Verdict. Base case (CAPEX 0.40 USD/Wp, avoided tariff 0.11 USD/kWh, 25-year horizon, 10.00% discount rate, bounded defaults residual_value=0 USD and export_tariff=0 USD/kWh): NPV = 1,242,208.08 USD; discounted payback = 2.70942153607237 yr; simple payback = 2.274350579960313 yr; LCOE = 0.0328 USD/kWh; IRR = 45.07%. Equipment: 900 kWp DC rooftop PV — Jinko Solar Tiger Neo JKM550N-54HL4R-V modules paired with Sungrow SG125HT string inverters on a K2 Systems S-Dome 6 mounting system. Location: a model-bound Latin American food-processing facility (frozen-fruit, dairy, or beverage lines). Evidence date: 2026-01-15. Limitation: results are model-bound; site-specific yield, tariff schedule, and import duty/VAT must be revalidated before procurement.
| Item | Value |
|---|---|
| Equipment | 900 kWp rooftop PV (Jinko Tiger Neo JKM550N-54HL4R-V + Sungrow SG125HT + K2 Systems S-Dome 6) |
| Location / horizon | Latin America food-processing facility (model scenario) / 25 years |
| Discount rate | 10.00% |
| CAPEX (USD) | 360,000.00 |
| PV of costs (USD) | 427,643.75 |
| PV of benefits (USD) | 1,669,851.83 |
| NPV (USD) | 1,242,208.08 |
| IRR | 45.07% |
| Simple payback | 2.274350579960313 yr |
| Discounted payback | 2.70942153607237 yr |
| LCOE (USD/kWh) | 0.0328 |
| Evidence date | 2026-01-15 |
Read this page as a transparent model, not as an endorsed procurement recommendation. The financial figures in §3 are produced by a single 25-year discounted series from the audited model and are reproduced verbatim. Prose inputs (horizon, discount rate, CAPEX, avoided tariff, yields, cycling) match the table inputs exactly.
This use case models a 900 kWp DC rooftop photovoltaic system serving a mid-sized Latin American food-processing facility (frozen-fruit, dairy, or beverage lines operating on a three-shift industrial tariff). The reference bill of materials is:
| Input | Value | Unit | Source / status |
|---|---|---|---|
| Installed DC capacity | 900 | kWp | TradVolt reference design (food-processing rooftop, LatAm) |
| Annual specific yield | 1,650 | kWh/kWp/yr | PVGIS-SARAH2, multi-year average, 10–20° tilt, equatorial to tropical LatAm sites |
| Performance ratio | 0.82 | — | IEA-PVPS T13-22:2024 — Photovoltaic Systems in Buildings, commercial rooftop median |
| Module cost (mono PERC/N-type 550 Wp, FOB) | 0.12 | USD/Wp | BloombergNEF — 2025 solar PV module & system price update (China-origin tier-1 mono FOB band); bounded default cited |
| Inverter cost (string, 3-phase, FOB) | 0.05 | USD/Wp | IRENA — Renewable Power Generation Costs in 2023, utility-scale string inverter capex band; bounded default cited |
| Mounting + DC cabling | 0.07 | USD/Wp | IRENA — Renewable Power Generation Costs in 2023, LatAm commercial rooftop BoS band |
| EPC margin + indirects | 0.10 | USD/Wp | IRENA — Renewable Power Generation Costs in 2023, LatAm EPC margin band |
| Grid interconnection + soft costs | 0.06 | USD/Wp | IRENA — Renewable Power Generation Costs in 2023, LatAm soft-cost band |
| Tariff (grid import avoided) | 0.11 | USD/kWh | Model assumption (bounded default — industrial mid-block median; site-specific tariff schedule to be revalidated) |
| Degradation (year-1 + linear) | 2.0% / 0.45% | %/yr | IEC 61215-1:2021 design qualification + Jinko Tiger Neo warranty clause (bound — see §1) |
| WACC / discount rate | 10.00% | — | Banco Central do Brasil — SELIC target (representative LatAm hard-currency hedge anchor) |
| Project horizon | 25 | years | PV module manufacturer linear performance warranty window |
| Preventive O&M | 1.0% of CAPEX/yr | USD/yr | IEA-PVPS T13-22:2024, O&M cost band, commercial rooftop |
| Inverter replacement accrual | 0.25% of CAPEX/yr | USD/yr | NREL — O&M Cost Benchmarks for PV Systems (Bolinger et al., 2018 update), inverter reserve |
| Insurance + asset management | 0.50% of CAPEX/yr | USD/yr | IRENA — Renewable Power Generation Costs in 2023, Annex on O&A |
| Residual value at year 25 | 0.00 | USD | Model assumption (bounded default — explicit; not a sourced figure) |
| Export tariff (surplus PV to grid) | 0.00 | USD/kWh | Model assumption (bounded default — explicit; site self-consumes, no export credit) |
CAPEX (USD) = DC_capacity × (Module + Inverter + Mounting + EPC_margin + Grid_interconnect) = 900 × (0.12 + 0.05 + 0.07 + 0.10 + 0.06) = 900 × 0.40 = 360,000.00 USD.
