The South-Eastern European (SEE) power markets are undergoing a significant transformation, characterized by a diminishing role of coal in price formation. As observed on 26 February 2026, coal’s contribution to the generation mix was approximately 18 percent, yet its influence on the market price was negligible. The trading session highlighted a shift towards a binary price formation structure, where prices are primarily determined by renewable energy during the day and gas during evening demand surges. This evolving dynamic is increasingly defining the operational landscape of SEE power markets.
Historically, coal served as a stabilizing buffer in the region’s energy mix, stepping in to set prices during periods of high demand or when hydroelectric output fell short. However, this stabilizing function has been eroded due to several factors: rising carbon costs, aging coal infrastructure, and robust competition from low-marginal-cost renewables. Consequently, coal has lost its place in the merit order under standard operating conditions.
The recent trading data indicates that even during peak demand periods, coal units were often outcompeted by renewables and gas imports. Elevated carbon pricing has further weakened coal’s competitiveness; as emissions allowances remain high and expected to stay firm, coal’s cost structure frequently surpasses that of gas on a clean spark basis. This shift means that coal only influences prices under extreme conditions such as severe cold snaps or prolonged droughts affecting renewable generation.
This transition simplifies the marginality structure but simultaneously heightens market volatility. The absence of coal as an intermediate layer leads to abrupt price shifts rather than gradual transitions across multiple layers of generation sources. During high solar output periods, prices tend to drop sharply toward operational floors, while low renewable availability sees gas units take over as marginal setters, pushing prices upwards rapidly.
In southern SEE markets like Serbia, North Macedonia, and Montenegro, this binary price mechanism is particularly pronounced. There have been instances where midday prices plummeted close to zero due to the full displacement of coal units by renewables. In contrast, as solar production waned in the evenings, gas units quickly escalated prices without any stabilizing presence from coal.
Hungary presents a slightly moderated scenario where while coal still contributes to generation levels, its role remains limited amidst imports from Austria and Slovakia alongside domestic renewables and gas sources. Here too, coal rarely establishes clearing prices but may operate for system stability or contractual obligations.
The critical driver behind these market changes is carbon pricing. With EUA costs integrated into coal operations, even slight increases in carbon pricing disproportionately disadvantage coal compared to more flexible gas options. The market increasingly penalizes higher emissions associated with coal plants while rewarding efficiency improvements seen in gas operations.
The implications for market volatility are substantial; in systems with multiple marginal layers, price adjustments tend to be incremental. However, with a binary structure emerging, small fluctuations in renewable output or demand can lead to significant price movements almost instantaneously—illustrating how sensitive the current system has become.
This volatility has direct consequences for asset valuation and trading strategies within the energy sector. Coal-fired plants that once provided stable marginal pricing are now facing reduced revenue opportunities as their operational hours dwindle between periods dominated by renewables and those driven by gas peaks.
For traders operating within this new framework, traditional strategies based on fuel spreads involving coal are becoming obsolete. Instead, focus is shifting towards forecasting renewable outputs and managing exposure to gas prices during peak demand times—essentially reframing market questions around whether renewables can meet demand or if reliance on gas will be necessary.
The transition towards binary price formation also amplifies the significance of accurate forecasting; minor errors can lead to outsized impacts on pricing dynamics. Misestimating solar output could trigger unexpected scarcity or prolonged price suppression depending on whether forecasts err on the side of surplus or deficit.
Moreover, as cross-border flows interact with this evolving market structure, local shocks can ripple across neighboring regions more rapidly than before due to diminished buffering provided by local coal plants. A decrease in renewable output in one area may necessitate increased imports from adjacent markets while surges can flood them with excess supply if interconnections permit.
Policy frameworks are reinforcing this trajectory away from coal dependency as environmental regulations promote decarbonization efforts that deter investment in existing coal infrastructure. While some operational capacity remains intact for security purposes during extreme demands, overall market pricing is trending towards a post-coal paradigm.
Looking forward, it appears that this binary price regime will not only persist but intensify as renewable capacities expand—particularly solar installations throughout southern SEE markets—while natural gas continues to serve as the primary flexible thermal resource amid an unyielding carbon pricing landscape. Without significant advancements in storage solutions or demand-side flexibility enhancements, fluctuations between renewable surpluses and gas-driven scarcity will likely dominate future market operations.
