As South-East Europe approaches early 2026, the dynamics of its electricity market are increasingly defined by liquidity concentration and the effectiveness of cross-border price transmission. Traditional assessments based solely on national supply-demand balances are giving way to a more complex understanding of how power exchanges operate as integral components of price formation. The operational relevance of these exchanges is marked not just by their trading volumes but also by their ability to absorb market volatility through intraday trading mechanisms.
A distinct liquidity hierarchy has emerged in the region. Leading this hierarchy are Hungary’s HUPX, Romania’s OPCOM, and Bulgaria’s IBEX, each boasting substantial trading volumes that facilitate reliable price references and mitigate the dominance of single assets. Positioned in a middle tier are SEEPEX and CROPEX, which serve as regional anchors while remaining vulnerable to cross-border congestion challenges. At the nascent stage are ALPEX and BELEN, which prioritize transparency and institutional integrity over sheer liquidity metrics.
HUPX stands out as the pivotal integration hub within this landscape. It consistently records daily day-ahead trading volumes between 70–80 GWh, with intraday trading escalating into terawatt-hours monthly. This robust activity fosters an environment where no individual generator or trader can monopolize pricing, ultimately leading to reduced risk premiums in supply contracts for industries relying on this exchange for hedging. The resulting narrower bid-ask spreads enhance market efficiency and diminish imbalance exposure for suppliers.
OPCOM in Romania plays a complementary yet critical role. With monthly day-ahead volumes frequently surpassing 1.4–1.6 TWh, it has transitioned from being merely a corridor market to a substantial volume engine. Its diverse generation portfolio—comprising nuclear, hydro, wind, and gas—contributes to price curves that respond primarily to market fundamentals rather than regulatory interventions. Consequently, average baseload prices in late 2025 and early 2026 hovered around €115–125/MWh, reflecting a well-functioning market clearing process that increasingly serves as a reference point for bilateral contracts extending beyond Romania’s borders.
Bulgaria’s IBEX emerges as the region’s export hub. With monthly day-ahead volumes ranging from 2.2–2.4 TWh and intraday trading exceeding 600 GWh monthly, IBEX is one of the most significant exchanges operationally. Its ecosystem includes over 150 licensed traders alongside various market participants, fostering continuous arbitrage opportunities that prevent unjustified price separations caused by illiquidity.
In contrast, SEEPEX and CROPEX reflect more nuanced roles within the Western Balkans. Serbia’s SEEPEX has evolved into a functional market with annual traded volumes exceeding 5.4 TWh and daily averages nearing 16 GWh. This development is attributed to over 40 active participants from multiple countries influencing pricing behaviors favorably. While volatility persists, it now reflects deeper market dynamics rather than erratic price shifts driven by singular bids. Serbian industries benefit from reduced supplier risk premiums estimated at €4–7/MWh compared to pre-2024 procurement practices reliant solely on bilateral agreements.
CROPEX maintains a hydro-centric approach. The exchange sees monthly day-ahead volumes around 0.8–0.9 TWh bolstered by meaningful intraday trading activities that include short-term products exceeding 50 GWh per month. This liquidity is crucial for industries as it directly mitigates imbalance costs; deeper intraday markets allow risks to be traded rather than administratively priced into fixed margins.
The BSP SouthPool in Slovenia may be small but plays a strategically significant role. Daily trading volumes typically range from 30–40 GWh; however, its integration with ADEX alongside HUPX and SEEPEX enhances its impact on regional liquidity dynamics. ADEX facilitates seamless participation across different markets, allowing traders to optimize strategies across Hungary, Slovenia, and Serbia collectively, thus tightening spreads and accelerating price convergence during stable conditions.
Greece presents a unique case with its power exchange ecosystem. Despite daily volumes exceeding 1.2 TWh, its pricing mechanisms remain highly responsive to gas prices and interconnector availability issues. Frequent directional congestion towards Bulgaria and Italy results in notable price spreads ranging from €6–10/MWh, highlighting an important lesson: significant volume does not inherently equate to lower risks if cross-border constraints persist.
ALPEX represents potential growth rather than current scale. Monthly trading volumes hover around 120–130 GWh with prices between €105–110/MWh indicating an emerging but still shallow market framework. Its future hinges on achieving operational coupling among Albania, Kosovo, North Macedonia, and Greece; such developments could transform ALPEX into a vital corridor for trade across various systems in the southern Western Balkans.
BELEN in Montenegro exemplifies challenges faced by smaller exchanges. With annual traded volumes below 0.35 TWh and daily averages under 1 GWh leading to volatile pricing fluctuations—from €30/MWh up to €230/MWh—this exchange offers transparency but lacks depth for effective hedging strategies. Consequently, suppliers often incorporate higher risk buffers into their contracts due to limited liquidity availability.
The ramifications of these structural dynamics on industrial electricity pricing are tangible rather than hypothetical. Analysis shows that industrial buyers operating within deep coupled markets experience compressed supplier margins averaging €3–5/MWh when day-ahead liquidity exceeds 1 TWh per month while intraday liquidity surpasses 20%. Conversely, markets where intraday liquidity dips below 10% see margins expand toward €8–12/MWh irrespective of prevailing spot prices.
Furthermore, cross-border congestion remains a critical factor; reducing congestion hours by approximately 10–15% annually via improved coupling can lower delivered industrial prices by €5–9/MWh without altering average spot prices significantly—underscoring the importance of infrastructure development over isolated price fluctuations.
The presence of trading firms such as Axpo and Statkraft across multiple exchanges reinforces this discipline; their operations are focused on ensuring price alignment rather than speculative activities. Their ability to trade effectively narrows spreads while local monopolies persist where they cannot operate freely.
By early 2026, the landscape is distinctly organized: Romania and Bulgaria emerge as volume leaders while Hungary serves as an optimization bridge; Greece acts as a major but constraint-sensitive price influencer; Serbia and Croatia solidify their positions as reference hubs amidst increasing liquidity; Slovenia remains small yet strategically amplified through integration efforts; Albania and Montenegro function primarily as transparency markets with future growth reliant on enhanced coupling capabilities.
The implications for industry stakeholders are clear: competitiveness in South-East Europe will hinge less on whether electricity prices fluctuate between “cheap” or “expensive” on any given day but will instead depend significantly on the liquidity levels within reference markets, depth of intraday trading activities, and frequency of open borders during divergent pricing scenarios—ultimately determining how risk is managed versus priced within this evolving landscape.
