As Montenegro approaches the first quarter of 2026, the country finds itself in a precarious position within Southeast Europe’s electricity sector. The introduction of the Carbon Border Adjustment Mechanism (CBAM) has created a complex environment for Montenegrin electricity exports, characterized by both opportunities and significant constraints. While the nation benefits from favorable hydro conditions and competitive price spreads, it also grapples with carbon-adjusted trade dynamics that undermine export profitability.
Montenegro’s energy generation landscape remains heavily influenced by thermal sources, particularly the Pljevlja coal plant, despite a notable surge in hydropower output. In Q1 2026, hydropower generation increased from 0.45 TWh to 0.81 TWh, marking a substantial rise of 79%. This increase in low-cost generation contributed to a decrease in average day-ahead prices to €85.8/MWh, significantly below the EU average of €120–130/MWh.
Under normal circumstances, such favorable pricing conditions would create an attractive environment for exports. The price differential between Montenegro and Southern Italy reached approximately €43/MWh, suggesting potential for robust export activity via the submarine HVDC interconnector linking the two regions. However, actual exports from Montenegro to Italy fell sharply, with scheduled exports declining by over 2,100 MWh per day and physical flows decreasing by about 1,400 MWh per day compared to Q1 2025.
The primary factor behind this decline is CBAM’s impact on export economics. Montenegro’s default emission factor of 0.979 tCO₂/MWh incurs a carbon adjustment cost of approximately €73.8/MWh on exports, effectively negating the price spread that would typically incentivize cross-border trade. Consequently, while the interconnector remains operational, its economic viability has been severely compromised.
This shift has profound implications for Montenegro’s market strategy and positioning within the region. Originally designed as a conduit to lucrative EU markets, the Italy interconnector is now viewed as a conditional asset whose utility is dictated by carbon-adjusted pricing rather than simple price differentials. This has resulted in a paradoxical situation where the corridor with the strongest price signals is experiencing diminished commercial flows.
Furthermore, this repricing trend is evident in capacity markets as well. Despite widening day-ahead spreads, auction clearing prices for the Montenegro–Italy interconnection have remained stable at around €7–8/MWh, mirroring levels from 2025. In an ideal market scenario, one would expect capacity prices to rise in tandem with spreads; however, their stagnation suggests that market participants foresee limited realizable value once CBAM costs are factored in.
On the domestic front, the ramifications of CBAM are less direct but still impactful. Regional hydrological conditions continue to shape electricity pricing in Montenegro, with strong hydro output leading to suppressed prices and increased trading activity on the domestic exchange (MEPX), which saw a year-on-year volume increase of 49%. This uptick reflects an urgent need to manage surplus generation amid reduced access to EU export channels.
However, trading within the Western Balkans presents its own challenges due to lower price levels and liquidity compared to EU markets. While there is potential for increased trade with neighboring countries such as Serbia and Albania, revenue prospects remain constrained. This dynamic compresses overall market value even during periods of heightened generation output.
The divergence between commercial schedules and physical flows introduces additional complexity for Montenegro’s electricity system. The country serves as a critical node in the transmission corridor connecting Greece and Albania to Europe. In Q1 2026, increased hydro generation in these neighboring countries resulted in higher physical flows through Montenegro despite a shift away from scheduled commercial exchanges affected by CBAM.
This situation poses operational challenges for transmission system operators who must manage flows that do not align with commercial schedules, raising congestion risks and necessitating balancing interventions. The concentration of flows along specific corridors can strain Montenegro’s relatively small grid during peak generation or demand fluctuations.
Moreover, while hydropower dominated production in Q1 2026, the presence of coal-fired generation maintains a high default emission factor under CBAM. This disconnect means that even when hydro generation is at its peak, exports are treated as coal-intensive, diminishing competitiveness in cross-border trade.
This structural issue underscores a broader limitation within the CBAM framework: its reliance on default emission factors rather than real-time data on generation emissions. For Montenegro, this means that improvements in carbon intensity do not yield immediate economic benefits for exports—a delay that hampers incentives for increasing low-carbon generation.
Investment signals emerging from Q1 2026 present a mixed outlook. The strong performance of hydropower and absence of CBAM costs for low-carbon output bolster the appeal of renewable investments in Montenegro. However, limited access to high-value EU markets under current CBAM conditions constrains revenue potential for new projects.
The future economics of investments will hinge on developments in carbon pricing and regulatory frameworks. Should CBAM continue relying on default emission factors, coal-dependent systems like Montenegro’s may struggle to regain competitiveness in export markets. Conversely, if mechanisms are introduced that account for actual emissions or harmonize carbon pricing across regions, there could be renewed opportunities for Montenegrin exports.
The importance of system flexibility and storage solutions will also grow as regional generation variability increases due to expanding solar capacity and fluctuating hydro output. Investments in battery storage and grid modernization will be essential for enhancing operational efficiency and market positioning; however, these require stable revenue frameworks currently complicated by uncertainty surrounding CBAM.
Looking forward, Montenegro’s electricity market is set to evolve along two distinct paths: continuing integration within regional systems driven by hydrology and intra-regional trade while simultaneously navigating its relationship with the EU based on carbon exposure reduction strategies. The Italy interconnector will remain strategically important but will function more conditionally based on carbon-adjusted spreads rather than raw price differentials.
The first quarter of 2026 marks not just a transitional phase but also a critical period where market participants must adapt to new regulatory realities. As Montenegro balances its low-carbon potential against its high-carbon legacy infrastructure designed for different market conditions, effective navigation through this transition will require policy adjustments alongside investments in low-carbon generation capabilities.
Ultimately, Montenegro’s competitive position will increasingly depend on its ability to align with evolving carbon economics shaped by CBAM—an essential factor determining both domestic market dynamics and integration into broader European energy systems.
