The electricity trading landscape in Romania is increasingly characterized by the dominance of a select group of integrated utilities and substantial suppliers, with independent trading houses gradually enhancing their roles. This shift occurs as cross-border arbitrage opportunities diminish, compelling traders to adapt their strategies in response to changing market conditions.
Leading the Romanian market is Hidroelectrica, which maintains its position as the most influential player. The company boasts the largest generation portfolio in the country, reporting electricity sales of approximately 10.13 TWh in the first nine months of 2025. With a net profit nearing RON 3.3 billion, driven by high-margin hydroelectric generation and optimized output management, Hidroelectrica commands a market share of 14–17%. This solidifies its role as a primary liquidity provider on OPCOM, significantly impacting price dynamics within the market.
Electrica holds the title of the largest commercial supplier in Romania, supplying around 7.3 TWh in 2025 and recording a net profit of approximately RON 1.2 billion. Its EBITDA stands at RON 2.38 billion, reflecting robust activities tied to its retail operations. The company’s trading strategy focuses on procurement and balancing rather than speculative trading, positioning it as a significant player in portfolio management.
OMV Petrom operates one of the region’s most advanced multi-commodity trading platforms. In 2025, it produced about 4.7 TWh from its Brazi gas-fired plant, contributing roughly 9% to national electricity generation. The company reported sales within its gas and power segment amounting to RON 12.7 billion, alongside an operating result of RON 570 million, emphasizing its integrated strategy that combines gas sourcing and power market positioning.
Nuclearelectrica plays a crucial role in providing baseload stability with an annual net profit estimated at RON 2.3 billion, driven by production levels around 7.4 TWh in the first nine months of 2025. The company’s forward-oriented trading approach focuses on long-term contracts rather than short-term volatility, enhancing its stabilizing influence within wholesale markets.
The competitive landscape also includes PPC Energie Romania and E.ON Energie Romania, both controlling mid-to-high single-digit market shares with estimated volumes handled at approximately 4–5 TWh and 3 TWh, respectively. These firms leverage significant procurement capabilities with exposure to cross-border sourcing amid an increasingly interconnected EU market.
A secondary tier of suppliers encompasses Premier Energy Furnizare, Engie Romania, and Getica 95 Com, each managing portfolios between 2–2.5 TWh. Their operational strategies rely on a blend of bilateral contracts and short-term optimization tactics.
The presence of independent traders is growing despite their smaller volume contributions. Tinmar Energy emerges as a leading independent trader with an estimated market share of around 2.7%, equating to roughly 1.3–1.4 TWh. Other notable players include Energy Distribution Services and Nova Power & Gas, which are active primarily in intraday and balancing markets.
The liquidity within Romania’s wholesale electricity market remains robust compared to regional standards, with OPCOM reporting approximately 15.7 TWh traded on the day-ahead market in 2025. Additionally, around 2.2 TWh was transacted on intraday markets, complemented by over 12 TWh across bilateral and OTC platforms. The average price for day-ahead transactions hovered near €114/MWh, indicating sensitivity to regional pricing trends.
<pHowever, opportunities for cross-border trading have diminished significantly due to converging annual average prices across neighboring markets—Romania at approximately €108.2/MWh, Hungary at €108.5/MWh, Bulgaria at €106.9/MWh, and Serbia at about €108.1/MWh. This compression has led traders to shift their focus towards optimizing hourly spreads and managing congestion rather than engaging in directional trades across borders.
The completion of infrastructure projects such as the new 400 kV Reșița–Pančevo interconnector, connecting Transelectrica with Elektromreža Srbije, has increased cross-border capacity to up to1,000 MW and has enhanced liquidity along the Romania–Serbia corridor—an area that is becoming increasingly vital for balancing operations despite Serbia’s non-participation in EU’s core flow-based coupling framework.
The structure of Romania’s electricity trading market continues to diverge from Western European models where speculative trading plays a larger role; instead profitability is largely anchored in effective portfolio optimization strategies employed by integrated utilities and major suppliers dominating both volume and financial outcomes.
