Dec25 Energy Market BriefPrices Pull Back From October Highs

November saw a continuation of two clear, competing forces shaping UK energy prices: stronger zero-carbon generation (particularly wind) steadily displacing gas in the short term, while structural concerns about gas supply and system resilience kept a risk premium alive in wholesale markets.

Over the month wholesale gas fell back from October highs, UK NBP futures were around 10% lower across November, which helped push wholesale power prices down from some earlier spikes, but the market remained volatile as traders balanced weaker near-term demand against medium-term supply risk.

Wind generation frequently provided material downward pressure on wholesale power, with the system recording some of its strongest pushes from wind in November (notably a new high in mid-November), lowering the marginal role for gas in many daylight and overnight settlement periods. That higher renewable output reduced system carbon intensity on many days and, together with mild weather and falling demand, supported the downward drift in day-ahead and near-curve power.

Despite these near-term easing factors, policy and system-level messages kept a premium attached to gas and winter security. NESO and Government publications in late November flagged longer-term gas security concerns and opened consultations on measures to strengthen resilience, warning of potential shortages in the early 2030s under certain scenarios. Those signals, together with the global dynamics around LNG and European gas flows, sustain the possibility of price spikes on cold, low-wind periods and mean that price relief is conditional rather than structural.

Carbon pricing moved higher through November, adding a steady but smaller cost push to power generation economics and keeping thermal (gas) generation relatively more expensive when carbon is considered. The EU ETS range rose over the month, which amplifies the influence of renewables on the dispatch stack and supports higher forward power curve levels for periods where gas is still required.
On fundamentals, temperature-adjusted consumption fell modestly in the latest official statistics released during the month, reflecting milder weather and demand-side measures; that helped blunt some winter upward pressure that would otherwise have been felt more sharply given tighter supply back-drops. However, system planners and the market continue to treat prolonged cold snaps, unplanned outages or major LNG diversions as credible shock scenarios.

What this means for customers: the immediate picture going into December is that wholesale prompt and near-curve prices are generally lower than the October peaks, and strong renewables output can depress day-ahead prices significantly when conditions are favourable. At the same time, medium- and long-dated risk premia have not evaporated because of supply-security concerns and higher carbon, so fixed-price offers for later winters and multi-year hedges still reflect that premium. For businesses with flexible consumption, value remains in exploiting periods of low day-ahead prices and in demand-side measures; for customers with limited flexibility, a blended approach that captures some near-term value while hedging against winter spikes is sensible.

November’s movement was largely a short-term easing on gas and power driven by renewables and milder demand, but that system-level warnings about gas resilience and rising carbon mean the market is still exposed to episodic spikes. Where appropriate, a procurement mix that blends short-term tactical purchasing with targeted longer-dated protection to lock in attractive pockets on the curve without leaving exposure to extreme events.