Weekly Market Snapshot
weekly
France · Belgium · DE-LU · Netherlands
France's electricity market recorded a highly elevated mean price of €136.5/MWh over the 7-day period (10–17 August 2026), with extreme intraday volatility driven by a pronounced solar generation mid-day trough and steep evening demand ramps. Nuclear dominance at 65.6% of total generation underpinned supply adequacy, while a steady week-on-week decline in renewable penetration — from 29.3% on 10 August to just 13.8% on 17 August — tightened residual load and supported persistently high prices. France maintained a net export position across all interconnected neighbours, confirming its role as a regional price-setter and power exporter despite the elevated market price environment.
Weekly Market Snapshot
weekly
France · Belgium · DE-LU · Netherlands
France's electricity market exhibited extreme price volatility over the 7-day period (3–10 August 2026), with day-ahead prices averaging €107.82/MWh against a standard deviation of €60.64/MWh, driven by a pronounced solar-driven midday price collapse contrasted with steep evening ramps reaching €172.66/MWh at hour 20. Nuclear dominance at 68.2% of the generation mix underpinned France's strong net export position across all five interconnected bidding zones, with the FR→IT corridor alone exceeding 108% NTC utilisation. A late-week deterioration in renewable output—falling to just 14.1% on 10 August—signals tightening residual load conditions heading into the coming days.
Weekly Market Snapshot
weekly
France · Belgium · DE-LU · Netherlands
France's electricity market recorded an exceptionally elevated weekly mean price of €108.72/MWh with extreme intraday volatility (standard deviation €66.90/MWh), driven by a pronounced duck-curve price structure where early-morning and evening hours reached up to €189.62/MWh while midday solar suppressed prices to near-zero or negative levels. Nuclear baseload dominated the generation mix at 72.0% of output (40,865 MW average), providing structural stability, while France maintained a strong net export position across all major interconnectors, particularly maximising the FR→IT corridor at 96.8% NTC utilisation. A sharp renewable collapse on 3 August to just 13.9% versus a weekly average of 22.6% signals an emerging supply tightness that warrants close monitoring into the following week.
Weekly Market Snapshot
weekly
France · Belgium · DE-LU · Netherlands
The French electricity market exhibited extreme price volatility over the 7-day period (20–27 July 2026), with day-ahead prices ranging from -€11.32/MWh to €204.95/MWh against a weekly mean of €90.98/MWh and a standard deviation of €70.01/MWh — reflecting the deep solar-driven midday price collapse and steep evening ramp characteristic of high-renewable summer dispatch. Nuclear baseload dominated generation at 68.9% of the mix, underpinning France's strong net export position of approximately 1.4 TWh across all interconnectors over the period. A notable decline in renewable share from 33.1% on 20 July to just 17.0% by 27 July signals tightening supply conditions entering the following week.
Weekly Market Snapshot
weekly
France · Belgium · DE-LU · Netherlands
France's electricity market recorded a week of elevated and highly volatile prices, with a mean of €116.11/MWh and a peak of €260.28/MWh, driven by a pronounced inverse price profile where off-peak overnight hours (€132.39/MWh average) significantly outpriced conventional peak hours (€102.34/MWh average), reflecting strong solar suppression of midday prices. Nuclear generation dominated at 67.1% of the mix, while France maintained a substantial net export position of approximately 1.19 TWh across all interconnectors, with the FR→IT corridor running at near-full capacity utilisation of 98.1%.
Weekly Market Snapshot
weekly
Netherlands
The NL bidding zone experienced a highly volatile week (7–14 July 2026), with day-ahead prices averaging €107.53/MWh against a standard deviation of €53.85/MWh and an extraordinary peak of €261.08/MWh, driven by an inverted peak/off-peak structure where overnight hours commanded a €42/MWh premium over daytime. Solar generation dominated the fuel mix at 38% of total output, producing 12 negative-price hours and midday price lows near €18–20/MWh, while a sharp renewable collapse from 100% penetration early in the week to 39–45% over the weekend triggered the most acute price stress. NL maintained a significant net export position, with cross-border flows strongly skewed toward DE-LU at an average of 1,744.7 MW outbound.