In January, the Serbian electricity market exhibited notable trading patterns, with the day-ahead market clearing 404,970.3 MWh. The average daily baseload price was €118.13/MWh, while peak prices reached €136.27/MWh. However, the month’s most stressed day saw peak prices soar to €293.84/MWh and baseload prices at €228.29/MWh. This month highlighted a shift in risk dynamics, moving beyond traditional metrics to encompass two critical layers: the balancing/imbalance layer managed by the Electricity Market Operator (EMS) and the carbon border adjustment mechanism (CBAM) that increasingly influences cross-border electricity transactions.
The balancing layer has emerged as a crucial determinant of scarcity value in Serbia’s energy landscape. It reflects real-time physical system stress rather than just theoretical implications. Analysis of hourly pricing patterns reveals that stress levels peak during late afternoon and early evening hours, with average prices reaching €166.55/MWh at hour 17 and €178.58/MWh at hour 18. This phenomenon is attributed to a classic flexibility premium linked to the operational constraints of domestic lignite generation and the absence of nuclear power, compounded by forecast errors in variable renewable energy sources.
Settlement logic published by EMS plays a significant role in shaping trading strategies. The settlement price is derived from a weighted average of activated resources and is subject to administrative constraints, including a prohibition on negative settlements and caps based on the highest upward activation costs within a specific timeframe. This framework creates a scenario where imbalances are not merely minor penalties but can lead to substantial financial exposure for balance responsible parties (BRPs) when expensive upward energy is activated.
Quantitative assessments reveal that Serbia’s reference balancing energy price for 2026 stands at €154.174/MWh, indicating that the system-level balancing value exceeds January’s baseload average of €118.13/MWh. The economic impact for January hinges on how much energy is settled in imbalance rather than as scheduled. A conservative estimate suggests that if 2% of January’s cleared volume was subject to imbalance pricing, it would represent approximately 8,099 MWh. Depending on the premium applied during stressed hours—ranging from €50/MWh to €150/MWh—the financial implications could range from €0.40 million to over €1 million.
This underscores a critical shift in trading strategy; traditional month-end hedging may no longer suffice as imbalances increasingly dictate market outcomes during peak hours when operational challenges align with schedule errors and reserve scarcity.
The second layer affecting Serbia’s electricity economics is the CBAM framework, which officially commenced on January 1, 2026. Under this regime, carbon certificate prices are linked to EU emissions trading system (ETS) allowances, creating a new layer of complexity for Serbian exporters. The evolving reporting mechanisms now base default emission values on the overall carbon intensity of the exporting country’s power system rather than solely on fossil fuel generation.
Recent reports indicate that EU carbon permits were trading around €81.35/tCO₂ as of February 9, 2026. Serbia’s grid emissions intensity remains high due to its reliance on lignite, with estimates suggesting an intensity range of approximately 0.67–1.05 tCO₂/MWh. This translates into a potential carbon cost of between €54.5/MWh and €85.4/MWh for each megawatt-hour exported under default conditions.
When juxtaposed with January’s market dynamics, this carbon value significantly alters the economic landscape for Serbian exports to the EU. The baseload price of €118.13/MWh effectively transforms into a CBAM-adjusted economic level ranging from approximately €173–203/MWh once carbon costs are factored in. During peak hours where Serbia aims to maximize export revenues—averaging between €166.55–178.58/MWh—the adjusted economic level could rise to between €221–264/MWh before accounting for congestion and transmission losses.
This creates a complex tradeoff for Serbian exporters: demonstrating low-carbon intensity through credible documentation allows them to compete more effectively within EU markets by minimizing carbon basis risks. Conversely, failure to substantiate low-carbon claims could lead to significant economic disadvantages, with potential reductions in effective pricing by €55–85/MWh at current EUA levels.
In summary, January’s trading dynamics reveal critical insights into Serbia’s evolving electricity market landscape where balancing scarcity and CBAM-adjusted economics play pivotal roles in shaping market behavior and strategic decision-making for stakeholders across the sector.
