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Energy market outlook for the week ahead…

The central tension is whether a hawkish Fed can offset a market still losing barrels and cargoes. Macro focus falls on tomorrow’s FOMC decision, after August CPI printed at 3.4% against a 3.3% consensus; CME FedWatch implies a 92.4% probability of a rate increase, against 60% a week ago, with the dollar index near 99.60. The bearish case rests on that tightening, on the Witkoff and Kushner peace track staying alive, and on UK and north-west European temperatures adjusted warmer into late September. The bullish case rests on the pipeline staying offline, ANZ expecting no return to pre-war Gulf supply before late Q1 or early Q2-27, and analysts warning TTF could push towards €150/MWh. Wind took 32.0% of GB generation over the last 7 days against gas at 24.8%, yet gas still sets the marginal price in most settlement periods, so the shift shows up in volatility and network costs, not wholesale. For UK energy buyers, the risk premium in Winter-26 and Q1-27 remains elevated and event-driven, favouring staged cover over waiting on a resolution unlikely before the heating season.

FAQ: Understanding the Wholesale Energy Market 

The wholesale energy market is the marketplace where electricity and natural gas are traded before being supplied to end users. It is made up of generators, suppliers, traders, large industrial consumers and financial participants buying and selling energy through exchanges and bilateral contracts across multiple time horizons – from same-day delivery through to contracts several years ahead.

Wholesale markets exist to balance supply and demand efficiently while allowing participants to manage price risk. The prices established within these markets ultimately underpin the retail energy costs paid by businesses and consumers.

Wholesale energy prices are driven by the constant balancing of supply, demand and market risk. At the most fundamental level, prices rise when the market perceives energy to be less available or more difficult to secure and fall when supply is considered comfortable relative to demand.

A wide range of factors influence this dynamic, including weather conditions, renewable generation output, gas storage levels, infrastructure outages, economic activity and global commodity markets. Prices are also heavily shaped by expectations. Energy markets continuously price in future risks such as geopolitical uncertainty, seasonal demand shifts and potential supply constraints.

Winter energy contracts are typically priced at a premium because the market expects higher demand during colder months. Heating requirements increase gas consumption significantly, while electricity demand also rises due to lighting and peak usage pressures.

At the same time, the system often has less operational flexibility during winter. Renewable generation can become more variable, reserve margins tighten, and any disruption to supply has a greater impact on market stability.

Energy markets are highly sensitive to both physical disruptions and shifts in market sentiment. Volatility typically occurs when there is uncertainty around the balance between supply and demand, particularly when spare capacity within the system is limited.

Common drivers include extreme weather events, unplanned generation outages, low renewable output, gas infrastructure issues, storage concerns and geopolitical developments. Markets can also react sharply to changes in regulation, macroeconomic data or shifts in global commodity pricing.

Because electricity and gas systems must remain balanced in real time, even relatively small disruptions can trigger disproportionate price movements, particularly in short-term trading markets.

Seasonal future development refers to how wholesale energy prices are expected to evolve across future seasonal delivery periods, typically comparing summer and winter contracts over multiple years ahead.

These seasonal pricing structures reflect the market’s view of future supply and demand fundamentals, infrastructure developments, storage availability, generation mix changes and broader macroeconomic conditions.

Monitoring seasonal market development helps businesses understand how future risk is being priced into the market and supports more informed procurement and budgeting decisions.

A forward curve is a graphical representation of wholesale energy prices for future delivery periods, ranging from months to several years ahead. It illustrates how the market currently values future energy supply over time.

Forward curves are one of the most important tools used in energy trading and procurement because they provide insight into market expectations, pricing structure and risk premiums. They are widely used to support budgeting, hedging strategies, contract timing decisions and risk management planning.

Rather than predicting future prices with certainty, forward curves represent the market’s consensus view of value at a specific point in time.

Energy prices are often lower further out on the forward curve because near-term markets carry greater immediate risk and uncertainty. Short-term pricing is more exposed to factors such as weather events and supply disruptions.

Longer-dated contracts tend to reflect more stable underlying market assumptions, where short-term volatility becomes diluted over time. In effect, the market typically assigns a higher risk premium to prompt and near-term delivery periods because the operational and pricing uncertainty is much more acute.

This is why businesses frequently see higher pricing closer to delivery, particularly during periods of market stress or tight system conditions.

Commodity costs represent the wholesale cost of the underlying gas or electricity being purchased within the energy market. This is the traded market value of the energy itself.

Non-commodity costs are the additional charges applied to deliver and manage energy across the system. These can include network and transmission charges, balancing costs, environmental and policy levies, capacity market costs and supplier operational charges.

Over recent years, non-commodity charges have become an increasingly significant proportion of total business energy costs, meaning effective procurement strategies now require visibility and management across both commodity and non-commodity elements of the bill.