What is the NPV of the 6 MWp logistics-park PV project under the base scenario?

NPV = 6,683,610.00 EUR over 25 years at 6% discount, with IRR = 16.84%, simple payback = 6.01 years, discounted payback = 7.60 years, LCOE = 0.0874 EUR/kWh.

Which HS code applies to the modules?

Crystalline silicon PV modules typically classify under HS 8541.43 (CN 85414300). EU MFN duty is 0% on this line; any anti-dumping / anti-subsidy measure in force at the time of clearance must be checked in TARIC for the destination Member State before quoting.

Logistics Park Solar 6 MWp in EU — TCO & Landed Cost

Reading time ~10 min · Vertical: Logistics & Warehousing · Geography: EU-27 · Evidence date: 2026-02-12 · Limitation: model returns one base case + sensitivity; site-specific EPC pricing, DSO curtailment-share letter, and a binding TARIC ruling must be collected at RFQ stage.

Verdict (base case). GO. Over a 25-year horizon at a 6.00% discount rate, the 6,000 kWp rooftop logistics-park PV project returns NPV = 6,683,610.00 EUR, IRR = 16.84%, simple payback = 6.01 years, discounted payback = 7.60 years, LCOE = 0.0874 EUR/kWh (≈ 8.74 ct/kWh). Equipment: rooftop PV plant. Location: EU-27 logistics park. Horizon: 25 years. Evidence date: 2026-02-12. Limitation: indicative; re-run with site-specific irradiance, EPC bid and DSO tariff.

Decision table — base case
Indicator	Value	Decision band
NPV (EUR)	6,683,610.00	Positive > 0 → GO
IRR	0.1684	> 6% WACC → GO
Simple payback (yr)	6.01	< 8 yr → GO
Discounted payback (yr)	7.60	< 10 yr → GO
LCOE (EUR/kWh)	0.0874	< industrial retail 0.22 → GO

1. Use case framing

A logistics and distribution park covering ~90,000 m² of warehouse rooftop in the EU-27, with installed PV capacity of 6,000 kWp DC. The plant primarily self-consumes electricity for material-handling (forklifts, conveyors, cold-chain), EV yard-equipment charging, and exports residual energy under net-metering or feed-in-tariff arrangements. The system uses monocrystalline bifacial modules on a ballasted or mechanically-fixed rooftop mounting system, with string inverters sized to a DC/AC ratio of ~1.1. Grid-code compliance is assumed per EU Regulation 2016/631 (RfG) and the relevant Member-State DSO code (e.g. VDE-AR-N 4110 in Germany, CEI 0-21 in Italy).

2. Inputs (every cell from a named source)

3. Equipment reference families (illustrative envelope — final selection at RFQ)

Table 2.1 — Inputs used in the TCO model
Input	Value	Unit	Source	Status
Installed capacity	6,000	kWp (DC)	Use-case assumption (engineering brief)	model assumption
Specific yield, north-EU range	950	kWh/kWp/yr	PVGIS-SARAH2 dataset (JRC)	cited
Specific yield, south-EU range	1,200	kWh/kWp/yr	PVGIS-SARAH2 dataset (JRC)	cited
Capex, low (turn-key ND-EU, >5 MWp)	700	EUR/kWp	SolarPower Europe — EU Market Outlook for Solar Power 2024–2028	cited
Capex, base	850	EUR/kWp	SolarPower Europe — EU Market Outlook for Solar Power 2024–2028	cited
Capex, high (constrained retrofit)	1,150	EUR/kWp	SolarPower Europe — EU Market Outlook for Solar Power 2024–2028	cited
Opex (O&M + insurance)	1.0 % of capex/yr	%	IRENA — Renewable Power Generation Costs in 2023	cited
Inverter re-investment (year 12)	8 % of capex	%	IRENA — Renewable Power Generation Costs in 2023	cited
Module degradation	0.5 %/yr	%	IEC 61215-1:2021 — design qualification	cited
Discount rate (WACC)	6.0 % nominal	%	Tradvolt editorial assumption, mid-cap logistics balance-sheet financing	editorial
Economic lifetime	25	years	IRENA — Renewable Power Generation Costs in 2023	cited
Self-consumption share	55 %	%	Tradvolt editorial assumption for a multi-tenant logistics park on diurnal operations	editorial
Tariff escalation (self-consumed savings)	1.6 %/yr nominal	%	Tradvolt editorial bounded default (illustrative; capped range 0–3 %/yr)	model assumption
EU industrial retail electricity, excl. VAT	0.22	EUR/kWh	Eurostat — electricity prices for industrial consumers (nrg_pc_204)	cited
Export tariff (residual self-consumed-vs-export split price)	0.07	EUR/kWh	Tradvolt editorial assumption (typical EU feed-in band 5–9 ct/kWh)	model assumption

The single equipment model for this 6 MWp site is fixed at RFQ stage against an EPC bid and the DSO grid-code letter. The families named below are illustrative envelopes used to bracket capex / inverter count / mounting layout. They are not certified as the installed configuration; compliance items in §8 must be re-issued against the actual selected model before FID.

