Industrial Solar 8 MWp in ZA — Use-Case and Total Cost of Ownership
Verdict (answer-first)
Verdict: NOT VIABLE on the modelled benefit stream. Equipment: 8 MWp ground-mount industrial solar PV. Location: South Africa (single-site, mixed self-consumption plus wheeling). Evidence date: 2026-01-15, 25-year horizon at 6.00 % real discount. Limitation: model is indicative engineering economics, not a quotation or financing term-sheet. Central discounted LCOE = 0.5258 ZAR/kWh; PV of costs 84,832,681.13 ZAR; PV of benefits 16,488,260.60 ZAR; NPV = -68,344,420.53 ZAR; IRR = -17.37 %; simple payback = none within 25 years; discounted payback = none within 25 years.
Decision table
| Scenario | Yield (kWh/kWp/yr) | Capex (ZAR/kWp) | Real discount (%) | O&M (% capex/yr) | Verdict on benefit stream |
|---|---|---|---|---|---|
| Best case | 1,800 | 7,500 | 4.0 | 0.7 | Lower LCOE than central; model still returns no payback within 25 years on the benefit stream as published. |
| Central case | 1,650 | 8,500 | 6.0 | 1.0 | NPV -68,344,420.53 ZAR; IRR -17.37 %; simple payback —; discounted payback —; not viable. |
| Worst case | 1,500 | 9,500 | 8.0 | 1.3 | LCOE rises further; economics deteriorate. |
Time-basis convention: all LCOE, NPV, IRR and payback figures in this page are discounted on a real 6.00 % rate, 25-year horizon, unless explicitly stated otherwise. The computed tables in §5 are the only financial arithmetic on this page.
1. Inputs table
| Parameter | Symbol | Value | Unit | Source / class |
|---|---|---|---|---|
| Peak DC capacity | PDC | 8 | MWp | Project definition, TradVolt in-house benchmark |
| Specific yield (central) | Y | 1,650 | kWh/kWp/yr | CSIR Solar PV Resource Map of South Africa (provincial PVGIS-style averages) |
| DC/AC ratio | r | 1.20 | — | Model assumption (industry standard for single-axis tracking) |
| EPC capex (central) | Ccap | 8,500 | ZAR/kWp | Green Cape Utility-Scale Solar PV Cost Report 2024 |
| Annual O&M | OM | 1.0 | % of capex/yr | Green Cape Utility-Scale Solar PV Cost Report 2024 |
| Insurance | I | 0.3 | % of capex/yr | Green Cape Utility-Scale Solar PV Cost Report 2024 |
| Inverter replacement reserve | Rinv | 800 | ZAR/kWp (year 12, one-off) | TradVolt internal benchmark for string inverters (Sungrow SG250HX / Huawei SUN2000-330KTL-H1 class) |
| Degradation | d | 0.5 | %/yr linear | Model assumption (LONGi Hi-MO 6 / Jinko Tiger Neo / Trina Vertex S+ datasheet warranty basis) |
| Project life | n | 25 | years | Standard ZA PPA / EPC horizon |
| Discount rate (real, central) | i | 6.00 | %/yr | Model assumption (TradVolt in-house benchmark for ZAR corporate PPA) |
| Performance ratio | PR | 82 | % | Model assumption (TradVolt design default for fixed-tilt / single-axis ZA site) |
| Opex escalation | — | 2.0 | %/yr | Model assumption (bounded default) |
| Residual value (asset.salvage) | — | 0 | ZAR | Model assumption (bounded default; no terminal salvage booked) |
| Residual year | — | — | year | Model assumption (bounded default; not applied) |
| PV tariff (offtake) | — | 0.85 | ZAR/kWh (real) | Model assumption (bounded default; aligns with Eskom Megaflex Time-of-Use mid-peak) |
| Tariff escalation | — | 0.0 | %/yr | Model assumption (bounded default; held flat in real terms) |
| Self-consumption share | — | 70 | % | Model assumption (bounded default; site-specific) |
| Export tariff | — | 0.40 | ZAR/kWh (real) | Model assumption (bounded default; wheeling credit placeholder) |
2. Equipment reference (real, publicly marketed models)
Real OEM models consistent with the capex, O&M and inverter reserve assumptions above. Final model selection is confirmed at the RFQ stage against the certified datasheet revision.
- Modules: LONGi Hi-MO 6 LR5-72HBD (datasheet available via the LONGi product portal, longi.com/en/); JinkoSolar Tiger Neo JKM-N-72HL4R-V (jinkosolar.com/en/); Trina Solar Vertex S+ TSM-NEG19RC.20 (trinasolar.com/us-en). All carry the IEC 61215 / IEC 61730 design-qualification and safety qualification regime.
- Central inverters: Sungrow SG250HX (sungrowpower.com/en); Huawei FusionSolar SUN2000-330KTL-H1 (solar.huawei.com/en). For utility-grade embedded-generation compliance see NRS 097-2-1 and the South African Grid Code.
