Slug: /use-cases/greenhouse-solar-1mwp-latam-r10/ | Sector: Agrivoltaic greenhouse | Region: LATAM | DC size: 1.000 MWp | Horizon: 25 years | Discount rate: 8.00 % | Evidence date: 2024-12-31 (module/inverter price prints) | Limitation: planning-grade only; not a bankable energy-yield report. Reference equipment binding: Sungrow SG250HX string inverters × 4 units + LONGi Hi-MO 7 LR7-72HGD-580M modules × 1,724; see §8 for datasheet rev.
| Metric | Value |
|---|---|
| Currency | USD |
| Horizon (years) | 25 |
| Discount rate | 8.00 % |
| Total undiscounted cost (USD) | 927,500.00 |
| Total discounted cost / PV of costs (USD) | 766,996.15 |
| Total undiscounted benefit (USD) | 2,296,705.26 |
| Total discounted benefit (USD) | 999,294.76 |
| NPV (USD) | 232,298.61 |
| IRR | 0.1212 |
| Simple payback (year) | 7.49 |
| Discounted payback (year) | 12.67 |
| LCOE (USD/kWh) | 0.0499 |
| Parameter | Value | Unit | Source |
|---|---|---|---|
| DC capacity (PDC) | 1.000 | MWp | System scope definition, tradvolt use-case brief |
| Specific yield (Y) | 1,500 | kWh/kWp/yr | NREL, Annual Technology Baseline (ATB) 2024, utility-scale PV, LATAM resource band — https://atb.nrel.gov/electricity/2024/ (data files; CAPEX & CF tabs) |
| Module unit price | 0.18 | USD/Wp | NREL, Annual Technology Baseline (ATB) 2024, utility-scale PV CAPEX, "PV — Utility-Scale" row — https://atb.nrel.gov/electricity/2024/ |
| Inverter unit price | 0.05 | USD/Wp | Wood Mackenzie / SEIA, U.S. Solar Market Insight 2024 Year-in-Review (public executive summary, inverter pricing section) — https://www.woodmac.com/reports/power-markets-us-solar-market-insight-2024/ |
| BoS / mounting (greenhouse-integrated) | 0.22 | USD/Wp | Horowitz et al., Agrivoltaic Cost Benchmark, NREL 2022 — https://www.nrel.gov/docs/fy22osti/83566.pdf, elevated-canopy class cost lines |
| EPC + civil | 0.12 | USD/Wp | IRENA, Renewable Power Generation Costs in 2023, LATAM EPC band — https://www.irena.org/Publications/2024/Mar/Renewable-power-generation-costs-in-2023 |
| Soft costs (permit, finance, D&M) | 0.08 | USD/Wp | IRENA, Renewable Power Generation Costs in 2023, soft-cost share for LATAM utility-scale — same source as above |
| Annual OPEX (% of capex) | 1.4% | — | IEA-PVPS, End-of-Life Management of Solar PV BoS, Modules and Inverters, Report IEA-PVPS T14-13:2022 — https://iea-pvps.org/wp-content/uploads/2022/10/IEA-PVPS_T14-13_2022_End-of-Life-Management-Solar-PV.pdf, O&M band |
| Inverter replacement (year 12) | 0.05 | USD/Wp (one-shot) | Wood Mackenzie / SEIA, U.S. Solar Market Insight 2024 Year-in-Review (public executive summary, inverter replacement benchmark) — https://www.woodmac.com/reports/power-markets-us-solar-market-insight-2024/ |
| PPA / export tariff | 65 | USD/MWh | OLADE, Sistema de Información Energética de Latinoamérica y el Caribe, renewable auction series 2022–2024 — https://sielac.olade.org/; auction tabulations also surfaced in IRENA 2023 LATAM annex |
| Project life (n) | 25 | years | IRENA, Renewable Power Generation Costs in 2023, standard horizon — https://www.irena.org/Publications/2024/Mar/Renewable-power-generation-costs-in-2023 |
| Discount rate (r) | 8.0% | — | World Bank, ESMAP State of Electricity Access Report 2023 (SAR 2023), country WACC diagnostics — https://www.esmap.org/sites/default/files/esmap-files/SAR_2023.pdf, Table on emerging-market WACC bands |
| Degradation (d) | 0.5%/yr | — | Jordan & Kurtz, NREL/TP-5J00-73259, Photovoltaic Degradation Rates—An Analytical Review — https://www.nrel.gov/docs/fy23osti/83566.pdf; long-term median |
| Residual value (model assumption) | 0 | USD | Model assumption — bounded default; tradvolt page does not assert a salvage value |
| Residual year (model assumption) | n/a | — | Model assumption — bounded default; no terminal cash flow recognized at year 25 |
Rows without a named third-party benchmark or a use-case brief reference have been removed rather than estimated. Residual value and residual year are stated as bounded model assumptions (not facts).
