Mining-Camp 2 MWh ESS in the EU — Use-Case & TCO

Verdict (answer-first). At the scenario TCO inputs — EU hard-rock mining camp, 10-year horizon, 6.00% real discount rate, EUR, evidence-date 2026-09-22 — the project does not recover its own incremental cost within the horizon. Headline figures (computed, copied verbatim from the COMPUTED TABLES): NPV = −5,046,717.85 EUR; IRR = n/a; simple payback = — (not reached); discounted payback = — (not reached); LCOS = 1.40 EUR/kWh.

1 — Scope and stack definition

This page covers a 2 MWh battery energy storage system (BESS) deployed at a hard-rock mining camp in the European Union, paired with a behind-the-meter (BTM) PV array and an existing diesel genset fleet. The camp is represented as operating 24/7, with an average site load dominated by HVAC, dewatering pumps, comms towers, and crushing/conveying. Stack components used as the basis for the TCO:

• 2 MWh BESS, LFP prismatic cells, 1C-capable, with a hybrid inverter plant (4 × 500 kW), MV transformer, MV switchgear, EMS/SCADA, fire suppression (aerosol + water mist), climate-controlled containers.
• 4 MWp ground-mount PV on the available camp footprint (disturbed land only).
• Existing diesel genset farm retained as the balancing asset (see §3).

Boundaries: 10-year horizon, real discount rate 6.00%, O&M flat-indexed at 2.0%/yr, diesel price €1.10/L (representative landed cost to a remote EU site).

2 — Equipment stack with named, publicly marketed models

The TCO below is parametric over the stack; the equipment rows below are the BESS-architecturally-equivalent products we would scope at RFQ. Datasheets cited are the public OEM product pages; cabinet-level ratings must be confirmed against the project-specific datasheet revision at the FAT.

2.1 — Reference standards (cited as full designation + edition)

• IEC 62933-5-2:2025 ed2.0 — Safety requirements for grid-integrated energy storage systems (EES), life-cycle. IEC Webstore home (cite full designation IEC 62933-5-2:2025 ed2.0 in text; deep publication URLs not in the evidence pack).
• IEC 63056:2020 — Safety requirements for battery-based energy storage systems (BESS) — lithium batteries (up to 1500 V DC); builds on IEC 62619; covers HESS/PV and large on/off-grid storage. IEC Webstore — IEC 63056:2020.
• IEC 62619:2022 ed2.0 — Safety requirements for secondary lithium cells and batteries for use in industrial applications incl. stationary/ESS (TC 21/SC 21A). IEC Webstore — IEC 62619:2022 ed2.
• UN 38.3 (UN Manual of Tests and Criteria, ST/SG/AC.10/11/Rev.7) — lithium battery transport provisions. UN Manual of Tests and Criteria (Rev.7).
• IEC 62485-5:2020 — Safety requirements for secondary batteries and battery installations — Part 5: Safe operation of stationary lithium-ion batteries (TC 21, 76 pp). IEC Webstore — IEC 62485-5:2020.
• IEC 62109-1:2010 / IEC 62109-2:2011 / IEC 62109-3:2020 — Safety of power converters for use in PV power systems (general + particular + module-integrated electronics). IEC 62109-1:2010 · IEC 62109-2:2011 · IEC 62109-3:2020.
• IEC 61215-1:2021 ed2.0 — Design qualification test requirements for c-Si and thin-film flat-plate PV modules (bifacial test instructions, NMOT removed). IEC Webstore — IEC 61215-1:2021.
• UL 1973 — Batteries for Use in Stationary and Motive Auxiliary Power Applications. UL 1973 standard page.
• UL 61730-1 — Photovoltaic (PV) Module Safety Qualification — Part 1. UL 61730-1 standard page.
• IEC 61851-1:2017 — Electric vehicle conductive charging system — Part 1 (cited as the EV-charging interface reference, not part of the BESS scope). IEC Webstore — IEC 61851-1:2017.

3 — Inputs to the TCO model

The scenario model takes the following inputs. Where a value is not directly supported by a primary OEM datasheet, customs source, or named dataset URL, it is flagged as a model assumption (see §4 and §11).

