Forward Markets: The Forgotten Stepchild

The energy crisis of March 2026 has a clear and violent face. A blockade in the Strait of Hormuz has effectively trapped 20% of the world’s daily oil and liquefied natural gas (LNG) supply, sending Brent crude prices skyrocketing toward $126 per barrel. This is a systemic shock that has cascaded directly into European electricity markets. But why?

Despite the rapid growth of wind and solar, natural gas remains the primary marginal price-setter during 32% of our hours. When global gas prices spike because Qatari LNG is blocked, European power bills follow them up the mountain in lockstep.

But while the headlines focus on the maritime chokepoint 3,000 miles away, the real structural failure is closer to home. Europe is attempting a world-first energy transition toward a renewable-dominated grid, yet it is doing so while ignoring its most important defensive tool: the forward market.

For a decade, we have perfected the spot market - the high-speed, automated, 24-hour dash for power. But we have left long-term hedging to languish as a forgotten stepchild. The result is a system where geopolitical friction can triple an industrial energy budget overnight because the financial architecture to lock in long-term prices is fragmented, illiquid, and poorly designed.

How 24-Hour Thinking Fails

In the trading rooms of Berlin, Paris, and Warsaw, the focus is almost exclusively on the day-ahead and intraday modules. This obsession with the short-term is understandable - it is fast, data-rich, and optimized by sophisticated algorithms. However, the spot market offers zero protection against black swan events. Reliance on short-term price signals is a luxury that vanished with the onset of extreme weather and geopolitical instability.

Since 2020, daily wholesale power price swings in Europe have increased fivefold. The volatility is a feature of a system where weather-dependent generation fluctuates wildly. On July 1, 2025, for instance, a heatwave across Central Europe reduced the cooling efficiency of thermal and nuclear plants just as demand for air conditioning surged. In Poland, prices spiked to a staggering €470/MWh. Companies that relied on the spot market that week saw their monthly margins erased in hours.

Without a deep, liquid forward market where participants can hedge their price exposure up to three years into the future, businesses aren't trading, but gambling. Currently, more than 80% of European utility sales volumes are hedged at least a year in advance. However, the instruments available to achieve this are buckling. The forward market is supposed to provide the shield that allows industrial consumers to plan multi-year investments. Instead, it is currently a collection of isolated islands, forcing market participants to pay a complexity tax just to manage basic risks.

Financial Transmission Rights (FTRs)
The Price of Narrow Bridges

To create a truly integrated European market, power must move across borders. But wires alone aren't enough. A producer in a low-price zone (like Sweden) needs to know they can sell into a high-price zone (like Italy) without losing their shirt to sudden price divergences. This is where Financial Transmission Rights (FTRs) come in.

Technically, an FTR is a derivative that entitles the holder to the difference in Locational Marginal Prices (LMPs) or bidding zone prices between a source and a sink node. The payout formula is represented as:

Value = Quantity x (PriceSink - PriceSource)

By holding this contract, a trader can effectively lock in their transport cost between two zones. If the price gap between Germany and Poland widens, the FTR pays out more, covering the increased cost of moving the power.

However, these bridges are chronically narrow. European Transmission System Operators (TSOs) have a legal obligation to make at least 70% of their transmission capacity available for cross-border trade. Yet, by the end of 2024, ACER reported that TSOs in the Core region made available an average of only 54% of capacity on their most congested lines. This failure cost the EU €580 million in lost economic welfare in a single year.

Because local forward markets in countries like Poland, Romania, or Bulgaria lack liquidity, traders are frequently forced into proxy hedges. They sell futures in a liquid market like Germany to cover their local exposure. This introduces basis risk - the danger that the price spread between the local hub and the German hub will move in ways that the hedge doesn't cover.

ACER has proposed the creation of virtual trading hubs to aggregate regional liquidity, but the industry remains cautious. Many market participants fear that these synthetic prices will divert liquidity from existing zonal markets and introduce a new layer of basis risk, leaving them exposed to the spot price differential between their national market and the hub. Until we move from FTR options (which only pay out one way) to two-way FTR obligations, the forward market will remain fragmented. FTR obligations act as a bond, forcing the holder to pay if the price difference is negative but allowing for perfect hedging that makes the outcome independent of spot price fluctuations.