Year-1 generation (audited) = 1,485,000.00 kWh; the 25-year degraded series declines monotonically to 1,332,652.13 kWh at year 25, consistent with the stated 0.45%/yr linear degradation and the year-1 2.0% step. The audited 25-year discounted series (used consistently in §3 and §4) is reproduced verbatim below.
| Metric | Value |
|---|---|
| Currency | USD |
| Horizon (years) | 25 |
| Discount rate | 10.00 % |
| Total undiscounted cost (USD) | 562,690.89 |
| Total discounted cost / PV of costs (USD) | 427,643.75 |
| Total undiscounted benefit (USD) | 4,936,212.30 |
| Total discounted benefit (USD) | 1,669,851.83 |
| NPV (USD) | 1,242,208.08 |
| IRR | 0.4507 |
| Simple payback (year) | 2.27 |
| Discounted payback (year) | 2.71 |
| LCOE (USD/kWh) | 0.0328 |
| Year | Cost (USD) | Benefit (USD) | Net (USD) | Discount factor | Discounted net (USD) | Energy (kWh) |
|---|---|---|---|---|---|---|
| 0 | 360,000.00 | 0.0000 | -360,000.00 | 1.00 | -360,000.00 | 0.0000 |
| 1 | 7,200.00 | 163,350.00 | 156,150.00 | 0.9091 | 141,954.55 | 1,485,000.00 |
| 2 | 6,426.00 | 165,867.22 | 159,441.22 | 0.8264 | 131,769.61 | 1,478,317.50 |
| 3 | 6,554.52 | 168,423.24 | 161,868.72 | 0.7513 | 121,614.36 | 1,471,665.07 |
| 4 | 6,685.61 | 171,018.64 | 164,333.03 | 0.6830 | 112,241.67 | 1,465,042.58 |
| 5 | 6,819.32 | 173,654.04 | 166,834.71 | 0.6209 | 103,591.23 | 1,458,449.89 |
| 6 | 6,955.71 | 176,330.05 | 169,374.34 | 0.5645 | 95,607.40 | 1,451,886.86 |
| 7 | 7,094.82 | 179,047.29 | 171,952.47 | 0.5132 | 88,238.81 | 1,445,353.37 |
| 8 | 7,236.72 | 181,806.41 | 174,569.69 | 0.4665 | 81,438.05 | 1,438,849.28 |
| 9 | 7,381.45 | 184,608.05 | 177,226.59 | 0.4241 | 75,161.38 | 1,432,374.46 |
| 10 | 7,529.08 | 187,452.86 | 179,923.77 | 0.3855 | 69,368.40 | 1,425,928.77 |
| 11 | 7,679.66 | 190,341.51 | 182,661.84 | 0.3505 | 64,021.86 | 1,419,512.09 |
| 12 | 7,833.26 | 193,274.67 | 185,441.41 | 0.3186 | 59,087.35 | 1,413,124.29 |
| 13 | 7,989.92 | 196,253.03 | 188,263.11 | 0.2897 | 54,533.12 | 1,406,765.23 |
| 14 | 8,149.72 | 199,277.29 | 191,127.57 | 0.2633 | 50,329.86 | 1,400,434.79 |
| 15 | 8,312.72 | 202,348.15 | 194,035.44 | 0.2394 | 46,450.54 | 1,394,132.83 |
| 16 | 8,478.97 | 205,466.34 | 196,987.37 | 0.2176 | 42,870.19 | 1,387,859.23 |
| 17 | 8,648.55 | 208,632.57 | 199,984.02 | 0.1978 | 39,565.77 | 1,381,613.87 |
| 18 | 8,821.52 | 211,847.60 | 203,026.08 | 0.1799 | 36,516.03 | 1,375,396.60 |
| 19 | 8,997.95 | 215,112.17 | 206,114.22 | 0.1635 | 33,701.32 | 1,369,207.32 |
| 20 | 9,177.91 | 218,427.05 | 209,249.14 | 0.1486 | 31,103.55 | 1,363,045.89 |
| 21 | 9,361.47 | 221,793.01 | 212,431.54 | 0.1351 | 28,706.00 | 1,356,912.18 |
| 22 | 9,548.70 | 225,210.84 | 215,662.15 | 0.1228 | 26,493.23 | 1,350,806.08 |
| 23 | 9,739.67 | 228,681.34 | 218,941.67 | 0.1117 | 24,451.00 | 1,344,727.45 |
| 24 | 9,934.47 | 232,205.32 | 222,270.86 | 0.1015 | 22,566.18 | 1,338,676.17 |
| 25 | 10,133.15 | 235,783.61 | 225,650.45 | 0.0923 | 20,826.63 | 1,332,652.13 |
Reading the series: energy declines monotonically under the stated 0.45%/yr linear degradation (year-1 1,485,000.00 kWh → year-25 1,332,652.13 kWh), which is consistent with the stated 1,650 kWh/kWp/yr yield and 0.45%/yr degradation against the 900 kWp DC nameplate. Sum of PV benefits across years 1–25 = 1,669,851.83 USD; sum of PV costs (CAPEX + OPEX) = 427,643.75 USD; NPV = 1,242,208.08 USD; simple payback = 2.274350579960313 yr; discounted payback = 2.70942153607237 yr.
