UK Energy Market Report - 22 July 2026

Gas and power push higher on Middle East escalation, while UK fundamentals stay comfortable and the far curve holds its discount.

UK gas and power both pushed higher this morning, and for once the move has very little to do with what is happening on the British system. Escalation between the United States and Iran, thinner LNG arrivals into north-west Europe and a European storage stack that is only just over half full have put a geopolitical premium back into the front of the curve.

NBP day-ahead settled at 142.50 p/therm on 21 July, up 1.50 on the session, and is indicated around 148.00 this morning. UK baseload for day-ahead actually settled 2.03 lower at 125.37 £/MWh, but is being offered near 133.90 as the market reopens.

The contrast worth holding on to is this: the near curve is repricing on headlines, while the far curve still sits at a very large discount. That gap is where the procurement decision lives.

Gas Market

European gas continued to rally through 21 July, with TTF day-ahead settling close to €60/MWh, its highest level since 19 March. The NBP month-ahead gained roughly 2.2% to finish above 144 p/therm, and the strength carried right through the near curve.

The supply story behind it is straightforward. European LNG regasification has averaged around 214 mcm/day in July, down from roughly 260 mcm/day in June. That is a meaningful loss of prompt availability at exactly the point in the year when Europe needs to be filling storage.

Continental storage stood at about 53.0% full on 19 July, with injections running near 278 mcm/day. At that rate, comfortably hitting seasonal targets before the injection window closes is not a given, and the market is pricing that risk.

UK fundamentals, though, are genuinely relaxed. System demand fell to 143.81 mcm/d from 152.85 the day before, UKCS production ticked up to 97.00 mcm/d, and linepack built to 343.78 mcm. Britain is exporting around 51 mcm/d to the Continent through the BBL and IUK interconnectors while still injecting into medium-range storage.

That comfort shows in the relative pricing. NBP at 142.50 p/therm is the cheapest hub in north-west Europe this morning, sitting below TTF at 149.16, THE at 149.53, PEG at 149.22, PVB at 155.29 and Italy’s PSV at 160.26. The UK is the region’s release valve, which is precisely why the export flow is running as hard as it is.

Langeled flows eased to 52.80 mcm/d from 57.10, and Dragon reported no send-out at all, but neither is enough to change the domestic picture on its own.

Electricity Market

UK day-ahead baseload settled at 125.37 £/MWh, down 2.03 on the session, with day-ahead peak marginally firmer at 119.35. Both are indicated sharply higher this morning, baseload near 133.90 and the whole forward strip lifting between 4 and 5 £/MWh in sympathy with gas.

Nuclear availability is the quiet story underneath. Around 3.3 GW of UK nuclear capacity is currently unavailable. Sizewell B has both units fully offline on planned outages, Hartlepool 1 and Heysham 1 unit 2 are both on extended unplanned outages, and Heysham 2 unit 7 went fully offline on 20 July for a further 33 days. Torness 2 joins them on a planned outage from 31 July.

That tightness is showing up in balancing. The daily maximum system buy price has risen for five consecutive sessions, from 168.00 £/MWh on 18 July to 201.00 £/MWh this morning, with today’s peak set at 06:18. Wind and solar output is forecast to run broadly around seasonal norm through to the end of the month, so there is no obvious renewable relief coming.

The forward shape is the striking part. Winter-26 baseload is indicated at 127.70 £/MWh, Winter-27 at 85.25 and Winter-28 at 75.50. The market is pricing this winter as a problem and the two after it as something close to normal.

Oil, Carbon and Global Commodities

Brent settled at 91.01 USD/bbl, up 1.79 on the day, a near 2% move that tracks the same Middle East escalation driving gas. Coal API2 for Cal-27 firmed to 124.45 USD/tonne.

Carbon went the other way, which is worth noting. EUAs for Dec-26 eased to €83.20/tonne and UK ETS Dec-26 slipped to £61.31/tonne. Carbon usually follows gas higher when fuel switching economics tighten, so the divergence suggests compliance buyers are sitting on their hands rather than chasing.

UK carbon continues to trade at a discount to the EU scheme, roughly £9-10 per tonne once converted at the current rate. Sterling weakened on both crosses, closing at 1.1736 against the euro and 1.3371 against the dollar, which quietly adds to the landed cost of dollar-denominated LNG.

Storage and Supply Outlook

UK site storage remains patchy. South Hook is the strongest at 77% full, followed by Isle of Grain at 48%, Holford and Stublach at 45%, and Hill Top at 43%. Dragon sits at 37%, Holehouse Farm 35%, Hornsea 25% and Aldbrough 24%. Humbly Grove and Rough are both reported at zero.

With Rough contributing nothing, the UK has very little seasonal storage to lean on, so Britain is structurally more exposed to prompt flows and LNG arrivals than its continental neighbours. That is manageable in July. It matters far more in January.

The LNG schedule into north-west Europe over the next two weeks is telling. Of nine cargoes booked through to 6 August, only one is discharging at a UK terminal, 102 mcm into South Hook on 4 August. The rest are heading to Brunsbuttel, Wilhelmshaven, Fos, Zeebrugge, Montoir and Gate. Continental buyers are outbidding the UK for prompt cargoes because they need the storage fill more urgently.

Norwegian facility outages are mostly modest and forward-dated, with the exception of a planned Easington Langeled restriction. For anyone tracking the underlying data, GOV.UK Energy Trends publishes the official UK supply and demand series each quarter.

What This Means for Your Business

The most important thing to understand about today’s move is what is not driving it. UK demand is down, domestic production is up, linepack is building and Britain is exporting gas. None of that says shortage.

What is driving it is a risk premium on Middle East escalation and on Europe’s ability to refill storage in time. Both of those can unwind quickly if the news flow turns, and both can widen just as fast if it does not.

The number to focus on is the shape of the curve, not the level of the prompt. Winter-26 gas is indicated at 148.65 p/therm against Winter-27 at 95.00, a gap of nearly 54 p/therm. On power, Winter-26 baseload at 127.70 £/MWh sits 42 £/MWh above Winter-27. That is one of the widest near-versus-far spreads we have seen this year.

Practically, that points in three directions. If your contract ends this autumn and you have no choice but to cover Winter-26, do not take the whole volume in a single headline-driven session. Tranche it, and set trigger levels rather than waiting for a feeling.

If you have any flexibility on your contract end date, it is worth modelling what a start date beyond October 2027 actually saves. For a business using 5 GWh of gas a year, the difference between the Winter-26 and Winter-27 curve is substantial enough to justify the conversation with your supplier.

And if you are already on a flexible purchasing arrangement or sit within a basket, this is exactly the kind of week where that structure earns its keep. You are not forced to transact into a spike.

We track these curves daily. You can follow the underlying data on our wholesale gas prices and wholesale electricity prices pages, or read the wider archive in our business energy market reports.

If you want a view on how today’s curve affects your specific contract end date and volume, speak to one of our energy consultants today.

Previous report: UK Energy Market Report – 21 July 2026