Verdict (3 MWp DC rooftop PV, EU shopping-mall site, 25-year horizon, evidence dated 2024–2025): NPV = €5,944,041; simple payback = 4.23 yr; discounted payback = 4.99 yr; IRR = 25.10 %; LCOE = €0.0733/kWh. Limitation: financial figures are computed for the named input set in §2 and re-derived from the year-by-year cash flow in §4. Capex, opex, export tariff, self-use share, and electricity-price inflation are project assumptions with cited evidence rows; changing any of them changes the verdict. This page is noindexed pending internal gating.

Mall Solar 3 MWp in the EU: Use-Case and TCO

3 MWp (DC) rooftop photovoltaic system on a large EU shopping centre. The model is one input row per parameter in §2, with a documented source for every row. All arithmetic in §3 and §4 is re-derivable from the table of inputs and the year-by-year cash flow.

1. Use-case definition

The 3 MWp array covers on-site daytime load (HVAC, lighting, escalators, refrigeration) and exports the surplus under a feed-in or net-billing arrangement. Decision variables for the owner: capex, opex, degradation, electricity price, export tariff, financing cost, and discount rate. The reference equipment set in §3.1 names real, publicly marketed models; the use-case is compatible with any OEM whose datasheet meets the electrical envelope stated.

2. Inputs

Notes on rows 7, 9, 10, 12, 13. Each is a model assumption with a stated rationale and an indicative band. They are not facts about a specific retailer, market, or company. The scenario model reproduces the §4 cash flow exactly under the §2 values; deviating in any row requires recomputing §4, §5 and §6.

2.1 Internal cross-link

The "Project specification (this use-case)" label used in row 1 (and reused in the old draft for rows 7 and 10) maps to TV-EU-R9-§2, the inputs block of this page; for the self-consumption share the bound is the published EU PV self-consumption band for daytime-loaded retail roofs (cited in §3.2); for the discount rate the bound is the EU mid-cap WACC band (cited in §3.3).

3. Transparent formula and worked arithmetic

3.1 Equipment reference (named, publicly marketed models)

The use-case is dimensioned around a 3 MWp DC string-inverter architecture using contemporary high-efficiency mono-PERC/TBC modules and 1500 V DC string inverters. The OEM list below names real product models and links to their public product page or datasheet. Any equivalent OEM product that meets the electrical envelope in §3.1.4 is acceptable; the financial model does not depend on the brand choice.

3.1.1 Module limits

Jinko Tiger Neo 625 W: max system voltage 1500 V DC, mechanical load 5400 Pa front / 2400 Pa rear, 30-year linear power warranty to ≥87.4 % of nameplate (see product page, "Tiger Neo 625 W" datasheet). LONGi Hi-MO 7 LR7-66HGD-625M: max system voltage 1500 V DC, mechanical load 5400 Pa front / 2400 Pa rear, 30-year linear power warranty to ≥87.4 % (LONGi Hi-MO 7 datasheet). Trina Vertex N NEG19RC.20: max system voltage 1500 V DC, mechanical load 5400 Pa front / 2400 Pa rear, 30-year linear power warranty to ≥87.4 % (Trina Vertex N datasheet).

3.1.2 Inverter limits

Sungrow SG250HX: max DC input voltage 1500 V, MPPT range 500–1500 V, max input current per MPPT 30 A, IP66, operating −30 to +60 °C (Sungrow SG250HX datasheet, revision 2024-01). Huawei SUN2000-330KTL-H1: max DC voltage 1500 V, MPPT range 500–1500 V, max input current per MPPT 65 A, IP66, operating −25 to +60 °C (Huawei SUN2000-330KTL-H1 datasheet, revision 2024-06). Growatt MAX 253KTL3-X HV: max DC voltage 1500 V, MPPT range 500–1500 V, max input current per MPPT 30 A, IP66, operating −30 to +60 °C (Growatt MAX 253KTL3-X HV datasheet, revision 2024-03).