4 — Methodology in one paragraph

Each row of the year-by-year cash flow in §5 is taken verbatim from the COMPUTED TABLES. Costs in year 0 are the entire project Capex (BESS + PV + integration = €4,420,000.00). Operating costs from year 1 onwards escalate at 2.0%/yr. Benefits are the avoided marginal cost of diesel plus the per-kWh discharged credit and any value of the avoided logistics cost (the latter two embedded in the year-by-year benefit line). All discounting is at 6.00% real, end-of-year convention. The NPV is the algebraic sum of discounted benefits minus discounted costs over the 10-year horizon. The LCOS is computed by dividing the PV of costs by the present-valued kWh discharged. Both payback definitions use the year-by-year benefit stream directly against the year-0 Capex (simple) and against the PV of costs (discounted) — the time-bases of the cost stream and the benefit stream are aligned because they are read off the same annual column. No previously reported 1.57-yr "payback" is reused on this page.

5 — scenario TCO tables (copy verbatim)

Read-through: the project prints a negative net cash every year of the horizon (Y1 net = −76,239.13 EUR, deepening to Y10 net = −96,627.25 EUR as O&M escalates 2.0%/yr while the benefit stream shrinks on the modelled degradation rate). The PV of cumulative discounted nets is dominated by the year-0 outflow, hence the strongly negative NPV. IRR is reported as n/a because the net cash stream is negative across the full 10-year window — there is no discount rate at which the project breaks even.

6 — Sensitivity (qualitative — no recomputed figures)

The scenario model has not produced a sensitivity table for publication. Qualitatively, the largest swing factors in this scenario, in the direction of making the NPV less negative or positive, are:

1. Diesel price. A higher landed diesel price (e.g., €1.30/L at remote-mine retail) raises the avoided-diesel credit per kWh, lifting both the benefit stream and the LCOS-implied value-of-storage basis.
2. Discount rate. A lower real discount rate (e.g., 4%) lengthens the present value of the late-year benefit stream; a higher discount rate compresses late-year benefits further.
3. Diesel SFOC at the operating load point. The 0.28 L/kWh figure is a representative mid-load value; partial-load performance may be materially worse on a 2 MVA-class machine (subject to confirmation against the specific genset SFOC curve).

No alternative-figure TCO is published on this page. A recomputed sensitivity is held back to the RFQ stage because the project's specific genset make/model, the actual diesel-supply contract, and the EU VAT/customs treatment all materially affect the answer (see §8 and §11).

7 — What the negative NPV does and does not mean

• It does not mean the BESS is uneconomic in absolute terms. The TCO above is an incremental delta against a do-minimum PV-on-diesel counterfactual. The benefit stream is the avoided marginal cost of diesel and the displaced logistics/disruption risk that the operator attributes to the BESS. The scenario model captures the avoided-marginal-cost component; the risk-hedging component is not monetised.
• It does mean that, at 6.00% real over 10 yr, with 2%/yr O&M escalation, the avoided-marginal-cost benefit alone does not pay back the BESS-side incremental Capex within the modelled horizon.
• Implications for procurement: if the buyer values carbon-cost avoidance, diesel-logistics risk reduction, or EU permit-readiness independently of the commercial TCO delta, the stack can still be defensible — but the TCO delta should not be cited as a primary justification.

8 — Certification, HS classification, and customs posture (with PENDING flags)

Issuer + certificate number column is intentionally a PENDING placeholder. The values below are the standards we expect to be named on the shipped nameplate/at the FAT; specific certificate IDs (TÜV/CE/UL/IEC CB scheme) are not in scope of this page and must be confirmed at the FAT against the shipped serial-level documentation.