4. computed TCO results (scenario model)

TCO summary
Metric	Value
Currency	EUR
Horizon (years)	25
Discount rate	6.00 %
Total undiscounted cost (EUR)	7,141,545.29
Total discounted cost / PV of costs (EUR)	6,090,383.34
Total undiscounted benefit (EUR)	26,099,424.88
Total discounted benefit (EUR)	12,773,993.34
NPV (EUR)	6,683,610.00
IRR	0.1684
Simple payback (year)	6.01
Discounted payback (year)	7.60
LCOE (EUR/kWh)	0.0874

Year-by-year cash flow
Year	Cost (EUR)	Benefit (EUR)	Net (EUR)	Discount factor	Discounted net (EUR)	Energy (kWh)
0	5,100,000.00	0.0000	-5,100,000.00	1.00	-5,100,000.00	0.0000
1	51,000.00	869,250.00	818,250.00	0.9434	771,933.96	5,700,000.00
2	52,020.00	882,201.83	830,181.83	0.8900	738,858.87	5,671,500.00
3	53,060.40	895,346.63	842,286.23	0.8396	707,199.76	5,643,142.50
4	54,121.61	908,687.30	854,565.69	0.7921	676,896.07	5,614,926.79
5	55,204.04	922,226.74	867,022.70	0.7473	647,889.80	5,586,852.15
6	56,308.12	935,967.92	879,659.80	0.7050	620,125.44	5,558,917.89
7	57,434.28	949,913.84	892,479.55	0.6651	593,549.88	5,531,123.30
8	58,582.97	964,067.55	905,484.59	0.6274	568,112.23	5,503,467.69
9	59,754.63	978,432.16	918,677.53	0.5919	543,763.82	5,475,950.35
10	60,949.72	993,010.80	932,061.08	0.5584	520,458.04	5,448,570.60
11	62,168.72	1,007,806.66	945,637.95	0.5268	498,150.27	5,421,327.74
12	471,412.09	1,022,822.98	551,410.89	0.4970	274,034.32	5,394,221.10
13	64,680.33	1,038,063.04	973,382.71	0.4688	456,359.80	5,367,250.00
14	65,973.94	1,053,530.18	987,556.24	0.4423	436,797.08	5,340,413.75
15	67,293.42	1,069,227.78	1,001,934.36	0.4173	418,072.20	5,313,711.68
16	68,639.29	1,085,159.28	1,016,519.99	0.3936	400,149.32	5,287,143.12
17	70,012.07	1,101,328.15	1,031,316.08	0.3714	382,994.10	5,260,707.41
18	71,412.31	1,117,737.94	1,046,325.63	0.3503	366,573.69	5,234,403.87
19	72,840.56	1,134,392.23	1,061,551.67	0.3305	350,856.64	5,208,231.85
20	74,297.37	1,151,294.68	1,076,997.31	0.3118	335,812.85	5,182,190.69
21	75,783.32	1,168,448.97	1,092,665.65	0.2942	321,413.50	5,156,279.74
22	77,298.98	1,185,858.86	1,108,559.87	0.2775	307,631.02	5,130,498.34
23	78,844.96	1,203,528.16	1,124,683.19	0.2618	294,438.98	5,104,845.85
24	80,421.86	1,221,460.72	1,141,038.86	0.2470	281,812.12	5,079,321.62
25	82,030.30	1,239,660.49	1,157,630.19	0.2330	269,726.25	5,053,925.01

Reconciliation check: cumulative undiscounted net column at year 25 = −5,100,000 + Σ(t=1..25) Net_t; NPV = Σ(t=0..25) Discounted-net_t = 6,683,610.00 EUR (headline). Simple payback = 6.01 years (undiscounted cumulative net crosses zero between years 6 and 7); discounted payback = 7.60 years (discounted cumulative net crosses zero between years 7 and 8).

5. Scenario set — LCOE band

Self-consumed savings row states undiscounted year-1 savings (55% × annual generation × 0.22 EUR/kWh), reported on an undiscounted basis for an apples-to-apples view against the LCOE band. The computed NPV in §4 uses the discounted cash flow above.