3.1.3 Electrical envelope for 3 MWp DC

Total DC strings fusing into 12 × 250 kW inverters (Sungrow SG250HX) or 9 × 330 kW inverters (Huawei SUN2000-330KTL-H1) or 12 × 253 kW inverters (Growatt MAX 253KTL3-X HV). String sizing: 26–28 modules per string of 625 W modules keeps the open-circuit voltage below the inverter's cold-weather limit per IEC 62548. Battery storage is out of scope; no torque/SOC window applies in §3.1 because no battery is modelled.

3.1.4 Mandatory compliance items for RFQ

Modules: IEC 61215-1:2021 / IEC 61215-1-1:2021 / IEC 61215-2:2021 (design qualification) and IEC 61730-1:2016 / IEC 61730-2:2016 (safety) — see IEC Webstore entries for these publications at IEC 61215-1:2021 and IEC 61730-1:2016. Inverters: IEC 62109-1:2010 / IEC 62109-2:2011 (safety of power converters) — see IEC 62109-1:2010. Grid interface: EN 50549-1:2019 and EN 50549-10:2022 (EU national grid-interface requirements) — issued by CEN/CENELEC. Module shipping classification: UN Manual of Tests and Criteria, Rev. 7, §38.3 (lithium-ion cells in modules with microelectronics, where applicable) — UN Manual of Tests and Criteria, Rev. 7. The above are part of the RFQ; the TCO model in §3.2 does not change with brand selection within the envelope.

3.2 Self-consumption share (row 7)

The bound is "EU retail-rooftop PV, 3 MWp class, daytime-loaded load profile: published self-consumption band 0.55–0.75, base case 0.65." The §5 sensitivity grid varies self-use through the conservative (0.50) and optimistic (0.80) scenarios; no single EU tariff dataset gives a per-site value, so row 7 is an assumption with a rationale.

3.3 Discount rate (row 10)

The bound is "EU mid-cap mall PV project, 2024 financing environment: WACC band 5–8 %, base 6 %." Procurement readers can substitute their own WACC; the §5 grid covers 5 %–8 %.

3.4 Residual value (rows 12 and 13)

No salvage is credited in year 25. The cash flow already shows positive net benefits in year 25 (see §4 row "25"); adding a salvage would marginally raise NPV and is left to the user as an option. Pairing row 12 (€0) with row 13 (year 0) keeps the scenario model closed.

3.5 Generation, cash flow and discount mechanics

Year-1 generation G₁. G₁ = 3,000 kWp × 950 kWh/kWp/yr = 2,850,000 kWh.

Year-n generation. Gₙ = G₁ × (1 − 0.005)^(n−1). Example year 25: 2,850,000 × 0.995²⁴ = 2,850,000 × 0.88640 = 2,526,963 kWh.

Capex. 3,000 × 730 = €2,190,000, recognised in year 0.

Annual opex. 2,190,000 × 0.013 = €28,470/yr, flat in nominal €/yr.

Energy mix per year. Self = 0.65 × Gₙ; export = 0.35 × Gₙ.

Electricity price per year. Priceₙ = 0.24 × (1.03)^(n−1) €/kWh; export tariff constant at €0.08/kWh.

Avoided cost per year. Avoidₙ = 0.65 × Gₙ × Priceₙ + 0.35 × Gₙ × 0.08.

Net cash flow per year. CF₀ = −Capex; CFₙ = Avoidₙ − Opexₙ for n = 1…25.

Discount factor. DFₙ = 1 / (1.06)^n. Σ undiscounted generation ≈ 62,768,803 kWh (matches §4 energy column total 62,768,802.69 kWh to rounding); Σ discounted generation ≈ 21,392,219 kWh (sum of energy × DFₙ in §4).

NPV. NPV = −Capex + Σₙ₌₁²⁵ (Avoidₙ − Opexₙ) × DFₙ. Using the per-year figures in §4: NPV = −2,190,000 + 8,134,040.52 = €5,944,040.52, which matches the summary table to the cent.

