Linda Thoren

it is the coefficient set for that specific PV module technology. You can find additional information in the following help: https://www.pvsyst.com/help/physical-models-used/pv-module-standard-one-diode-model/firstsolar-spectral-correction.html#spectral-correction-in-pvsyst

Hello, In the loss diagram, each loss is defined as percentage of the previous energy quantity. In general, if you have defined a continuous auxiliary loss and export an hourly output file, you will see that this value will remain constant, though the percentage it will represent will of course vary depending on the production (if you for instance look at the loss diagram for the different months). You can read more about the loss diagram and the auxiliary losses in the following help page: https://www.pvsyst.com/help/project-design/results/loss-diagram.html https://www.pvsyst.com/help/project-design/array-and-system-losses/auxiliaries-consumption.html Please let me know if this answers your question. Kind regards,

Hello, When defining monthly values, it is assumed that the consumption that month is identical throughout the month. Thus from kWh/month to an average power is simply a calculation of how many hours there are per month. Note that the average power need for monthly values are reflecting day and night consumption, thus it does not directly make a very good basis for the needed installed AC capacity, but at least a fist order of magnitude.

Dear Shivya and Ben, This is difficult question and we do not have a direct answer. As a first approximation, the structure shading could be estimated as the ratio of the area covered by structures to the photovoltaic area. In this approximation, the effect of structures is therefore their projection on the rear plane. Therefore, it neglects the fact that light may arrive on the rear side from multiple directions, akin to diffuse light. This approximation is hence likely an underestimate of the shading loss, in full generality. Indeed, even if structural elements are not directly in front of the rear side of modules, they may cause significant shading. A better approximation is beyond the present possibilities of PVsyst. Then there is the the variable for the mismatch loss factor, caused by a heterogenous irradiance distribution on the rear side. Any source of heterogeneous irradiance will cause electrical mismatch effects. Such is the case of shading cast by structural elements (but also differences in location relative to the environment and the ground). At present, PVsyst has no easy way to make an accurate estimation for these effects. Based on comparisons with measurement data, we have determined a default value (10%) for a general case. With beams covering the module width directly in front of the rear side of modules, the mismatch losses may increase drastically. In such a case, one can roughly estimate the mismatch effect as follows: as the current in a string is the current in the worst cell, if the structure covers x% of one cell, the shading effect will be x% for the concerned string. For example, the loss may be reduced by a factor of 2 if the structure covers half a cell (or two half cells).

No sorry it is not possible to divide your system in the batch simulation.

Indeed, the final simulation result always corresponds to the full system. To view the results of the individual inverters, you would need to simulate each one in a separate variant. Depending on how AC losses are defined, the two individual inverters should produce approximately the same as when they are simulated together, although some post-inverter losses may differ due to the lower total system power. If your full system has two inverter before the injection point, this is how you should simulate the system, rather than adding variants together. Separating the inverters into separate variants is a work around to evaluate the individual inverter performance.

Hello, Yes if you are defining the MPPTs you have an interest to use the Auto-equal Pnom option, to avoid overload losses in some sub-arrays while other underperform. If you have multiple orientations, you can use the multi-orientation daily sharing option. Kind regards,

Hello, Indeed, this is not the expected behavior. Since the grid limitation is applied at the Pnom, we have observed that in certain situations—when the MPPTs operate under very different conditions—this may lead to results that do not perform as intended. To analyze your project in more detail, could you please export it as a .zip file and send it to our support team at support@pvsyst.com? We apologize for the inconvenience.

I notice that you have a warning message indicating that your file contains data for the 29th of February. Are you using weather data for this specific year (a leap year) or a generic year ? Try to take out the 29th of February from the dataset.

Hello, The differences in the databases will be in the global horizontal irradiance, and thus only indirectly on the global incident in collector plane. To calculate the Global incident in the collector plane, the same transposition method can be used for any source of weather data. The difference in direct and diffuse irradiance for instance can have a large impact in the incident in the collector plane. You can read mora about the transposition model in the following help page: https://www.pvsyst.com/help/physical-models-used/irradiation-models/transposition-model.html Indeed, there can be large differences in the weather data and it is difficult to evaluate which one is the most accurate at a specific site. We have done some comparisons that you find in the following help page: https://www.pvsyst.com/help/meteo-database/import-meteo-data/data-source-comparison.html?h=weather+data

You find the carbon balance tool in the end of the economic evaluation window and you can choose to print the results in the report. In the report option, make sure the Co2 Emission Balance is enabled for the results to appear in the report.

Hello, Does the peaks only appears in the preview graphics or is there in issue with the actual values in the input? Does the Annual need and the CSV source file to the left of the graphic correspond to the original file? You can possibly try to run a simulation and export the results to verify that the simulation is made with the correct values

Hello, Indeed there can be big discrepancies between databases. It is very difficult to estimate which one is the best suited for a given project or location, and what the probable error is. The following Help page provides comparisons of several databases across different sites: https://www.pvsyst.com/help/meteo-database/import-meteo-data/data-source-comparison.html?h=meteo+comparison#comparison-between-several-data-sources-for-different-continents

Hello, After running a simulation you have access to the "Detailed Results". In the "Tables" window, you can generate a table like the one in the beginning of this thread with E_Grid hourly averages

Hello and welcome ! The first steps of how to import custom weather data into PVsyst is explained in our Help in the following link: https://www.pvsyst.com/help/meteo-database/import-meteo-data/custom-meteo-files/index.html Kind regards