Montenegro’s power market in Q1 2026: hydro gains collide with CBAM export economics

Montenegro’s electricity market in the first quarter of 2026 highlights a growing tension across Southeast Europe: strong low-carbon generation can improve domestic pricing, yet carbon-adjusted trade rules can still erode export value. The country entered the period with hydro conditions that lowered power prices and widened spreads versus EU markets, but CBAM-linked costs neutralised the economic case for cross-border flows—repricing infrastructure that was built to capture those very differentials.

Hydro strength drives lower prices, but not higher export value

Montenegro’s generation mix remains structurally influenced by thermal output even as hydro performs well. The Pljevlja coal plant continues to anchor baseload supply, while hydropower output rose sharply during the quarter. Hydropower generation increased from 0.45 TWh to 0.81 TWh, a +79% rise—one of the strongest relative increases in the region.

The influx of low-cost generation pushed average day-ahead prices down to €85.8/MWh, placing Montenegro below EU benchmarks, which were in the €120–130/MWh range. On paper, this should have created an attractive export environment: the price spread between Montenegro and Southern Italy reached roughly €43/MWh, the widest in the region.

CBAM turns a wide spread into a commercial dead end

Despite the physical opportunity for arbitrage via the submarine HVDC interconnector to Italy, scheduled exports fell and physical flows declined. Scheduled exports from Montenegro to Italy dropped by more than 2,100 MWh per day, while physical flows were about 1,400 MWh per day lower than in Q1 2025.

The driver identified is CBAM. Montenegro’s default emission factor of 0.979 tCO₂/MWh implies a carbon adjustment cost of approximately €73.8/MWh when applied to exports. That cost effectively absorbs the entire €43/MWh price spread versus Italy, removing the economic rationale for cross-border trading even when capacity is available—leaving the interconnector “commercially neutralised.”

Interconnector value shifts from arbitrage to conditional utilisation

The Italy interconnector was designed as a gateway to premium EU markets and a structural export channel intended to monetise price differentials independent of regional congestion. Under CBAM economics, its role changes: it becomes conditional on whether carbon-adjusted spreads justify usage rather than on raw price gaps alone.

This repricing also shows up in capacity-market signals. Even as day-ahead spreads widened, auction clearing prices for the Montenegro–Italy interconnection remained largely unchanged at around €7–8/MWh, similar to 2025 levels. In an environment where value could be fully arbitraged through spreads, capacity prices would typically track those moves upward; their stagnation suggests participants expect limited realisable value once CBAM costs are applied.

Domestic trading absorbs surplus—yet regional liquidity limits upside

CBAM’s effect is less direct inside Montenegro than on EU-bound exports, but it still shapes where surplus generation goes. Strong hydro output suppressed prices domestically and increased trading activity on MEPX (the Montenegrin exchange), where volumes rose by 49% year-on-year.

The increase reflects a need to allocate surplus generation within the region as access to EU export channels becomes less accessible under CBAM economics. However, intra-regional markets across the Western Balkans tend to offer lower price levels and less liquidity than EU markets. Montenegro can expand trade with neighbours including Serbia, Bosnia and Herzegovina, and Albania—but revenue potential remains inherently lower, compressing overall market value even during periods of strong generation.

Physical transit continues even as schedules shift

Montenegro also remains a key node in the south–north transmission corridor linking Greece and Albania to the broader European grid. In Q1 2026, increased hydro generation in Albania and Greece drove higher physical flows through Montenegro even as scheduled commercial exchanges shifted away from CBAM-exposed routes.

This divergence between commercial schedules and network physics has operational implications for transmission system operators: flows may not align with commercial plans closely enough to avoid congestion risk entirely, increasing reliance on balancing interventions. Concentrated corridor flows can add stress during periods of high variability in generation or demand—raising operational complexity and potential cost pressures for a relatively small but strategically important grid.

Coal legacy keeps carbon exposure elevated despite hydro dominance

The interaction between hydro and thermal generation matters under CBAM because Montenegro’s default emission factor does not reflect real-time generation conditions. While hydro dominated output in Q1 2026, the presence of coal means exports are still priced as if they were more carbon-intensive than they physically are during low-carbon periods.

This creates a disconnect between actual system performance and carbon costs applied at export time. The article frames this as a broader limitation of CBAM’s reliance on default emission factors rather than real-time data: short-term improvements in carbon intensity may not translate into immediate economic benefits for cross-border trade.

Investment signals are mixed: renewable appeal versus constrained export revenue

From an investor perspective, signals are described as mixed. Hydro performance supports the attractiveness of renewable investments in a carbon-constrained environment—particularly given Montenegro’s existing hydro assets and potential for additional capacity where low-carbon output avoids CBAM costs.

At the same time, limited ability to sell into high-value EU markets under CBAM conditions reduces upside revenue for new projects tied to export earnings rather than domestic or intra-regional sales.

What could change—and what must be built next

The future investment case depends heavily on how carbon pricing evolves and whether regulatory adjustments recognise actual emissions more directly or align carbon treatment across relevant systems. If CBAM continues using default emission factors that disadvantage coal-heavy systems structurally—and if interconnector value remains constrained—then revenue upside for export-oriented projects will remain limited.

The article also points to growing importance of flexibility as regional solar expands and hydro output fluctuates more widely across seasons. Investments such as battery storage and grid modernisation could help manage variability by improving balancing capability and operational efficiency—though such projects require stable revenue frameworks that remain complicated by uncertainty around CBAM implementation details.

A transitional phase where connectivity is no longer enough

Looking ahead, Montenegro’s electricity market is expected to evolve along two parallel tracks: continued operation within an integrated regional system driven by hydrology and intra-regional trade domestically; and an EU-facing position shaped by how quickly it can reduce carbon exposure under cross-border rules. The Italy interconnector remains strategically important but is likely to be used more conditionally—activated when carbon-adjusted spreads justify it rather than when physical connectivity alone makes exports feasible.

The first quarter of 2026 is therefore not portrayed as a steady-state equilibrium but as a transition period in which market participants adjust to new regulatory economics. For investors and policymakers alike, Montenegro’s competitive position can no longer be assessed solely through generation costs or physical access; carbon economics embedded through CBAM now play a decisive role in determining market access and value creation across borders.