds to 0.39 kW per 1.0 kWRebated of PV system size and is based on rebated capacity. Those unfamiliar with PV system size ratings and PV system operating characteristics may be surprised that the overall weighted-average peak demand impact was not substantially higher at this hour and time of year. To help put this result in perspective, it can be compared to a simple engineering estimate of peak power output based on published information regarding PV system performance. First, we begin with 1 kW [basis: rebated size] of horizontal PV system capacity. For purposes of determining rebates, PV system sizes are calculated as the product of cumulative estimated module DC power output under PTC conditions and inverter maximum DC to AC conversion efficiency. Factors such as manufacturing tolerance, soiling, module mismatch, temperature effects, and wiring losses may result in actual full-sun power output levels of about 0.76 kW/kWRebated. When the 3 to 4 PM angle of incidence effects for the month of September are included the expected output value drops significantly further. The peak-day operating characteristics of the 107 PV projects for which peak-day interval-metered data were available are summarized in the box plot of Figure 4. System sizes were used to normalize power output values prior to plotting summary statistics of PV output profiles for individual projects. The normalized values represent PV power output per unit of system size. Treatment in this manner enables direct comparison of the power output characteristics of PV systems of varying sizes. The vertically oriented boxes represent ranges within which 75% of project-specific values lie. The vertical lines represent the total range (i.e., maximum and minimum) of project-specific values. The energy production of the group of metered PV systems varied according to season. In Figure 7, normalized energy production by month is illustrated (on the right axis). These values represent the monthly average capacity factor for the on-line PV system capacity. As expected, normalized energy production levels reach their maximum values in the summer season and decrease towards the winter season as the intensity and duration of incident solar radiation falls off, coupled with increased incidence of storms and other weather disturbances off the Pacific Ocean, which affect the availability of solar radiation upon the PV modules.
6
Natsheh, E. M., E. J. Blackhurs und A. Albarbar. „PV system monitoring and performance of a grid connected PV power station located in Manchester-UK“. In IET Conference on Renewable Power Generation (RPG 2011). IET, 2011. http://dx.doi.org/10.1049/cp.2011.0121.
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Konishi, Hiroo. „A study of large-scale PV system design considering PV generation distribution“. In 2013 IEEE 39th Photovoltaic Specialists Conference (PVSC). IEEE, 2013. http://dx.doi.org/10.1109/pvsc.2013.6744940.
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Jadhav, Madhuri B., und M. U. Shetty. „Grid Connected PV System with Constant Power Generation“. In 2018 International Conference on Recent Innovations in Electrical, Electronics & Communication Engineering (ICRIEECE). IEEE, 2018. http://dx.doi.org/10.1109/icrieece44171.2018.9008950.
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Malla, S. G. „Small signal model of PV power generation system“. In 2017 IEEE International Conference on Power, Control, Signals and Instrumentation Engineering (ICPCSI). IEEE, 2017. http://dx.doi.org/10.1109/icpcsi.2017.8392289.
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10
Reshmi, N., und M. Nandakumar. „Grid-connected PV system with a seven-level inverter“. In 2016 International Conference on Next Generation Intelligent Systems (ICNGIS). IEEE, 2016. http://dx.doi.org/10.1109/icngis.2016.7854065.
Der volle Inhalt der QuelleBerichte der Organisationen zum Thema "PV GENERATION SYSTEM"
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Lu, Shuai, Ruisheng Diao, Nader A. Samaan und Pavel V. Etingov. Capacity Value of PV and Wind Generation in the NV Energy System. Office of Scientific and Technical Information (OSTI), März 2014. http://dx.doi.org/10.2172/1060671.
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2
Backstrom, Robert, und David Dini. Firefighter Safety and Photovoltaic Systems Summary. UL Firefighter Safety Research Institute, November 2011. http://dx.doi.org/10.54206/102376/kylj9621.