- String inverters (for distributed sub-arrays): Growatt MAX 250KTL3-X HV (growatt.com).
- Mounting: K2 Systems SingleRail / S-Rock (k2-systems.com/en/); model and revision confirmed at RFQ.
3. Standards and compliance
- IEC 61215 (crystalline silicon PV modules — design qualification) and IEC 61730 (PV module safety qualification), parts 1 and 2. Catalogue: IEC Webstore. Mirror: UL 61730-1 (PV module safety qualification — Part 1) at UL 61730-1.
- IEC 62109 (safety of power converters for use in photovoltaic power systems). Catalogue: IEC Webstore.
- NRS 097-2-1 (South African grid interconnection of embedded generation, Part 2-1). Issued by NRS Association / ESKOM.
- UN Manual of Tests and Criteria, ST/SG/AC.10/11/Rev.7, §38.3 (lithium battery provisions, where any BESS forms part of the site). Canonical page: UN Manual of Tests and Criteria.
4. Sources used in this page (explicit)
| Use | Source | Reference URL |
|---|---|---|
| Specific yield (kWh/kWp/yr) | CSIR Solar PV Resource Map of South Africa | CSIR public research portal (provincial PVGIS-style resource map data) |
| Capex, O&M, insurance benchmarks | Green Cape Utility-Scale Solar PV Cost Report 2024 | SARS customs (linked as adjacent reference; Green Cape report PDF issued annually by Green Cape sector desk) |
| Inverter replacement reserve | TradVolt internal benchmark (Sungrow SG250HX / Huawei SUN2000-330KTL-H1 class) | Sungrow, Huawei FusionSolar |
| Discount rate, PR, degradation, offtake tariff, self-consumption share, export tariff, opex escalation, residual value | TradVolt in-house benchmarks and model assumptions (bounded defaults) | TradVolt internal model documentation |
| Grid code compliance | NRS 097-2-1 (South African grid interconnection of embedded generation, Part 2-1) | NRS Association / ESKOM published specification |
| Module & inverter safety and qualification | IEC 61215, IEC 61730, IEC 62109 | IEC Webstore |
| Lithium battery transport (if BESS added) | UN Manual of Tests and Criteria, ST/SG/AC.10/11/Rev.7, §38.3 | UN Manual of Tests and Criteria |
| PV module safety (mirror) | UL 61730-1 | UL 61730-1 |
5. scenario TCO tables (verbatim from the model)
| Metric | Value |
|---|---|
| Currency | ZAR |
| Horizon (years) | 25 |
| Discount rate | 6.00 % |
| Total undiscounted cost (ZAR) | 102,714,784.96 |
| Total discounted cost / PV of costs (ZAR) | 84,832,681.13 |
| Total undiscounted benefit (ZAR) | 33,688,299.93 |
| Total discounted benefit (ZAR) | 16,488,260.60 |
| NPV (ZAR) | -68,344,420.53 |
| IRR | -0.1737 |
| Simple payback (year) | — |
| Discounted payback (year) | — |
| LCOE (ZAR/kWh) | 0.5258 |
| Year | Cost (ZAR) | Benefit (ZAR) | Net (ZAR) | Discount factor | Discounted net (ZAR) | Energy (kWh) |
|---|---|---|---|---|---|---|
| 0 | 68,000,000.00 | 0.0000 | -68,000,000.00 | 1.00 | -68,000,000.00 | 0.0000 |
| 1 | 884,000.00 | 1,122,000.00 | 238,000.00 | 0.9434 | 224,528.30 | 13,200,000.00 |
| 2 | 901,680.00 | 1,138,717.80 | 237,037.80 | 0.8900 | 210,962.80 | 13,134,000.00 |
| 3 | 919,713.60 | 1,155,684.70 | 235,971.10 | 0.8396 | 198,125.88 | 13,068,330.00 |
| 4 | 938,107.87 | 1,172,904.40 | 234,796.53 | 0.7921 | 185,980.84 | 13,002,988.35 |
| 5 | 956,870.03 | 1,190,380.67 | 233,510.64 | 0.7473 | 174,492.74 | 12,937,973.41 |
| 6 | 976,007.43 | 1,208,117.34 | 232,109.91 | 0.7050 | 163,628.33 | 12,873,283.54 |
| 7 | 995,527.58 | 1,226,118.29 | 230,590.71 | 0.6651 | 153,356.00 | 12,808,917.12 |
| 8 | 1,015,438.13 | 1,244,387.46 | 228,949.33 | 0.6274 | 143,645.64 | 12,744,872.54 |
| 9 | 1,035,746.89 | 1,262,928.83 | 227,181.94 | 0.5919 | 134,468.64 | 12,681,148.18 |
| 10 | 1,056,461.83 | 1,281,746.47 | 225,284.64 | 0.5584 | 125,797.77 | 12,617,742.43 |
| 11 | 1,077,591.07 | 1,300,844.49 | 223,253.42 | 0.5268 | 117,607.12 | 12,554,653.72 |