Contracts for Difference (CfDs)

The Public Anchor of Stability

As the EU power sector hit a landmark 50% renewable share in 2025, the role of the state shifted from a subsidizer to a stabilizer. The 2024 EU Electricity Market Design Reform cemented this change by mandating two-way Contracts for Difference (CfDs) for all new public financial support.

A two-way CfD is a symmetrical price shield. It works through a strike price agreed upon in a competitive auction.

1. If the market price is above the strike price (as it is now during the Hormuz crisis), the generator pays the excess profit back to the state, which is then used to lower consumer bills.
2. If the market price is below the strike price, the state tops the generator up, ensuring the project remains bankable.

The results of the UK’s seventh allocation round (AR7) in early 2026 provide a definitive proof of concept. The auction secured a record 14.7 GW of capacity - enough to power 16 million homes - across wind, solar, and tidal projects. Most importantly, offshore wind was locked in at a strike price of £91/MWh. Contrast this with the cost of running a new-build natural gas plant, currently estimated at £147/MWh. By using CfDs, the UK has essentially pre-bought stability for the next 15 years at a 30% discount compared to fossil fuels.

However, traditional CfDs are not without flaws. Because they guarantee a fixed revenue regardless of when the power is produced, they can create dispatch distortion. In 2025, Europe saw a massive spike in negative price hours - over 600 in Sweden and 500 in Germany - driven by solar oversupply. Traditional CfD generators have no incentive to turn off their plants when prices go negative, which wastes energy and strains the grid. To fix this, the market is moving toward cap-and-floor models and volume-neutral designs that ensure generators still respond to real-time price signals.

The Big Repricing

From Volume to Flexibility

In the private sector, the primary tool for long-term hedging is the Power Purchase Agreement (PPA). But the PPA market of 2026 looks nothing like the market of 2021. We are currently in the middle of what industry experts call The Big Repricing.

For years, the PPA market was driven by simple pay-as-produced contracts: a company would buy a certain amount of solar power whenever the sun was shining. But the sheer success of solar has broken this model. We now face a permanent solar duck curve where massive afternoon production crashes prices to zero or even negative. In 2025, total disclosed PPA capacity fell from 15.3 GW to 13.1 GW as corporate buyers realized that buying volume during the day was a liability.

The value has moved somewhere else. It is no longer about how many megawatts can you make? It is: how much volatility can you solve? This shift has triggered a 200% surge in utility-led deals and a tripling of Flexibility Purchase Agreements (FPAs) for battery energy storage systems (BESS). In 2025 alone, 12 GW of battery capacity was contracted to monetize the spread between afternoon lows and evening peaks. Utilities have repositioned themselves as the middlemen of chaos, using massive battery fleets to absorb the peaks and fill the troughs that corporate buyers are too risk-averse to handle.

From Stepchild to the Head of the Household

The maturity of the European forward market is a prerequisite for industrial survival. The March 2026 crisis has shown that as long as our forward markets are fragmented and illiquid, our economy remains hostage to chokepoints 3,000 miles away.

To build a resilient energy architecture, Europe must take three decisive steps:

• - Aggressive Grid Integration: TSOs must stop hoarding capacity for remedial actions and meet the 70% requirement. A unified continent needs open bridges.
• - Standardize the Instruments: We need to move toward FTR obligations and harmonized CfD designs that preserve dispatch incentives. The hidden tax of basis risk must be eliminated.
• - Incentivize Flexibility: The PPA market must continue its evolution toward Flexibility Purchase Agreements. Volume is cheap; reliability is the new gold.

Europe’s energy transition is half-finished. We have built the turbines and the panels, but we have failed to build the financial machinery to handle the volatility they create. The forgotten stepchild of energy trading needs to become the head of the household, or the transition will remain nothing more than a high-stakes gamble.