9 — Reference data sources (named URLs, not table labels)

• Solar resource (year-1 generation input basis) — EU PVGIS photovoltaic calculator (JRC, PVGIS-SARAH2).
• PV cost / performance reference — Fraunhofer ISE Photovoltaics Report and the Fraunhofer ISE LCOE Renewable Energy Technologies study (2024).
• PV cost benchmark (UK reference for project PV Capex sanity-check, not a tariff) — DESNZ solar PV cost data.
• EU industrial electricity / diesel price context — Eurostat Data Browser.
• EU battery regulation — Regulation (EU) 2023/1542; EC batteries landing EU batteries topic page.
• HS classification tools — EU TARIC consultation page; WCO HS Nomenclature 2022 edition; USITC HTS search; UK Global Tariff lookup.
• Battery transport — IATA Dangerous Goods Regulations (DGR); ICAO Dangerous Goods.
• Incoterms — ICC Incoterms 2020.
• Standards (full designation + edition cited in text; URLs are catalogue pages or exact document pages where provided) — IEC Webstore home; IEC 63056:2020 publication page; IEC 62619:2022 ed2 publication page; IEC 62485-5:2020 publication page; IEC 61851-1:2017 publication page; IEC 62109-1:2010 publication page; IEC 62109-2:2011 publication page; IEC 62109-3:2020 publication page; IEC 61215-1:2021 publication page; UL 1973 standard page; UL 61730-1 standard page; UN Manual of Tests and Criteria (Rev.7) UNECE page; NFPA 855 standard-development page.

10 — Next step (RFQ)

For a binding engineering and commercial offer — including OEM-grade datasheet revisions, project-specific genset make/model + SFOC curve, and an EU-of-origin/customs-stance section (TARIC lookup + member-state VAT treatment) — request the formal RFQ through TradVolt:

Request a formal RFQ for the 2 MWh EU mining-camp BESS+PV+genset stack

11 — Limitations and known gaps (notable for any reader re-using these figures)

1. The base-case NPV is negative. The model is not "wrong" in any direction relative to the computed input set; the figure is a direct consequence of (a) modest BESS-side avoided-marginal-cost at the representative diesel price and (b) the 2%/yr O&M escalation embedded in the computed inputs. If the reader's project differs on either, recompute the model.
2. asset.ess.usable_pct = 100% DoD in the headline cash flow (bounded 80–100% across the named commercial-warranty LFP offerings in §2).
3. asset.ess.cycles_per_year ≈ 1 cycle/day on the 2 MWh asset (bounded 0.5–1.5 cycles/day in §6) — drives the Y1 throughput of 540,000 kWh and the Y1–Y10 decay.
4. asset.ess.degradation_pct_per_year ≈ 2.0%/yr (bounded 1.5–2.5%/yr in §6) — drives the Y1→Y10 throughput path 540,000 → 450,224 kWh in the COMPUTED CASH-FLOW TABLE.
5. The "residual_value.amount" of 0 EUR is a conservative model-default; an explicit salvage/reuse value at year 10 would close part (not all) of the NPV gap. This is a bounded assumption, not a sourced figure.
6. The "asset.ess.value_per_kwh_discharged" credit of €0.05/kWh is built from the avoided-diesel-credit basis stated in §3; readers running this on a project with materially different logistics costs must override.
7. Cycle life, SFOC, and the LCOS basis are stated at the technology-class level; project-specific cell-datasheet revisions and the genset-specific SFOC curve must be confirmed at the FAT.
8. Certification IDs (TÜV/CE/UL/IEC CB scheme) for the BESS are marked "to be confirmed at FAT" throughout this page. We do not name an issuer-specific certificate number without the corresponding certificate PDF on hand.
9. EU import-duty rates and VAT treatment are PENDING and must be re-checked at the EU TARIC consultation page linked in §8 against the project's actual country-of-origin declaration.
10. The 6.00% real discount rate is a project assumption and is not a citation of any specific ECB or central-bank series. It is within a typical 4–8% project-WACC band for renewable-energy capex in the EU.
11. The previously quoted "1.57-year payback" is not used in this page. It was calculated against undiscounted Capex using PV-averaged annualised benefits, which mixes time-bases inconsistently. The scenario model returns no simple-or-discounted payback within the 10-year horizon for this scenario.

Page evidence-date: 2026-09-22. Equipment, scenario, horizon (10 yr), discount rate (6.00%, real), and currency (EUR) above match the scenario TCO inputs exactly; the figures in §5 are the computed output of that model.