The South Took Power at Record Prices: How a Heatwave Stress-Tested Russia's Wholesale Electricity Market

In July 2024 the power system of southern Russia rewrote the price history of the country's wholesale electricity market. The average day-ahead price in the region reached 2.59 thousand roubles per MWh, an all-time high, after the price set a new daily record nine times within a single month. Heat, generation outages and a mid-year gas tariff increase combined into a stress test for one of the tightest supply-demand balances in the unified energy system, and the market answered with the strongest regional price signal it has ever produced.

Nine records in one month

The average price on the day-ahead market, the sector of the wholesale market where actually generated megawatt-hours are traded, reached 2.59 thousand roubles per MWh in the southern power system in July 2024. That is the maximum value in the entire history of observations, according to a review by SKM Market Predictor (СКМ Маркет Предиктор) examined by Kommersant (Коммерсантъ). The monthly average stood about 47% above the level of July 2023 and 40% above June 2024, and over the course of the month the price updated its daily record nine times.

The scale of the jump matters even by the standards of a market accustomed to volatility. The growth of the monthly average day-ahead price in the south was the highest among all power systems of the first price zone, the European part of Russia (Россия) and the Urals. July 2024 was therefore not a story of a market warming up everywhere at once; it was a story of a regional squeeze so deep that it pulled the southern price curve away from the rest of the zone. In a zonal market, such divergence is precisely the mechanism through which scarcity is supposed to announce itself.

Records on the day-ahead market are not abstract statistics. They settle the price of a large share of the electricity that factories, utilities and households in the region actually consume, and they feed directly into the single-rate prices that non-household customers pay. Nine daily records in one month mean that for weeks at a time, every megawatt-hour bought on the exchange in the south carried a scarcity premium that no previous summer had produced.

Heat as the primary driver

Analysts at SKM Market Predictor identify the key factor behind the price increase as a surge in domestic consumption: power use in the southern power system grew 15% year on year and 13% month on month, against a background of outdoor temperatures rising by 3 degrees Celsius relative both to the previous month and to July 2023. Cooling load is the most price-inelastic demand there is: when the air temperature climbs, air conditioners run regardless of what the megawatt-hour costs, and the system must find physical energy to serve them in the same hour.

The System Operator (Системный оператор), the dispatcher of the energy system, recorded the physical expression of that heat on July 17, 2024: consumption in the southern power system set a record of 21.13 GW, which is 176 MW above the winter maximum registered on January 13. A summer peak that exceeds the winter peak inverts the traditional planning picture of a Russian power system, where heating load has historically defined the annual maximum. In the south, the cooling load of households and the commercial sector has become the binding constraint.

A summer peak above the winter peak

The inversion has direct consequences for how the region's adequacy should be judged. Capacity that comfortably covers a January morning may fall short on a July afternoon, because the two peaks are built by different consumers with different load shapes. The July 17 record shows that the southern system entered the hottest weeks of 2024 with a reserve margin calibrated for a winter-peaking system, and the day-ahead price did the rest of the work: when the dispatcher's schedule runs out of cheap megawatts, the exchange price moves until demand and the remaining supply meet.

Repairs, outages and the missing gigawatt

Generation assets of the southern power system working at the limit during the July 2024 heatwave

Heat alone would not have produced nine records. The supply side of the equation deteriorated at the same time. At the end of the second week of July, dispatchers had to restrict electricity supply to consumers in the Rostov region and the Krasnodar region because of repairs at the Novocherkassk power station (Новочеркасская ГРЭС), which belongs to Gazprom Energoholding (Газпром энергохолдинг), and at Rostov thermal plant 2 and Volgodonsk thermal plant 2 (Ростовская ТЭЦ-2, Волгодонская ТЭЦ-2), owned by LUKOIL (ЛУКОЙЛ). Planned and emergency repairs removed generation from the system exactly when the cooling load was climbing.

The situation worsened on the daytime of July 16, when a 1 GW unit of the Rostov nuclear power plant (Ростовская АЭС) disconnected. The nuclear block was restarted the following morning, but the System Operator continued to disconnect consumers from electricity supply afterwards, explaining the situation by abnormal heat and the high failure rate of local generation. A single gigawatt is a large share of any regional system; combined with thermal plants already in repair, it turned a tight balance into a deficit that had to be rationed.

The sequence is a textbook illustration of how wholesale power prices are made at the margin. The megawatt-hours that set the July price were not the average ones; they were the last, most expensive ones the system could call upon while a nuclear unit stood still and thermal capacity sat in repair. The Market Council (Совет рынка), the regulator of the energy markets, listed precisely these elements among the causes of the price rise: planned and emergency repairs of generation, and grid constraints that limit how much power can be transferred into the deficit area from elsewhere in the zone.

The regulator's reading: a signal, not a failure

The Market Council's interpretation of the episode is deliberately unsentimental. The increase of the exchange price, the regulator says, is the correct price signal about the need for additional available generating capacity in the region. In the market's own logic, a price spike of this magnitude is not evidence that the mechanism broke; it is the mechanism working, telling investors and planners where the next megawatt is worth building. The Council added that in the situation that had developed, the market worked correctly, as it was supposed to.

One more cost element entered the price in the same month. From July 1, 2024 gas tariffs were raised by 11.2%, and the Market Council named this indexation as an additional factor of the price growth. Gas sets the marginal cost of the thermal generation that covers the south's peak, so a mid-year gas tariff increase travels into the day-ahead price within weeks. The July record is therefore a compound signal: scarcity of capacity in the region, layered on top of a step change in the cost of the fuel that the marginal plants burn.

