# Dated electricity programme: inputs and calculations

WattInfo, 19 September 2026. All hourly results are conditional scenarios.

## Electricity

2035: 26 GWp solar, Gösgen/Leibstadt, existing hydro and pumping, fixed car charging, up to 2 GW imports, and a 3.2 TWh total data center assumption. Embedded data center growth is removed before adding 0.9973076923 TWh. Thirteen October–September weather years are paired with routine operation and a chosen 90-day winter Leibstadt outage.

2050: 53 GWp solar, the central electrification path and an extra 0.86 TWh for data centers after subtracting the embedded allocation. Test one/two new 1.1 GW units with existing plants, or two/three without them. Three weather years: 2011/12, 2016/17, 2021/22. The outage case removes the first new reactor for January–March. Two fleet options also have routine cases.

Routine units have 30-day maintenance and 98% output outside outages. The model first minimises annual unmet energy, then peak shortfall. Storage is finite and cyclic; pumping uses energy. Hydro topology, rights and maintenance are simplified; the grid is unconstrained and future conditions known. These are energy-balance screens, not probabilistic reliability studies. Remaining gaps are additional to modelled generation, storage and imports. Day/night follows the archived solar-position definition.

Winter TWh = sum of hourly unmet GW in October–March / 1000. Peak GW = maximum hourly unmet GW. Energy and power maxima can occur in different years. Routine and outage totals overlap and must not be added. No uncertain hydro expansion or additional stationary battery/fuelled reserve is credited.

## Owner finance

Two 1.1 GW units, commercial operation in 2047 and 2050 as planning assumptions. Ten-year construction spending: 3/6/10/14/17/17/14/10/6/3 percent. Overnight inputs: CHF 6,000/10,000/15,000 per kW. Add separate development 5%, attributable grid 5%, initial core 1%; reconcile a real offer to avoid duplication. All finance cashflows use constant 2026 CHF.

Sixty years of financial operation at 85% lifetime output. Annual fixed operation/maintenance CHF 240/kW plus insurance allowance CHF 10/kW; fuel, variable costs and waste CHF 15/MWh. Refurbishment 10% of overnight cost in operating year 30. Decommissioning 15% at life end, funded by annual contributions earning 2% real. The owner ledger deducts contributions, not also the terminal expense. Insurance premiums and waste allocation are provisional; uninsured tail risks remain unpriced.

Break-even price = discounted owner cash expenditure / discounted generation, using mid-year real flows valued at commercial operation. Financing carry is a diagnostic, not an additional expense in that formula. The public chart varies the real required return at unchanged central construction and operation assumptions. The financial 85% output assumption is separate from hourly availability.

## Downloads and reproduction

The evidence JSON contains original case summaries, case definitions, source-linked programme inputs and timeline, finance assumptions and mapped display claims. CSVs contain all 66 scenario results and both owner cashflows. The code archive contains calculation modules and input manifests; reacquire referenced data separately. It is not a self-contained hourly-data bundle. Original third-party documents are linked through the source catalogue and are not redistributed.