The recent surge in European gas prices, driven by geopolitical tensions and disruptions in global energy supply chains, has reignited a significant shift in the energy landscape of Southeast Europe. As natural gas prices soared by over 50% across the continent, utilities have been prompted to reevaluate their power generation strategies, leading to a notable resurgence in coal-fired electricity generation. This shift has resulted in international thermal coal prices climbing by 26%, reaching approximately $133 per tonne.
In Southeast Europe, where coal constitutes a vital part of the electricity generation portfolio, this trend has profound implications for regional electricity trading and cross-border power exchanges. Unlike Western European nations that have progressively phased out coal as part of their decarbonization efforts, many Balkan countries still heavily depend on lignite-fired power plants. These facilities typically serve as baseload generators to meet domestic electricity needs but can also become competitive exporters during periods of elevated gas prices.
Countries such as Serbia, Bosnia and Herzegovina, Bulgaria, and Romania house some of the largest lignite generation capacities in Europe. Key facilities like Serbia’s Nikola Tesla complex, Bosnia’s Tuzla and Kakanj plants, and Bulgaria’s Maritsa East stations produce electricity primarily based on domestic lignite mining operations rather than imported fuels. This structural advantage becomes particularly significant when the costs of imported natural gas escalate.
As gas prices rise sharply, the marginal generation costs for gas-fired power plants increase correspondingly. Consequently, electricity generated from gas becomes more expensive, driving wholesale electricity prices up across interconnected markets. In these scenarios, coal plants with stable fuel costs can emerge as competitive sources of electricity exports to neighboring markets where gas-fired units typically set the marginal price.
This phenomenon is not unprecedented in European electricity markets. Similar patterns were observed during the energy crisis following Russia’s invasion of Ukraine in 2022 when several countries temporarily ramped up coal-based electricity production in response to soaring gas prices. However, the enduring presence of lignite capacity in Southeast Europe renders the region particularly susceptible to these fuel-switching dynamics.
Electricity trading flows are quick to react to changes in marginal generation costs. When coal generation becomes cheaper than gas-fired electricity in adjacent markets, traders are likely to export power from lignite-heavy systems toward regions where gas units dominate pricing. These cross-border exchanges can occur through interconnectors linking Serbia with Hungary and Romania, Bulgaria with Greece and Romania, and Bosnia with Croatia.
The economic viability of these trades is heavily influenced by relative fuel costs and carbon pricing structures across European markets. While coal plants generally face higher carbon emissions costs under the EU Emissions Trading System, many Western Balkan countries remain outside full integration into this market. This means their lignite plants may operate with reduced carbon cost exposure compared to their counterparts in EU member states.
This disparity in carbon pricing can yield temporary competitive advantages for non-EU coal plant electricity exports when gas prices surge. Traders closely monitor these price differentials as they dictate whether cross-border electricity flows will head north toward Central Europe or remain confined within domestic markets.
The recent spike in coal prices indicates a rising demand from utilities seeking alternatives to costly natural gas. Power producers across Europe and Asia have increased their thermal coal purchases to secure fuel supplies amid sustained high gas prices. Although coal prices have risen due to this demand surge, the increase has been less pronounced than that seen in gas markets, allowing coal to maintain a temporary cost advantage in electricity generation.
This scenario underscores Southeast Europe’s role as a flexible electricity supply zone within the broader European power system. During times of high gas prices or insufficient renewable generation in Western Europe, lignite plants in the Balkans can provide additional power through cross-border trading, thus stabilizing regional electricity markets.
However, the long-term prospects for coal within Southeast Europe remain uncertain. The evolving European climate policy landscape and the gradual integration of Western Balkan energy markets into EU regulatory frameworks are anticipated to introduce carbon pricing mechanisms that will elevate the costs associated with lignite-based generation. Additionally, several countries in the region have announced intentions to reduce reliance on coal over the coming decades.
Despite this uncertainty, current market conditions illustrate that coal continues to play a crucial stabilizing role within the European electricity framework. In times of volatility within gas markets, coal-fired power plants can serve as buffers that help sustain electricity supply and mitigate price spikes.
In Southeast Europe specifically, this stabilizing role is particularly evident due to abundant lignite resources and established generation infrastructure. While European energy policy trends toward decarbonization and renewable growth, immediate market dynamics still allow coal to significantly influence electricity pricing structures and cross-border trading activities.
As long as natural gas remains a primary determinant of marginal electricity prices throughout much of Europe, fuel-switching between gas and coal will continue to be a vital mechanism influencing electricity market behavior. Southeast Europe’s substantial coal generation capacity and strategic positioning within interconnected European power networks will ensure its ongoing importance in this balancing act.