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Under the United States Department of Homeland Security (DHS) Assistance to Firefighter Grant Fire Prevention and Safety Research Program, Underwriters Laboratories examined fire service concerns of photovoltaic (PV) systems. These concerns include firefighter vulnerability to electrical and casualty hazards when mitigating a fire involving photovoltaic (PV) modules systems. The need for this project is significant acknowledging the increasing use of photovoltaic systems, growing at a rate of 30% annually. As a result of greater utilization, traditional firefighter tactics for suppression, ventilation and overhaul have been complicated, leaving firefighters vulnerable to potentially unrecognized exposure. Though the electrical and fire hazards associated with electrical generation and distribution systems is well known, PV systems present unique safety considerations. A very limited body of knowledge and insufficient data exists to understand the risks to the extent that the fire service has been unable to develop safety solutions and respond in a safe manner. This fire research project developed the empirical data that is needed to quantify the hazards associated with PV installations. This data provides the foundation to modify current or develop new firefighting practices to reduce firefighter death and injury. A functioning PV array was constructed at Underwriters Laboratories in Northbrook, IL to serve as a test fixture. The main test array consisted of 26 PV framed modules rated 230 W each (5980 W total rated power). Multiple experiments were conducted to investigate the efficacy of power isolation techniques and the potential hazard from contact of typical firefighter tools with live electrical PV components. Existing fire test fixtures located at the Delaware County Emergency Services Training Center were modified to construct full scale representations of roof mounted PV systems. PV arrays were mounted above Class A roofs supported by wood trusses. Two series of experiments were conducted. The first series represented a room of content fire, extending into the attic space, breaching the roof and resulting in structural collapse. Three PV technologies were subjected to this fire condition – rack mounted metal framed, glass on polymer modules, building integrated PV shingles, and a flexible laminate attached to a standing metal seam roof. A second series of experiments was conducted on the metal frame technology. These experiments represented two fire scenarios, a room of content fire venting from a window and the ignition of debris accumulation under the array. The results of these experiments provide a technical basis for the fire service to examine their equipment, tactics, standard operating procedures and training content. Several tactical considerations were developed utilizing the data from the experiments to provide specific examples of potential electrical shock hazard from PV installations during and after a fire event.
3
Backstrom, Robert, und David Backstrom. Firefighter Safety and Photovoltaic Installations Research Project. UL Firefighter Safety Research Institute, November 2011. http://dx.doi.org/10.54206/102376/viyv4379.
Der volle Inhalt der QuelleAnnotation:
Under the United States Department of Homeland Security (DHS) Assistance to Firefighter Grant Fire Prevention and Safety Research Program, Underwriters Laboratories examined fire service concerns of photovoltaic (PV) systems. These concerns include firefighter vulnerability to electrical and casualty hazards when mitigating a fire involving photovoltaic (PV) modules systems. The need for this project is significant acknowledging the increasing use of photovoltaic systems, growing at a rate of 30% annually. As a result of greater utilization, traditional firefighter tactics for suppression, ventilation and overhaul have been complicated, leaving firefighters vulnerable to potentially unrecognized exposure. Though the electrical and fire hazards associated with electrical generation and distribution systems is well known, PV systems present unique safety considerations. A very limited body of knowledge and insufficient data exists to understand the risks to the extent that the fire service has been unable to develop safety solutions and respond in a safe manner. This fire research project developed the empirical data that is needed to quantify the hazards associated with PV installations. This data provides the foundation to modify current or develop new firefighting practices to reduce firefighter death and injury. A functioning PV array was constructed at Underwriters Laboratories in Northbrook, IL to serve as a test fixture. The main test array consisted of 26 PV framed modules rated 230 W each (5980 W total rated power). Multiple experiments were conducted to investigate the efficacy of power isolation techniques and the potential hazard from contact of typical firefighter tools with live electrical PV components. Existing fire test fixtures located at the Delaware County Emergency Services Training Center were modified to construct full scale representations of roof mounted PV systems. PV arrays were mounted above Class A roofs supported by wood trusses. Two series of experiments were conducted. The first series represented a room of content fire, extending into the attic space, breaching the roof and resulting in structural collapse. Three PV technologies were subjected to this fire condition – rack mounted metal framed, glass on polymer modules, building integrated PV shingles, and a flexible laminate attached to a standing metal seam roof. A second series of experiments was conducted on the metal frame technology. These experiments represented two fire scenarios, a room of content fire venting from a window and the ignition of debris accumulation under the array. The results of these experiments provide a technical basis for the fire service to examine their equipment, tactics, standard operating procedures and training content. Several tactical considerations were developed utilizing the data from the experiments to provide specific examples of potential electrical shock hazard from PV installations during and after a fire event.
4
Schauder, C. Advanced Inverter Technology for High Penetration Levels of PV Generation in Distribution Systems. Office of Scientific and Technical Information (OSTI), März 2014. http://dx.doi.org/10.2172/1129274.
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