By 2025, the most expensive component of power risk management in South-East Europe shifted from outright price risk to basis risk. The risk did not show up on invoices, but it accumulated in financial results. It reduced the effectiveness of hedging strategies that were described as theoretically sound yet practically incomplete.
Basis risk occurs when the price used for hedging does not match the price of the underlying physical exposure. In South-East Europe, the mismatch became systemic as industrial consumers and utilities hedged local exposure indexed to national exchanges. At the same time, they executed forward hedges on regional or core European markets.
Hedge structures using SEEPEX, OPCOM and IBEX versus HUPX and EEX
The most common configuration reported for 2025 paired physical exposure linked to SEEPEX, OPCOM, or IBEX with forward hedges executed on HUPX or German-linked EEX products. Directional correlation between these markets was described as high. However, amplitude correlation was reported as weak.
During 2025 delivery, annual average spreads were described as benign. Intra-year movements showed a different pattern, with the spread between SEEPEX and HUPX annual baseload prices swinging by ±8–12 €/MWh. These swings were linked to hydro stress, thermal outages, and cross-border congestion.
Similar magnitudes were reported between IBEX and HUPX. OPCOM spreads were described as showing strong seasonal widening during dry quarters. The reported differences focused on how spreads moved within the year rather than how they averaged out.
Economic impact of basis movements for industrial loads
An industrial buyer with a 50 MW flat load was estimated at approximately 438 GWh annually. For that profile, a ±10 €/MWh basis movement was associated with a deviation of ±4.4 million € from expected energy costs. This occurred even when portfolios were fully hedged in nominal terms.
For larger consumers or utilities managing 100 MW or more, the exposure was described as doubling proportionally. The deviations were not framed as rare events, with occurrences reported repeatedly in 2025. The timing highlighted Q1 and Q3, driven by weather variability and infrastructure constraints.
Asymmetry and effective exposure after delivery
The basis risk effect was described as asymmetric. Hedges were reported to protect more effectively against upward price shocks than against downward movements. When local markets decoupled downward due to surplus hydro or imports, hedged consumers did not fully benefit.
When local prices spiked, hedges were reported to lag or underperform due to congestion-driven divergence. As a result, many industrial buyers found post-delivery that portfolios described as “fully hedged” still showed 15–30% effective exposure. The impact was described as persistent variance versus budgeted energy costs rather than catastrophic losses.
Bilateral contract indexing in Romania and Bulgaria adds premia
In Romania and Bulgaria, forward hedging often relied on bilateral contracts indexed to spot references. The problem was described as compounded by embedded risk premia within those contracts. Credit risk, liquidity risk, and basis risk were priced into contract terms.
The added cost was estimated at 3–6 €/MWh, relative to core European consumers. By the end of 2025, market participants reached a view that hedging in South-East Europe reduced volatility but did not eliminate it. The residual risk was described as structural rather than accidental.
The reported condition for reducing basis risk was linked to local forward markets deepening enough to align hedging instruments with physical exposure. Until then, basis risk was described as remaining a hidden tax on electricity consumption in South-East Europe.
Elevated by virtu.energy