Lab-ESS 200 kWh UK TCO (r9)

Verdict (answer first): For a 200 kWh usable LFP lab energy-storage system in the United Kingdom, modelled with a Huawei SUN2000-100KTL-M2 hybrid inverter and CATL 280Ah LFP cells over a 10-year horizon at an 8.00% discount rate, the project has a net present value of −USD 250,856.53, no simple payback and no discounted payback within the 10-year horizon, an IRR of −0.2474 (i.e. −24.74%), and a levelised cost of storage of USD 0.7315/kWh (energy throughput basis). Evidence date: 2026-01-15. Limitation: this is a use-case TCO study built from named public sources and bounded model assumptions; it is not financial advice.

0. Decision table

Sign convention: the "Savings" line is PV of tariff-and-capacity benefits (positive when displaced grid cost is avoided); "Net tariff–capacity delta" in the cash-flow table is benefit minus the residual grid cost that remains (negative when grid cost still rises relative to no-ESS). At base assumptions, PV of Savings > 0 (USD 49,225.25) but is dwarfed by PV of costs.

1. Scope

A 200 kWh usable lithium-iron-phosphate (LFP) battery is paired with a 100 kW hybrid inverter to back a UK laboratory load: HVAC recirculation, fume-hood extract fans, −80 °C ULT chest freezers, server racks and PC test-benches. The system is intended for daily peak shaving and a short ride-through of facility faults. Grid tariffs follow the UK standard commercial profile with capacity-based and reactive-power charges from the local DNO Use-of-System schedule.

2. Equipment identification

3. Inputs table (cited)

Bounded defaults (base_date, residual_value.amount, residual_value.year, power factor, daily cycles) are stated explicitly. They are model assumptions, not sourced facts, and should be re-validated before procurement. Discount rate is shown as a bounded default; the scenario model does not source it from the Bank Rate in this revision.

4. Capex stack

5. Computed TCO summary (scenario model)

Costs and benefits are both discounted at 8.00% per year; PVs are stated explicitly in the cash-flow table. Residual value is held at USD 0 at year 10 by bounded default; crediting any positive salvage would shift NPV upward by the discounted residual but would not change the reject verdict at base assumptions. "Benefit" here is PV of Savings (tariff displacement + capacity-charge relief). The Net tariff–capacity delta (negative when grid cost rises) is shown in the cash-flow table and is the line that drives the IRR to be negative.

6. Computed year-by-year cash flow (scenario model)

Year-0 cost of USD 284,000 is the scenario model capex line (capex converted from GBP at FX 1.27 plus freight/duties placeholder; freight/duties figure is PENDING — see §4). Operating cost rises 3% real per year. The "Benefit" column is the scenario model output for Savings + net tariff–capacity delta; the per-year net remains positive across years 1–10, but discounted against the Year-0 −USD 284,000 outflow, no payback is reached inside the 10-year horizon. Discount factors are 1/(1.08)^y computed to four decimal places. SoH taper is bounded linear 1.00@y5 → 0.80@y10 (factors 0.96/0.92/0.88/0.84/0.80 across years 6–10) and is applied to the energy throughput that drives the Benefit column.

7. Sensitivity (re-stated against the computed base)

The computed base NPV is −USD 250,856.53. Sensitivities below re-state the directional impact of input moves against this base, not recomputed cash flows (recomputed values would require re-running the scenario model).

Sensitivity ranges are qualitative against the computed base; re-run the scenario model with the candidate inputs to obtain exact NPVs before a procurement decision.

8. Compliance & certification — evidence required

9. HS / customs code block

UKGT/UKXI rules apply post-Brexit. Always re-verify the live 8/10-digit measure before customs clearance.

10. CTAs

Request a tailored RFQ for a 200 kWh lab ESS (UK) Request the datasheet pack (PDF)

The datasheet pack is delivered via the RFQ flow; no public PDF is published for this use case.