The energy landscape in the Western Balkans is undergoing a significant transformation as coal plants face increasing financial instability. This shift is not only an environmental concern but also poses risks to the financial health of utilities and governments across the region. The first half of May 2026 highlighted the vulnerabilities of aging lignite and coal-fired assets, with coal generation in the broader HU+SEE system declining by approximately 260 MW. Despite this reduction, electricity prices surged, with Serbia’s SEEPEX averaging €101.61/MWh, Montenegro’s BELEN at €98.76/MWh, Bulgaria’s IBEX reaching €104.98/MWh, and Romania’s OPCOM climbing to €115.88/MWh.
This price volatility underscores a critical issue: the region is losing its cheap firm capacity faster than it can be replaced by more flexible energy solutions. While coal remains politically significant, its operational and financial viability is increasingly in question.
A stark example of this trend is evident at RiTE Ugljevik in the Republic of Srpska, which resumed operations in early May after a prolonged shutdown due to coal supply and operational challenges. The plant reported a staggering €18.3 million loss in Q1 2026, with revenues plummeting from €18.8 million the previous year to just €2.2 million, while expenses exceeded €20 million. This situation is indicative of a structural problem rather than a typical cyclical downturn; when coal plants cannot operate effectively, they become contingent liabilities rather than reliable baseload providers.
The state’s intervention in acquiring Comsar Energy RS and its Ugljevik Istok 2 concession for over €120 million illustrates the extent of support required to sustain coal infrastructure, transforming what was once seen as generation security into fiscal exposure.
Similarly, RiTE Gacko reported a modest net profit of approximately €50,000 in Q1 2026, down from €440,000 during the same period last year. Although revenue stood at €24.3 million, rising expenses at around €24.2 million left little room for profitability. This precarious financial position makes Gacko vulnerable to various shocks, including equipment failures and environmental costs.
The situation is mirrored in Montenegro, where Pljevlja’s coalmine saw significantly reduced profits in 2025, and EPCG recorded a €92 million loss before rebounding to profitability in early 2026. This mixed performance highlights the inherent tensions within hydro-coal utility systems, where strong hydrological conditions can enhance earnings but coal exposure remains challenging.
In Serbia, coal continues to play a central role in the national power system. While EPS reported increased profits in 2025 and a profit of €129 million in Q1 2026, the overall market trajectory indicates rising pressures on lignite-based generation—underscoring that current profitability does not mitigate future transition risks.
The challenges facing Western Balkan coal operations can be categorized into four main areas: technical issues stemming from aging infrastructure; financial burdens requiring continuous capital investment; regulatory pressures linked to EU accession and environmental compliance; and market dynamics influenced by expanding solar capacity that reduces coal utilization during peak periods.
This complex environment creates a difficult financial model for coal plants. Traditional baseload economics thrive on high load factors, but an energy system increasingly reliant on renewables demands flexibility that older lignite units are ill-equipped to provide. As such, operators face escalating fixed costs and declining operational predictability.
The implications extend beyond individual companies; they pose sovereign risk concerns as coal utilities often align closely with public balance sheets. When these plants falter, governments may need to intervene through guarantees or liquidity support, thereby converting energy transition risks into fiscal liabilities.
Banks are also reassessing their exposure to coal-related assets amid growing transition risks associated with utilities and infrastructure linked to coal systems. Credit committees are increasingly scrutinizing whether cash flows depend on assets facing declining utilization or rising compliance costs.
The instability surrounding coal operations translates into heightened volatility for electricity traders. A sudden outage at a major lignite facility can quickly tighten regional supply chains, particularly when nuclear or hydro outputs are low. Recent data reflects this trend: decreased firm generation coupled with increased gas usage has led to rising prices despite lower demand levels.
This instability presents both challenges and opportunities for renewable developers. While declining reliability of coal strengthens the case for new renewable investments and storage solutions, inadequate grid planning and slow transitions from firm capacity could heighten system risks and balancing costs.
A comprehensive approach is necessary for transitioning away from coal—one that encompasses coordinated portfolios of wind, solar, storage solutions, hydro optimization, grid enhancements, demand response strategies, and flexible gas resources as needed. Simply substituting coal with solar will not suffice; it is essential to replace both energy production capabilities and system services.
The strategic importance of battery storage and flexible hydro resources cannot be overstated as they provide essential services historically offered by coal plants such as inertia and voltage support. However, renewables alone do not inherently deliver these services without advancements in grid technology.
The political ramifications of transitioning away from coal are significant since these plants often serve as major employers within their communities. A successful transition requires not only energy modeling but also social and financial planning to address potential job losses.
Delaying this transition only compounds existing costs; years of underinvestment in flexible alternatives increase the likelihood of emergency imports and politically sensitive tariff adjustments. Coal assets that seem economically viable due to sunk capital costs may reveal hidden expenses when factoring outages and environmental liabilities into the equation.
The Western Balkans are nearing a critical juncture where financial instability at Ugljevik, margin compression at Gacko, volatility at Pljevlja, and ongoing reliance on coal-heavy systems signal a shift from viewing coal as a secure asset toward managing its decline strategically.
The pressing question remains whether regional governments and utilities will leverage their remaining operational window for credible capacity replacements or continue investing resources into aging assets until failures render transition efforts more costly than proactive measures.
