Renewable volatility and shifting trade patterns are continuing to reshape short-term power signals across Southeast Europe, with Week 09 delivering a broad fall in electricity prices alongside a mixed generation picture. Prices declined across most markets as supply-demand fundamentals improved, while wind and solar output contracted sharply and hydropower partially compensated. For developers and grid stakeholders, the episode underscores how operational variability can quickly propagate into market conditions that influence dispatch planning, offtake assumptions and the timing of grid upgrades.
Week 09 price correction points to softer regional conditions
Across the Southeast European (SEE) region, electricity prices continued their downward trend in Week 09, with broad-based declines reinforcing a softer market environment. Greece fell by -13.46% to €54.07/MWh, while Bulgaria and Romania posted sharper corrections of -22.71% and -21.72% respectively. Hungary dropped -19.67% and Croatia -18.15%, aligning with the regional bearish move, while Serbia declined -14.48%. Turkey recorded the steepest contraction at -29.77%, reflecting significant domestic price adjustment.
Italy stood out as the only market moving higher, edging up 1.76% to €106.67/MWh and maintaining a structural premium over neighboring markets. In Southern Europe, most SEE countries traded below €100/MWh except Italy, with weekly averages spanning €21/MWh to €107/MWh. Turkey registered the lowest weekly average at €20.74/MWh, while Serbia was the second-cheapest SEE market at €46.83/MWh following a -14.48% decrease; Hungary also ranked among the more expensive markets at €86.09/MWh.
Demand softens while wind and solar drop; hydropower offsets
Regional electricity demand softened in Week 09 as total consumption declined -1.87% week-on-week to 17,429.74 GWh, attributed to milder weather and easing load requirements. Hungary (-12.34%) and Croatia (-11.28%) led contractions, while Romania (-5.79%) and Bulgaria (-5.47%) recorded moderate declines. Italy reduced consumption by -4.22% and Greece saw a marginal -1.80% decrease; Serbia edged lower by -3.89%, whereas Turkey diverged with a 3.71% increase adding nearly 250 GWh week-on-week.
Variable renewable generation remained volatile across the SEE region, with wind and solar output down -24.0% week-on-week to 2,995.93 GWh, mainly driven by weaker wind production. Italy experienced the sharpest adjustment as total RES fell sharply (-78.1% wind, partly offset by +4.6% solar), while Croatia recorded a similar collapse (-77.1% total RES, -78.2% wind). Greece and Romania posted declines of -7.5% and -25.1%, despite strong solar gains (+30.1% Greece, +69.5% Romania), and Turkey’s RES output fell -15.5%. By contrast, Hungary (+108.0%) and Bulgaria (+23.2%) saw exceptional RES growth supported by strong solar performance.
Hydropower strengthened across the region, rising 5.97% week-on-week to 3,886.75 GWh and offsetting weaker wind output—an operationally relevant signal for system balancing planning as variable renewables swing output levels quickly. Turkey (+7.86%) and Croatia (+488.6%) led gains, with Romania up 5.50% and Serbia up 36.24%. Bulgaria (-17.82%) and Italy (-11.16%) declined, while Greece saw a marginal -1.49% reduction; Hungary recorded a 20.93% increase despite a smaller hydro base, reinforcing system flexibility amid renewable volatility.
Thermal generation rises as coal and gas adjust
Thermal power generation increased 4.1% week-on-week to 6,270.15 GWh as weaker wind aligned with selective demand shifts that supported conventional dispatch needs during the period of renewable weakness. Lignite/coal generation climbed 5.77% (+165 GWh) and gas-fired output rose 2.56% (+81 GWh). Turkey led with a 10.68% coal surge pushing total thermal to 2,609.78 GWh.
Italy increased thermal dispatch (+8.47% gas alongside a sharp coal rebound), surpassing 2,100 GWh in total thermal generation for the week—an indicator that fuel mix adjustments can remain central when renewables underperform relative to forecasted profiles used in scheduling studies and day-ahead bidding strategies.
Cross-border flows shift sharply; Day-Ahead prices turn upward
Cross-border flows moved significantly in Week 09: net imports fell -79.1% to 1,551.96 GWh as regional trade rebalancing took hold across interconnectors that link national systems into a broader market footprint for balancing energy and congestion management studies.
Bulgaria’s net imports collapsed -99.7%, Hungary fell -35.1%, and Turkey cut net exports -34.1%. Greece increased exports +4.5%, corresponding to a -258.45 GWh net export figure reported for the period; Croatia switched to net importer status and Romania moved from marginal net exports to net imports.
Italy strengthened as a structural net importer (+31.6% to 1,344.68 GWh), while Serbia maintained stable net imports—patterns that can affect how utilities evaluate transmission capacity needs for reliability-driven redispatch as well as how investors frame risk around cross-border price convergence assumptions.
As Week 10 began, Day Ahead prices on March 04 ranged from €99.58/MWh in Serbia and €102.04/MWh in Greece to €142.64/MWh in Hungary and €143.6/MWh in Slovakia, indicating an upward trend after the Week 09 correction window.
Broader implications for project planning and grid modernization
The combination of falling prices in Week 09 with sharp renewable swings—wind and solar down -24% week-on-week while hydropower rose nearly 6%—highlights why technical studies for new wind and solar capacity increasingly need robust operational scenarios covering forecast error ranges, ramping constraints and balancing energy requirements across both domestic grids and interconnector corridors.
For developers preparing EPC packages or grid connection readiness workstreams, the observed pattern supports tighter alignment between resource forecasting inputs used in day-ahead bidding models, transmission reinforcement schedules designed to manage changing flow directions, and procurement timelines for flexibility assets such as storage or dispatchable backup where system conditions warrant it.
At industry level, the Week 09 data points—demand down -1.87%, thermal up 4.1%, net imports down -79.1%, plus an upward Day-Ahead turn into Week 10—reinforce that investment planning for renewables must remain tightly coupled to grid modernization roadmaps that can absorb variability without forcing inefficient curtailment or excessive reliance on short-notice thermal balancing.