In the evolving energy landscape of South-East Europe, gas-fired power generation is increasingly recognized not merely as an energy source but as a crucial component of system reliability. These plants serve a vital role by providing stability during peak demand and unforeseen crises, yet they are compensated under outdated remuneration frameworks that treat them like traditional energy suppliers. This misalignment has led to chronic underpayment, exacerbating market volatility and resulting in a pricing structure that often fails to mitigate risks associated with rare but severe stress events.
The operational utilization of gas-fired capacity in the region is significantly low, typically operating at only 10–25% load factors annually. In key markets such as Serbia, Bulgaria, and parts of Romania, gas plants may run for less than 200–400 hours per year. However, these limited operational hours often coincide with critical demand periods—such as winter peaks and low-wind evenings—where their presence is indispensable for preventing system failures.
The economic implications of this underutilization are substantial yet largely unrecognized. Recent winter stress events have seen peak electricity prices soar to €250–300/MWh, with intraday prices reaching between €400 and €600/MWh when supply responses are limited. Modeling indicates that introducing an additional 300–500 MW of fast-ramping gas capacity could materially lower peak prices by €40–80/MWh and reduce balancing activation volumes by 20–30%. The potential cost savings during severe demand weeks can amount to tens of millions of euros across the region.
Despite their critical function in maintaining system stability, gas plants predominantly earn revenue through energy margins that diminish when the system operates smoothly—ironically, the very condition they help sustain. This creates a paradox where effective performance leads to reduced earnings; consequently, markets tend to reward instability over reliability.
The financial landscape for new or upgraded gas-fired capacity is daunting, with capital expenditures ranging from €700 million to €1.1 billion per GW based on configuration and grid connections. Fixed operational costs add another €25-40 million per GW annually before accounting for fuel expenses. Recovering these costs through limited operational hours is virtually impossible without significant price spikes, compelling investors to seek volatility that the market aims to minimize.
This underpayment trend has tangible consequences: operators may delay maintenance or reduce availability during less profitable periods. When stress conditions arise, discrepancies between “installed” and “available” capacity become evident, leading to exponential increases in the value of each missing megawatt. Consequently, markets react with drastic repricing measures that cannot accommodate previously under-incentivized capacities.
Moreover, synchronous gas units provide essential frequency support and voltage control—services that renewable resources currently cannot replicate at scale. As coal and lignite retire from the energy mix, gas increasingly assumes this critical role. During periods characterized by low inertia in the grid, balancing prices have reached upwards of €600/MWh due to a scarcity of rapid-response capabilities.
For traders in the market, this persistent underpayment clarifies why volatility remains prevalent even amid seemingly stable fundamentals. The market does not overreact; rather it reflects uncertainty regarding future availability of gas-fired insurance capacity—a factor that drives winter peak product premiums between €40 and €70/MWh above baseload prices even in years marked by adequate nominal capacity.
Industrial electricity buyers also face hidden risks stemming from this underpayment issue. While they benefit from stable prices associated with gas plant availability, they indirectly incur costs during outages or plant exits through peak surcharges or emergency pricing during crises. In practical terms, it is estimated that 20-30% of annual electricity expenditures can be traced back to just a few days when system insurance fails.
The regional dynamics further complicate the situation; gas plants operating in one country can stabilize neighboring markets through cross-border flows and frequency coupling. For instance, a flexible unit in Romania may mitigate volatility in Bulgaria while availability in Hungary helps cap prices in northern Serbia. However, compensation mechanisms remain national despite these regional benefits—leading rational investors to underprovide what effectively functions as a public good across borders.
As coal phase-outs accelerate due to climate policies, reliance on gas as an insurance layer intensifies at a time when regulatory signals often portray it as transitional and risky—thereby increasing financing costs. This divergence between systemic reliance on gas for stability and market willingness to pay for it perpetuates volatility within energy markets.
While mechanisms such as capacity payments and ancillary service reforms exist as potential solutions, their implementation remains inconsistent across the region. Current capacity mechanisms frequently undervalue fast-ramping capabilities and short-duration availability by compensating based on installed megawatts rather than usable responses during critical stress periods.
The overarching conclusion is clear: gas-fired capacity within South-East Europe is mispriced as an energy source while functioning fundamentally as insurance against instability. Underpaying for such insurance does not yield savings; instead, it shifts costs into crisis situations that could have been mitigated through adequate compensation structures. For traders and buyers alike, understanding this dynamic is crucial for navigating budget volatility that no average-price hedge can fully address.
Until markets begin explicitly compensating for availability, rapid response capabilities, and inertia—rather than relying solely on energy margins—the underprovisioning of gas capacity will persist alongside structural volatility within the market landscape.