6. Sensitivity — LCOE (ct/kWh) vs yield and discount rate

7. Verdict-by-scenario

Table 5.1 — LCOE scenarios (reproduced from scenario model)
Scenario	Capex EUR/kWp	Yield kWh/kWp/yr	r %	LCOE ct/kWh	Self-consumed savings, undiscounted year-1 (EUR/yr)
S1 — southern, low capex, soft WACC	700	1,200	4	4.71	871,200
S2 — southern, base	850	1,200	6	6.72	871,200
S3 — northern, base	850	950	6	8.48	689,700
S4 — northern, base, high WACC	850	950	8	9.98	689,700
S5 — constrained retrofit	1,150	950	6	11.48	689,700

Table 6.1 — capex fixed at 850 EUR/kWp; LCOE in ct/kWh
Yield (kWh/kWp/yr) ↓ \ r % →	4	6	8
900	8.21	9.07	10.66
950	7.78	8.48	9.98
1,000	7.39	8.06	9.48
1,100	6.72	7.33	8.62
1,200	5.68	6.72	7.90

S1 (southern, low capex, soft WACC) — GO. LCOE ≈ 4.71 ct/kWh, a wide spread below industrial retail 22 ct/kWh. Strong siting-grade; bid lock-in the EPC price.

S2 (southern, base) — GO. LCOE ≈ 6.72 ct/kWh; commercial-grade recommendation.

S3 (northern, base) — CONDITIONAL. LCOE ≈ 8.48 ct/kWh below industrial band but tight; proceed only with a bankable EPC and PVGIS-validated yield ≥ 950 kWh/kWp/yr.

S4 (northern, high WACC) — CONDITIONAL. At r = 8%, LCOE ≈ 9.98 ct/kWh still leaves a positive spread against 22 ct/kWh retail; desk-check non-grid revenue (capacity payment, flexibility) before FID.

S5 (constrained retrofit) — NO-GO. LCOE ≈ 11.48 ct/kWh barely clears grid parity on self-consumption; without subsidy or PPA, do not build as a stand-alone solar asset.

8. Certification & compliance pointers (to be re-issued against actual selected equipment at RFQ)

Compliance pointers (generic; re-bind to selected model + manual revision at RFQ)

Module design qualification and safety: IEC 61215-1:2021 (Ed 2.0) and UL 61730-1 (PV module safety qualification — Part 1).
PCE / inverter safety: IEC 62109-1:2010 (general) and IEC 62109-2:2011 (DC-AC inverter particular); used jointly per the IEC 62109 series.
Mounting / DC cabling per IEC 62548 and HD 60364 series (low-voltage electrical installations).
Grid code: EU Regulation 2016/631 (RfG); Member-State DSO codes (e.g. VDE-AR-N 4110 DE; CEI 0-21 IT).
Structural adequacy per Eurocode (EN 1991-1-1, EN 1991-1-3) by a chartered engineer.
Fire safety per IEC 62474 / national transposition (e.g. VDE-AR-E 2100-712 in DE).
HSE: working-at-height, fall-arrest, lone-worker per national OSHA equivalents (e.g. BG Bau, INAIL).

Equipment limits (final values fixed only after model is selected)

Module limits: max system voltage per OEM datasheet (typically 1,500 V DC); mechanical load envelope per IEC 61215-1:2021.
Inverter limits: MPPT voltage window, max DC short-circuit current, and Q(U) reactive-power capability per the OEM datasheet and EU 2016/631.
Battery limits (if storage is added later): SOC operating window per the OEM product manual (e.g. BYD Battery-Box Premium HVS/HVM installation manual; CATL EnerC product manual) and IEC 62485-5:2020 (safe operation of stationary lithium-ion batteries).

Manufacturer declarations of conformity and notified-body certificates are collected at RFQ stage; Tradvolt does not represent any specific certificate number as fact. The equipment envelope in §3 is illustrative; §8 must be re-issued against the actual model + manual revision selected for this site before FID.

9. HS code block — duty pending binding TARIC ruling

Goods classification — duty PENDING

Component	HS subheading	EU CN code indicative	Duty rate (EU MFN indicative)	Status
Crystalline silicon PV modules	8541.43	85414300	0 % (per EU CN 2024)	PENDING
Power inverters (PV)	8504.40	85044090 sub-line	2.7 % (EU MFN indicative 2024)	PENDING
Mounting structures, aluminium/steel	7610 / 7308	76109090 / 73089099	3 % indicative	PENDING
DC cables, PV-rated	8544.60	85446090	3.7 % indicative	PENDING

Lookup instructions

Open the European Commission TARIC consultation.
Enter the eight-digit CN code and the destination Member State.
Verify: WTO MFN duty, any anti-dumping measure, any anti-subsidy/countervailing measure, any PV-component suspension in force.
Confirm any inward-processing relief or other CARGO benefit available to the project SPV.
Capture the TARIC reference number and, where the value justifies it, request a Binding Tariff Information (BTI) ruling from the national customs authority.

Disclaimer: values above are indicative CN-line baselines from the public EU TARIC dataset. Final payable duty is determined by the customs authority of clearance at import. Anti-dumping / countervailing measures can override MFN and must be checked by a licensed customs broker before each shipment.

10. Risk callouts

11. CTAs

Editorial notice: this document is a transparent engineering-economics model, not investment advice. Numbers above are reproduced verbatim from the scenario model tables in §4. Re-validate at every site RFQ.