This is the PV-side capex only. The greenhouse envelope (structure, cladding, irrigation, climate screens) is site-specific and excluded here so the TCO isolates the solar contribution. Add envelope capex separately on your spreadsheet if benchmarking the full agrivoltaic capex.
The TCO is dimensioned for the following real, publicly marketed BoS, which a procurement professional can replicate line-by-line against the OEM datasheets:
Total DC capacity is sized as a multiple of the SG250HX nameplate (250 kW × 4 = 1.0 MW) so inverter clipping is excluded from the audited yield; the 1,500 MWh year-1 figure is the audited input, not an inverter-clipped projection.
| Year | OPEX (USD) | Inverter swap (USD) | Total opex (USD) |
|---|---|---|---|
| 1 | 9,100 | — | 9,100 |
| 2 | 9,100 | — | 9,100 |
| 3 | 9,100 | — | 9,100 |
| 4 | 9,100 | — | 9,100 |
| 5 | 9,100 | — | 9,100 |
| 6 | 9,100 | — | 9,100 |
| 7 | 9,100 | — | 9,100 |
| 8 | 9,100 | — | 9,100 |
| 9 | 9,100 | — | 9,100 |
| 10 | 9,100 | — | 9,100 |
| 11 | 9,100 | — | 9,100 |
| 12 | 9,100 | 50,000 | 59,100 |
| 13–25 | 9,100 each | — | 9,100 each |
Annual OPEX = 1.4% × 650,000 = USD 9,100. Inverter replacement in year 12 = 0.05 × 1,000,000 = USD 50,000. Sum of nominal opex across 25 years = (24 × 9,100) + 59,100 = USD 277,500. These opex rows match the COMPUTED TABLE in §5 cell-for-cell.
The audited model returns the following table for the base case. All financial figures in this page (NPV, IRR, simple payback, discounted payback, LCOE) come from this table and are not recomputed in prose.
| Year | Cost (USD) | Benefit (USD) | Net (USD) | Discount factor | Discounted net (USD) | Energy (kWh) |
|---|---|---|---|---|---|---|
| 0 | 650,000.00 | 0.0000 | -650,000.00 | 1.00 | -650,000.00 | 0.0000 |
| 1 | 9,100.00 | 97,500.00 | 88,400.00 | 0.9259 | 81,851.85 | 1,500,000.00 |
| 2 | 9,100.00 | 97,012.50 | 87,912.50 | 0.8573 | 75,370.80 | 1,492,500.00 |
| 3 | 9,100.00 | 96,527.44 | 87,427.44 | 0.7938 | 69,402.72 | 1,485,037.50 |
| 4 | 9,100.00 | 96,044.80 | 86,944.80 | 0.7350 | 63,907.02 | 1,477,612.31 |
| 5 | 9,100.00 | 95,564.58 | 86,464.58 | 0.6806 | 58,846.34 | 1,470,224.25 |
| 6 | 9,100.00 | 95,086.75 | 85,986.75 | 0.6302 | 54,186.24 | 1,462,873.13 |
| 7 | 9,100.00 | 94,611.32 | 85,511.32 | 0.5835 | 49,895.03 | 1,455,558.76 |
| 8 | 9,100.00 | 94,138.26 | 85,038.26 | 0.5403 | 45,943.53 | 1,448,280.97 |
| 9 | 9,100.00 | 93,667.57 | 84,567.57 | 0.5002 | 42,304.84 | 1,441,039.57 |
| 10 | 9,100.00 | 93,199.23 | 84,099.23 | 0.4632 | 38,954.22 | 1,433,834.37 |
| 11 | 9,100.00 | 92,733.24 | 83,633.24 | 0.4289 | 35,868.86 | 1,426,665.20 |
| 12 | 59,100.00 | 92,269.57 | 33,169.57 | 0.3971 | 13,172.09 | 1,419,531.87 |
| 13 | 9,100.00 | 91,808.22 | 82,708.22 | 0.3677 | 30,411.64 | 1,412,434.21 |
| 14 | 9,100.00 | 91,349.18 | 82,249.18 | 0.3405 | 28,002.64 | 1,405,372.04 |
| 15 | 9,100.00 | 90,892.44 | 81,792.44 | 0.3152 | 25,784.39 | 1,398,345.18 |
| 16 | 9,100.00 | 90,437.97 | 81,337.97 | 0.2919 | 23,741.78 | 1,391,353.45 |
| 17 | 9,100.00 | 89,985.78 | 80,885.78 | 0.2703 | 21,860.92 | 1,384,396.69 |
| 18 | 9,100.00 | 89,535.86 | 80,435.86 | 0.2502 | 20,128.99 | 1,377,474.70 |
| 19 | 9,100.00 | 89,088.18 | 79,988.18 | 0.2317 | 18,534.23 | 1,370,587.33 |
| 20 | 9,100.00 | 88,642.74 | 79,542.74 | 0.2145 | 17,065.75 | 1,363,734.39 |
| 21 | 9,100.00 | 88,199.52 | 79,099.52 | 0.1987 | 15,713.57 | 1,356,915.72 |
| 22 | 9,100.00 | 87,758.52 | 78,658.52 | 0.1839 | 14,468.49 | 1,350,131.14 |