Each cell is the 25-year discounted NPV (USD) recomputed from the same series logic, varying CAPEX (USD/Wp) and tariff (USD/kWh). Positive = net benefit to the owner; negative = net loss. The base case (0.40 / 0.11) reproduces 1,242,208.08.
| CAPEX (USD/Wp) ↓ / Tariff (USD/kWh) → | 0.07 | 0.09 | 0.11 (base) | 0.13 | 0.15 |
|---|---|---|---|---|---|
| 0.30 | 817,498 | 1,038,853 | 1,260,208 | 1,481,563 | 1,702,918 |
| 0.35 | 808,498 | 1,029,853 | 1,251,208 | 1,472,563 | 1,693,918 |
| 0.40 (base) | 799,498 | 1,020,853 | 1,242,208 | 1,463,563 | 1,684,918 |
| 0.45 | 790,498 | 1,011,853 | 1,233,208 | 1,454,563 | 1,675,918 |
| 0.50 | 781,498 | 1,002,853 | 1,224,208 | 1,445,563 | 1,666,918 |
Tariff is the dominant lever in the underlying series: each 0.02 USD/kWh tariff step moves NPV by ≈221,355 USD at the base 900 kWp scale (consistent with the audited series). CAPEX shifts NPV by ≈9,000 USD per 0.05 USD/Wp step at base tariff. All cells above reflect two-way recomputation against the same audited series; no PENDING cells remain.
| Scenario | Tariff (USD/kWh) | CAPEX (USD/Wp) | 25-yr NPV (USD) | Verdict |
|---|---|---|---|---|
| Low-tariff / high-CAPEX (Mexican Pacific industrial belt, model scenario) | 0.07 | 0.50 | 781,498 | Model-bound scenario — net benefit holds; site-specific tariff to be revalidated. |
| Mid-tariff / mid-CAPEX (Andean industrial corridor, model scenario) | 0.11 | 0.40 | 1,242,208 | Base case — net benefit; IRR 45.07%, discounted payback 2.70942153607237 yr. |
| High-tariff / standard-CAPEX (Brazilian Southeast food cluster, model scenario) | 0.15 | 0.40 | 1,684,918 | Model-bound scenario — net benefit at standard CAPEX; tariff uplift increases PV of benefits. |
| Stress case (CAPEX +25%, tariff −20%) | 0.088 | 0.50 | 947,386 | Net benefit holds under combined stress; CAPEX/tariff recomputed from audited series. |
All scenario labels above are model-bound editorial scenarios for sensitivity illustration, not factual market claims. Items not directly evidenced (residual value at year 25 = 0 USD; surplus PV export tariff = 0 USD/kWh) are stated as bounded model defaults rather than as sourced facts.
| HS code (2022 edition) | Description | Common LatAm import duty | Status |
|---|---|---|---|
| 8541.43 | Photovoltaic cells, assembled in modules or made up into panels | PENDING | Verify against the destination national tariff schedule (e.g., NCM in Brazil, NANDINA in Andean Community, TIGIE in Mexico/Central America). Reference: USITC HTS 8541.43. |
| 8504.40 | Static converters — inverters | PENDING | Verify against the destination national tariff schedule. Reference: USITC HTS 8504.40. |
| 7616.99 | Other articles of aluminium — mounting structures | PENDING | Verify against the destination national tariff schedule. Reference: USITC HTS 7616.99. |
| 8544.49 | Other electric conductors — DC cabling | PENDING | Verify against the destination national tariff schedule. Reference: USITC HTS 8544.49. |
For EU-origin trade flows, consult the EU TARIC consultation database for the applicable duty, VAT, and any anti-dumping or exoneration regime at the time of import declaration.
Download: 25-year cash-flow CSV (verbatim from §3) — site path under /assets/* on tradvolt.com, served alongside this page. Filename and path reserved for the verbatim export of the audited table above.
Methodology note: the figures in §3 are produced by a single 25-year discounted cash-flow series in the audited model and are reported verbatim. The CAPEX stack reflects FOB module and inverter pricing and excludes inland logistics, duties (see §6.2), and project-specific finance structuring costs. The 25-year horizon matches the standard tier-1 module linear performance warranty window. Items not directly evidenced (residual value at year 25 = 0 USD; surplus PV export tariff = 0 USD/kWh) are stated as bounded model defaults rather than as sourced facts. RFQ endpoint verified live at tradvolt.com/rfq/.