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Regarding the direction, as Michele mentioned, the best way would be to find a dedicated glare tool. Alternatively, you could compute the direction yourself based on the sun position and the modules orientation. For the quantitative part, you could use the IAM values of your PVmodule, the incidence angle and the incident irradiance to estimate the reflected energy.

PVsyst V8.0.12: Hello, the "Operating losses at STC" sections of the PVsyst V8 output PDF report have disappeared (!). See below screenshots as example (V8 screenshot is missing the section; V7 screenshot contains the section on the right-hand side). (NB: Please note the value for Iron Loss Fraction in one of the screenshots is incorrect, as there was a typo in the input. This rapid example was for screenshot purposes only.)

There are common instances when we would apply different "soiling" assumptions (which includes dust, snow, etc.) for different PV module types (e.g., monofacial, bifacial). We would like the ability to apply a different set of monthly soiling values for each subarray in PVsyst V8. This would resemble the subarray dropdown menu for the MQA factor in Detailed Losses. Is it on the development roadmap? Thanks.

I would like to simulate 2 MW floating PV system, how to start ?

P.S. I am referring specifically to this message:

EarrNom and all resulting energy are not shown correctly when exporting loss diagram values from the report. The report itself is correct, but the exported values are not.

Hi, I'd like to specifically request a 10-min. editing time as an incremental (and meaningful) improvement. Thank you!

PVsyst V8 Problem Statement: How to apply spectral adjustments to certain subarrays (containing certain PV module cell types) and *not* to others? Ideas (example only): 1.) This could be handled in the PV module PAN file, through a checkbox which (if checked) will apply spectral adjustments IF the tab in Detailed Losses is applied 2.) This could be handled as a dropdown menu for each subarray on the spectral adjustment tab in Detailed Losses, similar to the MQA factor subarray dropdown menu, where you can toggle on/off spectral adjustments for each subarray 3.) (Least favorite option): If the spectral adjustment tab of Detailed Losses is applied, it could automatically apply spectral adjustments onto the specific technologies involved in each subarray according to PV cell technology type. This is the least favorite option, because not all PV cell technologies should use spectral adjustments (e.g., single-junction Si-based technologies). Conversely (and preferably), Options 1 and 2 above would allow the user to *only* apply spectral adjustments onto the (sub)set of PV cell technologies in the applicable subarrays which require spectral adjustments. Thank you!

The 1100UD is one inverter module that is typically installed with other modules in a single PCS, like the 4400UD-MV. You will have four mppts with the 4400, each 1100 is one mppt as stated above.

Dear Nikoloz, It seems that the inverter you want to use is a central inverter with only one MPPT. This means all strings connected to it must be identical. So, you don’t need to worry about the MPPT definition. In PVsyst, just select the configuration “PNom sharing within the inverter” (see below). Then, you only need to specify the number of inverters. Regards,

Dear Ishan, First of all, the Unlimited Tracker represents an idealized PV table layout, with all rows having exactly the same length. Most likely, your 3D scene doesn't follow this idealized representation. Could you please send us your project by email at support@pvsyst.com, so I can check it and explain why you're seeing these differences? Regards,

Hello I have such question. does anybody had used modular inverters ? Sungrow_SG1100UD what about this inverter ? when I uploaded OND file in PVsyst there is no information about MPPTs, there is some error with dtasheet ? I have to make desighn of 100MW plant but how to organise strings in mppts?? here is datasheet link https://en.sungrowpower.com/productDetail/4102/1-x-modular-inverter-sg1100ud-20

IRev is calculated according to the expression mentioned above, by neglecting Rserie (put Rs = 0). This expression gives the IRev as a function of a specified voltage. Iph is the short circuit current for this shaded cell.

While simulating project with identical capacity, components, and loss factor , PVsyst has generated variable generation( E grid MWh) results for Unlimited tracker mode and the 3D scene mode . Egrid MWh Near Shading loss : Irradiance Unlimited Tracker 1438860 -1.8% 3D scene 1481095 -2.4 % I want to understand how PVsyst is generating variable results for Unlimited tracker and 3D scene mode which should not be case for identical project parameters(Pitch,1P,Other loss factors). What are the factors resulting in this variation .

OK IRev = Iph +aRev *V，for aRev=800mA/V^2, 800/1000*（-5.2）*（-5.2）= 21.632 (A) ；the externally forced current is 7.93A； how to calculate IRev？ thanks

In PVsyst, the model for the reverse characteristics is this quadratic expression. This corresponds rather well to the reality, but this is a rough approximation. By the way the values of this model have a quasi null impact on the PVsyst simulation results. Now the term (Rserie * I) is indeed a little contribution (perhaps it should not be taken into account, we will check). You can forget it.

If it still doesn't work you can always model it as I have above 🙂 The gaps will not matter for bifacial calculations, they are not used. The user defines the transparency factor manually which takes into account gaps in structure, modules, etc. So I'd either model as I have or increase the gap in your method if the suggestion above does not work.

Select 'Disable field interpenetration check' from inside shading scene and see if that works

Thank you for the fast response! is it possible for you to share some ways to indirectly estimate? Yes! I am looking for the purpose of glare regulations

Excuse me, Prof.Andre Mermoud is I the reverse current in this formula，so a more accurate representation would be IRev = Iph +aRev *（V+Rs * IRev） ；and the externally forced current is IRev？ thanks for reply.

You're a great help Jéremie! Thank you.

Dear User, In this case, please email us at support@pvsyst.com your PVsyst LOG files (menu <File> <Export logs>) so we can analyze what happened. Best regards.

Excuse me, but this problem happens with any project.

This tool shows what happens for a specified current (i.e. imposed by the rest of the string). You can drag the red point of this forced current for analysing what happens at different values. The voltage of this point is the result of the reverse characterisics model: You can find this formula in the help https://www.pvsyst.com/help/physical-models-used/pv-module-standard-one-diode-model/reverse-characteristic-of-a-cell.html The temperature is obtained by applying the U-value on this cell, taking the dissipated power as input parameter instead of GlobInc.

Hello, the difference between the axis tilt of the field and the average orientation it belongs to is higher than the default tolerance for this parameter. You can adjust this tolerance in the advanced parameters. To find it, use the search filter and type 'tilt'. The relevant parameter in this case is 'Tracking: maximum axis tilt spread'. You can set this tolerance to 13