The first quarter of 2026 places Montenegro in a uniquely exposed position within Southeast Europe’s evolving electricity landscape. Few markets illustrate the duality of the Carbon Border Adjustment Mechanism as clearly: a system benefiting from strong hydro conditions and favourable price spreads, yet simultaneously constrained by carbon-adjusted trade economics that erode export value. The result is a market where physical potential and commercial outcomes diverge, and where the strategic role of infrastructure—particularly the Italy interconnector—is being repriced in real time.
Montenegro entered Q1 2026 with a generation mix that, while partially diversified, remains structurally influenced by thermal output. The Pljevlja coal plant continues to anchor baseload supply, even as hydro output surged during the quarter. Hydropower generation increased from 0.45 TWh to 0.81 TWh, representing a +79% rise, one of the strongest relative increases in the region. This influx of low-cost generation pushed average day-ahead prices down to €85.8/MWh, positioning Montenegro well below EU benchmarks, which remained in the €120–130/MWh range.
On paper, this should have created one of the most attractive export environments in Southeast Europe. The price spread between Montenegro and Southern Italy reached approximately €43/MWh, the widest in the region. Under traditional trading conditions, this differential would have supported strong exports via the submarine HVDC interconnector linking Montenegro to Italy, a strategically critical asset designed precisely to monetise such arbitrage opportunities.
Instead, the opposite occurred. Scheduled exports from Montenegro to Italy declined by over 2,100 MWh per day, while physical flows fell by approximately 1,400 MWh per day compared to Q1 2025. The explanation lies squarely in CBAM. Montenegro’s default emission factor of 0.979 tCO₂/MWh results in a carbon adjustment cost of approximately €73.8/MWh. When applied to exports, this cost effectively absorbs the entire price spread, eliminating the economic rationale for cross-border trade. The interconnector, while physically available, becomes commercially neutralised.
This dynamic has far-reaching implications for Montenegro’s market positioning. The Italy interconnector was conceived as a gateway to premium EU markets, offering Montenegro a structural export channel independent of regional congestion. Under CBAM, its value proposition changes. Instead of serving as a high-margin export corridor, it becomes a conditional asset whose utilisation depends on carbon-adjusted economics rather than raw price differentials. In Q1 2026, this translated into a paradox: the corridor with the strongest price signal delivered weaker commercial flows.
The repricing of interconnector value is visible in capacity markets as well. Despite widening day-ahead spreads, auction clearing prices for the Montenegro–Italy interconnection remained largely unchanged, averaging around €7–8/MWh, similar to 2025 levels. In a fully arbitraged market, capacity prices would be expected to rise in line with spreads. Their stagnation indicates that market participants anticipate limited realisable value once CBAM costs are applied. This decoupling between physical spreads and financial valuation marks a structural shift in how interconnectors are priced and utilised.
Within the domestic market, the impact of CBAM is less direct but equally significant. Montenegro’s electricity pricing remains influenced by regional conditions, particularly hydrology. The strong hydro output in Q1 2026 suppressed prices and supported increased trading activity on the domestic exchange, MEPX, where volumes grew by 49% year-on-year. This increase reflects the need to allocate surplus generation within the region, as export channels to the EU become less accessible.
However, this inward shift in trading comes with limitations. Intra-regional markets within the Western Balkans offer lower price levels and less liquidity compared to EU markets. While Montenegro can increase trade with neighbouring systems such as Serbia, Bosnia and Herzegovina, and Albania, the revenue potential is inherently lower. The result is a compression of overall market value, even in periods of strong generation output.
The divergence between commercial schedules and physical flows adds another layer of complexity. Montenegro remains a key node in the south–north transmission corridor linking Greece, Albania, and the broader European grid. During Q1 2026, increased hydro generation in Albania and Greece led to higher physical flows through Montenegro, even as scheduled commercial exchanges shifted away from CBAM-exposed routes. Electricity continued to move through the Montenegrin system according to network physics, reinforcing its role as a transit country.
This divergence has operational implications. Transmission system operators must manage flows that are not fully aligned with commercial schedules, increasing the risk of congestion and the need for balancing interventions. The concentration of flows along specific corridors can place additional stress on the network, particularly during periods of high generation or demand variability. For Montenegro, which operates a relatively small but strategically important grid, these challenges translate into higher operational complexity and potential cost increases.
The interaction between hydro and thermal generation within Montenegro’s system also deserves attention. While hydro output dominated in Q1 2026, the presence of the coal plant ensures that the system retains a relatively high default emission factor under CBAM. This creates a disconnect between actual generation conditions and the carbon cost applied to exports. Even in periods when hydro provides the majority of output, exports are priced as if they were coal-intensive, reducing competitiveness.
This structural issue highlights a broader limitation of the CBAM framework: its reliance on default emission factors rather than real-time generation data. For Montenegro, this means that short-term improvements in carbon intensity do not translate into immediate economic benefits in cross-border trade. The incentive to increase low-carbon generation is therefore present but delayed, as the market does not fully recognise these changes in the near term.
From an investment perspective, the signals emerging from Q1 2026 are mixed. On one hand, the strong performance of hydro generation and the absence of CBAM costs for low-carbon output reinforce the attractiveness of renewable investments. Montenegro’s existing hydro assets and potential for additional capacity position it favourably in a carbon-constrained market. On the other hand, the limited ability to export electricity to high-value EU markets under CBAM conditions reduces the revenue upside for new projects.
The economics of future investments will depend heavily on the evolution of carbon pricing and regulatory adjustments. If CBAM continues to rely on default emission factors, coal-heavy systems will remain structurally disadvantaged, and the value of interconnectors such as the Italy cable will remain constrained. Conversely, if mechanisms are introduced to recognise actual generation emissions or to align carbon pricing across the region, Montenegro could regain some of its export competitiveness.
The role of system flexibility and storage becomes increasingly important in this context. As hydro output fluctuates and solar capacity expands across the region, Montenegro will need to manage greater variability in generation. Investments in battery storage and grid modernisation could enhance the system’s ability to balance supply and demand, improving both operational efficiency and market positioning. These investments, however, require stable revenue frameworks, which are currently complicated by the uncertainty surrounding CBAM and carbon pricing.
Looking ahead, Montenegro’s electricity market is likely to evolve along two parallel tracks. Domestically and within the Western Balkans, it will continue to operate as part of a relatively integrated regional system, driven by hydrology and intra-regional trade. In relation to the EU, its position will depend on its ability to reduce carbon exposure and adapt to the new economics of cross-border trade. The Italy interconnector, while still a strategic asset, will play a more conditional role, activated when carbon-adjusted spreads justify its use.
The first quarter of 2026 does not represent a steady-state equilibrium but rather a transitional phase in which market participants are adjusting to a new regulatory environment. For Montenegro, this transition is particularly pronounced. The country sits at the intersection of low-carbon potential and high-carbon legacy, with infrastructure designed for a different set of market conditions. Navigating this transition will require a combination of policy adaptation, investment in low-carbon generation, and a redefinition of its role within the regional and European electricity systems.
What is already clear is that Montenegro’s competitive position can no longer be assessed solely on the basis of generation costs or physical connectivity. Carbon economics, embedded through CBAM, now play a decisive role in determining market access and value creation. The ability to align with these economics will define the trajectory of the Montenegrin power market in the years ahead, shaping both its domestic evolution and its integration with the broader European system.
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