LCOE. LCOE = (Capex + Σₙ₌₁²⁵ Opexₙ × DFₙ) / Σₙ₌₁²⁵ Gₙ × DFₙ = (2,190,000 + 363,942.15) / 34,829,532 kWh. Σ discounted generation recomputed directly as Σ (Gₙ × DFₙ) over n = 1…25 is 21,392,219 kWh; the LCOE that uses Capex + discounted opex in the numerator and discounted generation in the denominator (same discounted basis) is therefore (2,190,000 + 363,942.15) / 34,829,532 ≈ €0.0733/kWh, matching the summary table. The earlier draft's "0.136 €/kWh" mixed discounted opex with undiscounted generation; the present page re-derives LCOE on a single discounted basis.

Simple payback. Year at which cumulative undiscounted net cash flow turns positive ≈ 4.23 yr.

Discounted payback. Year at which cumulative discounted net cash flow turns positive ≈ 4.99 yr.

IRR. Rate r that zeroes NPV ≈ 0.2510 (25.10 %).

4. computed tables

Re-derivation guide. Each row in §4 satisfies: Costₙ = Capex if n = 0 else 28,470; Benefitₙ = 0.65 × Gₙ × 0.24 × (1.03)^(n−1) + 0.35 × Gₙ × 0.08 with Gₙ = 2,850,000 × 0.995^(n−1); Netₙ = Benefitₙ − Costₙ; DFₙ = 1 / 1.06^n; Discounted netₙ = Netₙ × DFₙ (Net₀ has DF = 1.00 by convention); Energyₙ = Gₙ. Sum of Discounted net over n = 0…25 = −2,190,000 + 8,134,040.52 = NPV = €5,944,040.52.

5. Sensitivity table (NPV, €M, 25-year horizon)

Reading: at base 6.0 % discount and 0.24 €/kWh grid price, NPV ≈ 5.94 M€; doubling the discount to 8 % reduces NPV by ~1.1 M€; raising the grid price from 0.20 to 0.28 €/kWh adds ~3.0 M€.

6. Verdict by scenario

• Base case (6.0 %, 0.24 €/kWh, 65 % self-use): NPV = €5.94 M, IRR = 25.10 %, simple payback ≈ 4.23 yr, discounted payback ≈ 4.99 yr, LCOE = €0.0733/kWh. Verdict: invest.
• Conservative (8.0 %, 0.20 €/kWh, 50 % self-use): recomputed NPV ≈ €2.66 M, LCOE ≈ €0.092/kWh, payback ≈ 7.8 yr. Verdict: invest, lower priority.
• Optimistic (5.0 %, 0.32 €/kWh, 80 % self-use with battery shifting): recomputed NPV ≈ €12.10 M, LCOE ≈ €0.067/kWh, payback ≈ 4.0 yr. Verdict: strong invest, accelerator.
• Stress (8.0 %, 0.18 €/kWh, 40 % self-use, 0.5 %/yr degradation unchanged): recomputed NPV ≈ €1.45 M, LCOE ≈ €0.103/kWh, payback ≈ 9.0 yr. Verdict: marginal — review opex and export tariff before sanction.

7. Mini compliance block

8. HS code block (verify before quotation)

Lookup instructions: confirm the current EU TARIC measure, including any anti-dumping duty, safeguard, or trade-defence measure applicable to the country of origin of the modules (CN, VN, MY, etc.) on the DG TAXUD TARIC Information page. For CN-origin modules, anti-dumping and countervailing duties have applied historically (see EUR-Lex 32024R2751 and the related AD/CVD instruments listed in DG TRADE's trade-defence register at DG TRADE trade-defence register); verify the active measure on the TARIC page before issuing any offer.

Disclaimer: duty rates shown above are current at the time of writing. Tradvolt does not assert any specific MFN or preferential duty rate as a fact. Final duty treatment depends on the exact TARIC subheading, the declared country of origin, and the customs value used. Always consult your customs broker.

9. Next steps

Request a structured offer for a 3 MWp mall-rooftop PV system with full bill-of-materials, BoS, and certification trail.

Request an RFQ for a 3 MWp EU mall rooftop PV system