UK Q+1 Power Settles at £135.54/MWh as Late-Summer Demand Erodes Near-Term Premium
Hormuz-driven supply anxiety keeps European gas bids elevated, but weakening UK summer consumption leaves the gap between Q+1 and Cal+1 power prices exposed.
UK Power Q+1 settled at £135.54/MWh at Saturday's close (2026-08-22), sitting £34.64/MWh above the Cal+1 contract at £100.90/MWh. European natural gas prices edged higher on Thursday (2026-08-13), with British wholesale gas contracts posting a 0.7% gain as traders priced in tighter near-term availability across North Sea import hubs, according to market reports.3
The storage backdrop keeps winter concerns alive. Gas Infrastructure Europe data show EU underground facilities at approximately 60% of total capacity in mid-August, below seasonal norms, according to the same market reports. With injection targets unmet across the bloc, buyers remain reluctant to sell the prompt aggressively.3
The supply disruption behind current price levels originates in the Persian Gulf. Attacks on the Ras Laffan industrial complex in Qatar — responsible for approximately 20% of global LNG supply — removed roughly 17% of Qatar's LNG capacity, with restoration expected to take three to five years, according to Elenger's Q1 2026 gas market review. ICE Endex TTF front-month stood at €65.83 per megawatt-hour at Saturday's close (2026-08-22), well above the €26.73/MWh at which the contract ended Q4 2025. The benchmark peaked above €33/MWh in January 2026 following the initial Qatar shock before easing somewhat in February, per Elenger.2
At those TTF levels, UK gas-fired generation carries elevated marginal costs. UK Carbon stood at £58.75 per tonne as of Sunday (2026-08-23). But elevated generation costs only translate into high clearing prices when load is there to absorb them. Weaker-than-expected August consumption pulls dispatch volumes lower, pressing the baseload clearing price regardless of where European gas trades.3
Ongoing Strait of Hormuz disruption kept European gas bids supported through mid-August, per market reports covering Thursday (2026-08-13). Benchmark Dutch front-month gas gained 0.2% in that session. The supply-side bid feeds directly into UK power economics through the cost of gas-fired generation. Yet elevated costs without commensurate load compress the margins of gas plant operators and, eventually, pull clearing prices lower.3
US LNG export volumes offer a potential offset on the supply side. Weekly vessel departures from US terminals reached 141 billion cubic feet in the week to mid-May 2026, up 26 billion cubic feet week-on-week despite maintenance at several export facilities, according to TradingView market data. US volumes reach European markets through the Atlantic LNG arbitrage; should that export momentum have continued into autumn delivery windows, incremental regasification could ease TTF and reduce the cost floor for UK baseload.1
The £34.64/MWh spread between UK Q+1 and Cal+1 is what supply-side bulls need to defend through September. A sustained run of mild temperatures or a persistent undershoot in UK daily power consumption could narrow it from the top, with Q+1 drifting toward the Cal+1 anchor. North Sea import hub supply tightness, flagged by traders on Thursday (2026-08-13), is the supply-side factor most capable of resisting that move.3