Took about 20 min, cost ~ £0.54.
Vanadium flow battery technoeconomics
A live discounted-cash-flow model for a grid-connected vanadium redox flow battery (VRFB) run on daily price arbitrage — charge at the cheapest hours, discharge at the dearest. Costs follow the standard power-and-energy decomposition; revenue uses 2024-calibrated GB day-ahead spreads. Every assumption below is editable.
System size▸
Capital cost (CAPEX)▸
Operation & market▸
Financial▸
Advanced & scaling▸
Where the capital goes
Energy-scaling vs power-scaling components
A typical trading day
Cheapest hours charge · dearest hours discharge
Cumulative discounted cash flow
Where the line crosses zero is the payback point; its end value is the NPV
NPV across system size
Soft costs scale sub-linearly, so £/MWh improves with scale
Annual economics (Year 1)
The operating engine behind each year’s cash flow
Method & assumptions
How this model is built, and where the defaults come from
Defaults & sources. CAPEX uses the standard power (£/kW) + energy (£/kWh) split from grid-storage cost studies (PNNL / Viswanathan et al. 2022 list ~$350/kW power and ~$178/kWh energy for VRFB; Minke & Roznyatovskaya techno-economic breakdowns). Arbitrage revenue is calibrated to the 2024 GB day-ahead market — average daily price spread ≈ £54/MWh, annual baseload ≈ £72/MWh (gridcog; Modo Energy; Ofgem/Elexon). LCOS, NPV, IRR and discounted-payback follow conventional DCF practice. The hourly price series is a deterministic, seeded representation tuned to those two published statistics — it captures realistic intraday and seasonal shape but is not the literal historical dataset; swap in your own price file for a hard number.
Not investment advice A screening tool for comparison and sensitivity, not a bankable model. Real projects layer in balancing-mechanism, ancillary and capacity-market revenue, degradation testing, financing structure and site-specific civil costs.