PV & Hybrid System Designer
Grid-connected PV strings, independent MPPTs, battery compatibility and approximate monthly energy production (client-side v1.2).
PV strings and battery systems
Enter actual module, inverter and battery manufacturer data. Monthly energy results are statistical screening only; hourly clipping and dispatch cannot be verified from monthly data.
Temperatures & solar data (optional)
The string checks need only the design cell temperatures below. Solar data is optional: without it, the energy estimate uses a built-in default (a generic illustrative climate, estimate only). Enter your own values for a better estimate. Client-side only: nothing is looked up online.
Solar data and losses (optional): using built-in illustrative irradiation (not site-specific)
Monthly horizontal irradiation (kWh/m²/month) and ambient temperature
Panels & subarrays
Each subarray can use its own module and orientation. Differing models/orientations are allocated to separate MPPTs.
MPPT and AC limits
Actual manufacturer specifications must replace the illustrative values. Each tracker is independent; physical PV inputs are not additional trackers.
Data of every MPPT
All 3 MPPT(s) use these values. If the MPPTs of your inverter have different limits, tick “The MPPTs are not identical” to enter each one.
Storage
Electricity price
The value of the production is an estimate: the annual energy of the model multiplied by your electricity price. It does not model the tariff structure, how much is self-consumed or exported, degradation, price changes or costs. The pre-filled price is only an example: enter your own.
Design & verification
| MPPT | Subarray | Strings × modules | Max Voc | Min Vmp | MPPT Isc | Full-load |
|---|---|---|---|---|---|---|
| 1 | A | 1 × 18 | 705.7 V | 480.1 V | 16.1 A | Not assessed |
| 2 | A | 1 × 18 | 705.7 V | 480.1 V | 16.1 A | Not assessed |
| 3 | A | 1 × 18 | 705.7 V | 480.1 V | 16.1 A | Not assessed |
Full-load range is independently assessed. Unused tracker capacity is permitted. A PARTIAL or NOT FULLY ASSESSED design is not a verified recommendation.
- Full-load MPPT voltage range: NOT ASSESSED for one or more trackers.
Scope and assumptions (2)
- Candidate ranking uses pre-clipping statistical energy potential (or nameplate where no irradiation); VERIFIED maximum annual AC optimization is NOT ASSESSED using monthly data.
- Vmp temperature coefficient estimated from Pmax and Isc coefficients.
Statistical monthly solar production
GENERIC CLIMATE ESTIMATE — not site-specific. Estimated from built-in illustrative monthly irradiation; changes to latitude, temperature or diffuse assumptions do not make it measured or site-specific. Enter actual monthly GHI for a better preliminary estimate.
Theoretical gross value only: estimated annual energy × 0.20 €/kWh, about €309 per kWp per year. Not expected bill savings: self-consumption, exports/curtailment, tariffs, degradation and costs are not modeled. Zero-export sites cannot value every generated kWh at the purchase tariff.
Where the energy goes: losses relative to the in-plane energy (total 20.0 %)
| Loss | % of in-plane energy |
|---|---|
| Module temperature and low irradiance | 5.1 % |
| Optical (incidence angle, net of spectral) | 2.1 % |
| Shading | 0.0 % |
| Soiling | 2.0 % |
| DC wiring | 1.5 % |
| Other (mismatch, AC wiring, availability) | 8.0 % |
| Inverter | 3.0 % |
| Total | 20.0 % |
The losses multiply, so the percentages do not add up exactly. Module temperature is estimated from ambient temperature and irradiance; the temperature coefficient of the module you entered then sets how much power is lost when it is hot.
Statistical model limits (4)
- Statistical monthly estimate only: cloud sequences, hourly clipping, current limiting, true inverter conversion curve, availability and load-driven curtailment NOT ASSESSED.
- Approximate tilt/azimuth transposition (Hay-Davies/Reindl anisotropic sky on monthly mean values); cell temperature is estimated from the daytime ambient temperature and the irradiance (about NOCT 45 °C). The temperature and low-irradiance constants were calibrated against an independent solar-resource simulation tool for one site in Greece (generic crystalline silicon, about -0.40 %/°C): annual agreement about 1 %, single months up to about 6 %. A check at a second site in Greece (data not used for the calibration; 30° south and 20° east) gave annual differences of +0.1 % and +2.5 % and single months within about 4 %; colder, cloudier or non-Greek climates are not validated.
- Irradiation input is monthly global HORIZONTAL irradiation (GHI), not plane-of-array data. The default system losses (soiling, DC wiring, inverter, optical and other) total about 14 %; do not add losses that are already included.
- The loss chain contains shading, soiling, DC cabling, module temperature, low irradiance, optical (incidence angle net of spectral) and other system losses (mismatch, AC wiring, availability, degradation) as flat percentages, and a constant inverter efficiency; clipping and hourly effects are NOT included. The diffuse fraction of each month comes from the monthly data table (for the built-in default, its illustrative Kd values).
Step-by-step formulas
Temperature-corrected string voltages
Monthly preliminary AC-equivalent energy
The transposition factor uses representative solar geometry and assumed diffuse fraction. Hourly clipping, curtailment, MPPT behavior and battery power paths are not solved.