News and Analytics
04.09.2026
Impact of the European Hydrological Crisis
Prolonged heat and record-low water levels in the Danube River caused significant disruptions for European nuclear generation. On the Romanian stretch, water flow dropped to 1,650 m³/s, forcing the operator Nuclearelectrica to shut down two reactors at the Cernavodă NPP simultaneously for the first time in history. In Hungary, operations at the Paks NPP were curtailed due to a lack of cooling water—even after a slight rise in water levels, only one of the plant's eight units was operating at full capacity.
To cover the deficit, Romania’s Nuclearelectrica began importing Ukrainian electricity via Moldova's state supplier, Energocom, under a long-term memorandum. Additionally, Romania was forced to pause its coal phase-out schedule, bringing two reserve coal-fired units at the Rovinari and Paroșeni thermal power plants (totaling nearly 300 MW of capacity) back online to maintain dispatchable generation until new gas-fired plants are built.
Pricing and Commercial Arbitrage in the DAM and IDM Markets
The pricing environment in Ukraine’s short-term markets remained highly dynamic. In the Day-Ahead Market (DAM) during the last ten days of August, sales volume dropped by 18.9% (to 498,900 MWh). The maximum daily price fell to 3,871 UAH/MWh, while the minimum dropped to 2,018 UAH/MWh. No daily supply deficits were recorded.
Conversely, in the Intraday Market (IDM), sales volume grew by 21.9% (reaching 60,100 MWh), with a maximum price of 5,382 UAH/MWh and a minimum of 3,202 UAH/MWh.
Price volatility and the spread between DAM and IDM rates are creating a favorable environment for commercial arbitrage. Effective trading and the optimization of sales strategies are becoming critical to ensuring high profit margins for Battery Energy Storage Systems (BESS) and gas cogeneration units (CHPs), which are increasingly being integrated into domestic industrial hubs.
Ukrainian Energy Market Review: August 2026
August 2026 brought a series of key shifts to the energy markets in Ukraine and neighboring European countries. The market landscape was heavily influenced by severe weather conditions, updated tariff regulations, and a surge in large-scale financing for new decentralized generation facilities.
Power System Balance and Foreign Trade Dynamics
Renewable energy sources helped drive electricity imports down to their lowest level since the beginning of the year, allowing Ukraine to remain a net electricity exporter for the second consecutive month. In August, export volumes surged by 64.4% compared to July, reaching 382,100 MWh, while imports stood at roughly 184,000 MWh. Hungary accounted for the largest share of Ukrainian exports (approximately 45%), with increased delivery volumes also going to Moldova, Romania, Slovakia, and Poland.
Impact of the European Hydrological Crisis
Prolonged heat and record-low water levels in the Danube River caused significant disruptions for European nuclear generation. On the Romanian stretch, water flow dropped to 1,650 m³/s, forcing the operator Nuclearelectrica to shut down two reactors at the Cernavodă NPP simultaneously for the first time in history. In Hungary, operations at the Paks NPP were curtailed due to a lack of cooling water—even after a slight rise in water levels, only one of the plant's eight units was operating at full capacity.
To cover the deficit, Romania’s Nuclearelectrica began importing Ukrainian electricity via Moldova's state supplier, Energocom, under a long-term memorandum. Additionally, Romania was forced to pause its coal phase-out schedule, bringing two reserve coal-fired units at the Rovinari and Paroșeni thermal power plants (totaling nearly 300 MW of capacity) back online to maintain dispatchable generation until new gas-fired plants are built.
Pricing and Commercial Arbitrage in the DAM and IDM Markets
The pricing environment in Ukraine’s short-term markets remained highly dynamic. In the Day-Ahead Market (DAM) during the last ten days of August, sales volume dropped by 18.9% (to 498,900 MWh). The maximum daily price fell to 3,871 UAH/MWh, while the minimum dropped to 2,018 UAH/MWh. No daily supply deficits were recorded.
Conversely, in the Intraday Market (IDM), sales volume grew by 21.9% (reaching 60,100 MWh), with a maximum price of 5,382 UAH/MWh and a minimum of 3,202 UAH/MWh.
Price volatility and the spread between DAM and IDM rates are creating a favorable environment for commercial arbitrage. Effective trading and the optimization of sales strategies are becoming critical to ensuring high profit margins for Battery Energy Storage Systems (BESS) and gas cogeneration units (CHPs), which are increasingly being integrated into domestic industrial hubs.