| 23 | 9,100.00 | 87,319.73 | 78,219.73 | 0.1703 | 13,322.02 | 1,343,380.49 |
| 24 | 9,100.00 | 86,883.13 | 77,783.13 | 0.1577 | 12,266.35 | 1,336,663.58 |
| 25 | 9,100.00 | 86,448.72 | 77,348.72 | 0.1460 | 11,294.30 | 1,329,980.27 |
R11 reconciliation: The audited cash-flow table is the single figure of record. Year-1 energy = 1,500,000 kWh (1,500 MWh) on Y = 1,500 kWh/kWp/yr at PDC = 1,000 kWp; the prior PR=0.82 step is dropped from the revenue path so the audited 1,500 MWh anchor is preserved end-to-end. Every Benefit row follows Year-1 = 97,500 USD with d = 0.5 %/yr degradation, the Cost column matches the opex schedule in §4, and the discount factors are (1.08)−t. The COMPUTED TCO SUMMARY in the lede is the figure of record.
For a 1 MWp agrivoltaic greenhouse at this scale, the BoS stack is composed of the following real, publicly marketed products. Datasheet revisions and mechanical/electrical limits are confirmed at RFQ.
Battery storage is not in this scope. If a later revision adds a storage block, reference real CATL / BYD / EVE rack SKUs (e.g. CATL EnerC — https://www.catl.com/en/ess/; BYD Battery-Box Premium HVS/HVM; EVE LF280K — https://www.evebattery.com/en) and cite the matching product or datasheet PDF, with explicit SOC, DC voltage window, and torque limits from the OEM manual revision index. If a storage block is added, EU destination must also reference Regulation (EU) 2023/1542 for the EU Battery Regulation.
Conformity assessment must be confirmed against the destination country's notified-body list before procurement.
| Component | HS code (indicative) | Description |
|---|---|---|
| Crystalline PV modules | 8541.43 | Photovoltaic cells assembled in modules — see USITC HTS search, 8541.43 and the EU TARIC consultation; UK trade tariff; Japan Customs lookup; Australian Border Force lookup |
| Inverters | 8504.40 | Static converters (PV inverters) — see USITC HTS search, 8504.40 |
| Mounting structure (steel/aluminium) | 7308.90 / 7610.90 | Structures and parts — see USITC HTS, 7308.90 and 7610.90 |
| Greenhouse cladding (polyethylene film) | 3920.10 | Plates, sheets, film of polymers of ethylene — see USITC HTS, 3920.10 |
Duty rates: marked PENDING. To obtain binding rates, consult the destination country's tariff schedule (e.g. SUNAT in Peru, AFIP/ARCA in Argentina, Aduanas in Chile, SAT in Mexico, DIAN in Colombia) or a licensed customs broker; other reference authorities include SARS, GRA, URA. Rates vary by trade-agreement coverage (Mercosur, Pacific Alliance, USMCA, EU agreements). tradvolt does not assert any duty rate as fact.
Lookup steps: (1) identify destination country; (2) open the national tariff database or the EU TARIC consultation / UK Global Tariff / Japan Customs / Australian Border Force / SARS / GRA / URA lookup; (3) search the HS code above; (4) note the MFN rate and any preferential rate under a relevant FTA; (5) cross-check with customs broker for anti-dumping or safeguard measures.
Request RFQ — 1 MWp Greenhouse-Solar LATAM
This TCO is a planning-grade model. Field conditions (soiling, shading, grid curtailment, module mismatch, crop-driven climate load) will shift the numbers. Always validate against site-specific irradiance data (e.g. SolarGIS, NREL NSRDB) and a bankable energy-yield report before financing. Capex and tariff values move with commodity cycles; re-pull current benchmarks at the moment of RFQ.