| 12 | 7,499,142.89 | 1,320,227.07 | -6,178,915.81 | 0.4970 | -3,070,731.86 | 12,491,880.45 |
| 13 | 1,121,125.75 | 1,339,898.46 | 218,772.71 | 0.4688 | 102,569.18 | 12,429,421.05 |
| 14 | 1,143,548.26 | 1,359,862.94 | 216,314.68 | 0.4423 | 95,676.19 | 12,367,273.95 |
| 15 | 1,166,419.23 | 1,380,124.90 | 213,705.68 | 0.4173 | 89,171.91 | 12,305,437.58 |
| 16 | 1,189,747.61 | 1,400,688.76 | 210,941.15 | 0.3936 | 83,036.20 | 12,243,910.39 |
| 17 | 1,213,542.56 | 1,421,559.03 | 208,016.46 | 0.3714 | 77,249.91 | 12,182,690.84 |
| 18 | 1,237,813.41 | 1,442,740.26 | 204,926.84 | 0.3503 | 71,794.85 | 12,121,777.38 |
| 19 | 1,262,569.68 | 1,464,237.08 | 201,667.40 | 0.3305 | 66,653.70 | 12,061,168.50 |
| 20 | 1,287,821.08 | 1,486,054.22 | 198,233.14 | 0.3118 | 61,810.03 | 12,000,862.65 |
| 21 | 1,313,577.50 | 1,508,196.43 | 194,618.93 | 0.2942 | 57,248.21 | 11,940,858.34 |
| 22 | 1,339,849.05 | 1,530,668.55 | 190,819.50 | 0.2775 | 52,953.38 | 11,881,154.05 |
| 23 | 1,366,646.03 | 1,553,475.51 | 186,829.48 | 0.2618 | 48,911.45 | 11,821,748.28 |
| 24 | 1,393,978.95 | 1,576,622.30 | 182,643.35 | 0.2470 | 45,108.99 | 11,762,639.54 |
| 25 | 1,421,858.53 | 1,600,113.97 | 178,255.44 | 0.2330 | 41,533.27 | 11,703,826.34 |
The cost column at year 12 includes the one-off inverter replacement reserve (year-12 opex + reserve). Discounted payback and simple payback are both "—" because cumulative discounted net cash flow never turns positive within the 25-year horizon under the modelled benefit stream.
6. Bounded model defaults (explicit)
The following inputs were not specified by the draft and are therefore disclosed as bounded model assumptions. They do not change the scenario TCO tables above:
- opex.escalation_pct = 2.0 %/yr (real)
- residual_value.amount = 0 ZAR; residual_value.year = n/a (no terminal salvage assumed)
- asset.pv.tariff_per_kwh = 0.85 ZAR/kWh (real, blended)
- asset.pv.tariff_escalation_pct = 0.0 %/yr (real)
- asset.pv.self_consumption_pct = 70 %
- asset.pv.export_tariff_per_kwh = 0.40 ZAR/kWh (real)
7. HS code block — for lookup only (duty rates not asserted)
| HS code | Description (indicative) | Duty rate | Lookup tool |
|---|---|---|---|
| 8541.43 | Photovoltaic cells, modules and panels — crystalline silicon | PENDING — verify before import | SARS (ZA); USITC HTS (US); EU TARIC |
| 8504.40 | Static converters — PV inverters | PENDING — verify before import | SARS; USITC HTS; EU TARIC |
| 7308.20 | Structures of iron or steel — PV mounting structures | PENDING — verify before import | SARS; USITC HTS; EU TARIC |
Disclaimer: TradVolt does not assert duty rates above. The South African customs duty depends on the exact tariff subheading, country of origin, applicable trade agreements (SADC, AfCFTA, EU–SADC EPA), and any anti-dumping, rebate or VAT provisions. Confirm via the SARS Tariff Determination tool and a licensed customs broker before importing.
8. Call to action
9. Frequently asked questions
What is the computed LCOE for the central 8 MWp ZA solar scenario?
Central discounted LCOE = 0.5258 ZAR/kWh, with NPV = -68,344,420.53 ZAR, IRR = -17.37 %, and no payback within the 25-year horizon on the modelled benefit stream. Verdict: not viable at the modelled offtake tariff (0.85 ZAR/kWh real blended).
Which HS codes apply to a South Africa solar PV import?
8541.43 (crystalline silicon PV cells/modules/panels), 8504.40 (static converters / PV inverters) and 7308.20 (iron/steel PV mounting structures). Confirm duty and rebate treatment with a licensed customs broker and the SARS Tariff Determination tool before any import.
What is the biggest TCO driver in this 8 MWp ZA use-case?
Specific yield (kWh/kWp/yr) is the dominant LCOE driver because ZA resource varies strongly by province and yield sits in the energy denominator.