Late-August Price Collapse on the Day-Ahead Market
A profound structural shift in pricing during the final third of August evolved into extreme evening peaks and a substantial drop in average prices across all hours of the day. This situation was the result of a synergy between key factors:
Return of Nuclear Power Units: A significant drop in average prices and maximum daily rates (which fell to 3,871 UAH/MWh between August 23 and 29) was directly tied to the completion of scheduled summer maintenance at Ukrainian nuclear power plants (NPPs). On Friday, August 21, 2026, Energoatom wrapped up its planned preventive maintenance ahead of schedule and connected another nuclear unit to the grid (the sixth out of nine located in government-controlled territory). This added approximately 1,000 MW of stable, round-the-clock baseload capacity to the power system.
Extreme "Duck Curve": The overlap of stable nuclear baseload generation with high daytime output from solar power plants (SPPs) created a massive surplus. From August 21–22 onward, during peak solar hours (10:00 AM – 5:00 PM), prices began to crash en masse to the lower price cap of 10.00 UAH/MWh. Renewable energy producers, trying to stay on schedule, dumped their prices to the absolute minimum.
Persistent Evening Deficits: Despite the drop in average prices, during the evening hours (7:00 PM – 11:00 PM)—when solar generation falls off and consumption spikes—prices sharply skyrocketed to 10,000–12,500 UAH/MWh. While baseload nuclear generation can cover a flat consumption profile, it lacks the physical flexibility to rapidly ramp up and smooth out these evening peaks.
Tariffs, Public Service Obligations (PSO), and Regulatory Policy
Following the resolution of a legislative conflict regarding the district heating support law, the national regulator (NEURC) was able to increase Ukrenergo's electricity transmission tariff by 25% to 928.45 UAH/MWh (excluding VAT), effective August 1, 2026. For green electrometallurgy enterprises, the tariff rose by 49% to 563.26 UAH/MWh.
The new tariff structure embeds costs for supporting green generation under Public Service Obligations (PSO) amounting to 19.69 billion UAH out of a total 32.52 billion UAH. Furthermore, distribution tariffs were updated, and NEURC scheduled the adoption of a new Methodology for calculating the residual energy mix, along with approving changes to ensure the stable operation of renewable energy sources.
Energy Project Financing and Auctions
The banking sector has emerged as a powerful engine for energy independence. As of early August, under the memorandum on restoring energy infrastructure, Ukrainian banks had financed projects totaling 60.4 billion UAH (including 56.1 billion UAH for businesses). This has funded the construction of 1.938 GW of new capacity (solar, gas, bioenergy, and wind installations). Energy storage systems accounted for 813 MW of this volume. The structuring of these projects—specifically the registration of new solar power plants on leased land as a Single Property Complex (SPC)—significantly simplifies the process of securing collateralized bank loans, thereby accelerating the launch of new facilities.
Meanwhile, the Guaranteed Buyer announced three "green" auctions scheduled for late September 2026 to allocate an 850 MW support quota (700 MW for wind, 100 MW for solar coupled with storage, and 50 MW for conventional solar). The technical requirements for projects involving storage are strict: the BESS capacity must be at least 80% of the solar plant's capacity, with a minimum duration of 2 kWh per 1 kW of capacity. The price cap for such facilities is set at 12 euro cents/kWh.
The European Vector
On a pan-European level, the European Commission is preparing a reform of EU electricity grid management. Plans are underway to significantly expand the mandate of the EU Agency for the Cooperation of Energy Regulators (ACER) by handing it control over the development of a unified grid development plan. This initiative has already met resistance from several countries, most notably Germany, where transmission system operators (Amprion, TenneT, TransnetBW, and 50Hertz) fear a forced partition of the unified German bidding zone and are demanding that ACER be restricted to a purely supervisory role.
Ivan Nadiein, Founder of UKRTEPLO LLC: "August 2026 clearly highlighted the main vulnerability of our domestic energy system—a critical lack of flexibility. The abnormal 'duck curve,' where daytime DAM prices collapse to 10 hryvnias only to skyrocket past 12,000 during evening peaks, indisputably proves that the era of simply piling on solar megawatts is over. Today, the market demands dispatchability. The strategic focus must decisively shift toward deploying Battery Energy Storage Systems (BESS) and highly maneuverable gas cogeneration units (CHPs).
It is precisely these hybrid decentralized solutions that allow us not only to effectively engage in commercial arbitrage on the DAM and IDM, but to physically balance the grid during peak load hours. Thanks to the active influx of bank capital into distributed generation, we are already shaping a new, resilient energy architecture today—one capable of turning price volatility from a systemic threat into a powerful investment incentive."