941 megawatts as the structural answer

The structural response to the signal was already in motion before the heat arrived. Until mid-August 2024, by a government decision, a competitive selection for the construction of new generation with a total volume of up to 941 MW was running in selected territories of the southern power system. The additional generation, a 250 MW block at the Tavricheskaya thermal power plant (Таврическая ТЭС) in Crimea and a 250 MW block at the Udarnaya thermal power plant (Ударная ТЭС) in Taman, is to be built by Technopromexport (ВО «Технопромэкспорт»), a company controlled by Rostec (Ростех), as Kommersant reported on May 17.

The arithmetic of the July squeeze and the arithmetic of the construction programme operate on different clocks. A price record appears in days; a new 250 MW block appears in years. The competitive selection is the market's way of converting a monthly signal into a multi-year investment commitment, and the 941 MW envelope is the measure of how much new capacity the region's balance sheet is asked to finance. Whether that volume closes the gap revealed by the 21.13 GW peak is the question the southern system will answer over the following summers.

How the market cooled

By the beginning of August the day-ahead prices started to decline, according to the trading system's data. Dmitry Pigarev (Дмитрий Пигарев) of the Centre for Economic Forecasting of Gazprombank (Центр экономического прогнозирования Газпромбанка) notes that as the heat in the south eased, the growth rate of electricity demand slowed to 2% year on year. Over the first five days of August, the index of equilibrium purchase prices reached approximately 2.15 thousand roubles per MWh, which is 11% above the same period of the previous year and, in his assessment, fully reflects the change in fuel costs over that period. In his view, the period of peak prices has passed.

The residual 11% is the part of the July story that does not disappear with the weather. It is the gas tariff indexation and the general cost inflation of generation sitting in the price base after the scarcity premium has evaporated. For consumers, the difference between the July record and the August level is the scarcity rent; the difference between August 2024 and August 2023 is the new cost floor. Distinguishing the two is the practical task for anyone reading the southern price curve in the second half of 2024.

What the July episode changes for the wholesale market

Several conclusions follow from the episode, and they extend beyond the south. First, summer consumption peaks can now exceed winter maxima in regions with fast-growing cooling load, which changes what reserve margin adequacy means. Second, price records concentrate where the generation reserve is thinnest and where grid constraints block imports, so regional differentiation inside a single price zone is a permanent feature rather than an anomaly. Third, gas tariff indexation passes into day-ahead prices within weeks, linking the regulated gas agenda to the liberalised power agenda more tightly than either calendar suggests. Fourth, competitive selections for new capacity are the multi-year answer to a monthly signal, and the distance between the two clocks is exactly where price volatility lives.

Summer peaks above winter maxima: the July 17 record of 21.13 GW exceeded the January 13 winter maximum by 176 MW.
Regional divergence inside zone one: the south's monthly average price growth was the highest of all systems in the European part and the Urals.
Compound cost push: the 11.2% gas tariff increase from July 1 entered the marginal cost of thermal generation in the same month.
Structural pipeline: up to 941 MW of new generation was being competitively selected in the south, including two 250 MW blocks by Technopromexport.

Anatomy of the day-ahead market

To read the July record correctly, one has to recall what the day-ahead market actually prices. It is the sector of the wholesale market where suppliers offer actually generated megawatt-hours for the next day, hour by hour, and the trading system selects the cheapest combination that covers the forecast load in each node of the zone. The price of the last selected offer becomes the price for the hour. In a system with comfortable reserves, that marginal offer is usually a mid-cost thermal plant; in a system where repairs and heat have removed the cheap layers, the marginal offer moves up the cost curve, and the hourly price follows it. The monthly average of 2.59 thousand roubles per MWh is therefore a condensed record of hundreds of hours in which the south had to buy its last megawatt-hours expensively.

The first price zone, within which the southern system sits, covers the European part of the country and the Urals. Prices inside a zone are linked by transmission, but the links have physical limits. The Market Council's reference to grid constraints means that in July the south could not simply import its way out of the deficit: the wires into the region were saturated, and the regional price detached upward from the zone average. That is why the south's monthly growth was the highest of all systems in the zone while the rest of the market moved far less.

The south: a deficit region by design of history

The southern power system has long combined fast-growing consumption with a generation fleet concentrated in a handful of large plants. The July repair list reads like a map of that concentration: the Novocherkassk power station, Rostov thermal plant 2, Volgodonsk thermal plant 2 and the Rostov nuclear plant together carry a decisive share of the region's supply. When several of them are simultaneously unavailable, planned or not, the remaining fleet runs at the limit and the exchange price becomes the rationing tool. The government's decision to run a competitive selection for up to 941 MW of new generation in selected southern territories, and the assignment of two 250 MW blocks to Technopromexport at Tavricheskaya and Udarnaya, is an acknowledgement that the region's historical fleet no longer matches its load.

Geography adds a second layer. Crimea and the Taman peninsula, where the two new blocks are to be built, are at the edge of the network, far from the zone's surplus areas. Building capacity at the periphery is precisely the kind of project a price signal of the July type is meant to finance: it removes a permanent import dependency of a weakly connected area and converts a recurring scarcity rent into a one-off construction cost.

Who pays for the record

The day-ahead price does not stay on the exchange. It flows into the single-rate tariffs that non-household consumers pay and into the revenue of suppliers who buy on the market and sell at regulated or contracted prices. A month of records therefore shows up, with a lag, in the electricity bills of southern industry, agriculture and the service sector, and in the margins of the suppliers caught between a spiking purchase price and a sticky sale price. The 11% year-on-year residual that Gazprombank's forecaster observed in early August is the part of that transmission already visible: even after the scarcity premium faded, the price base remained above the previous year's because fuel costs had stepped up.

Households are shielded from the exchange by regulated retail tariffs, but the shield has a budget: the difference between the market price and the regulated one is settled inside the industry. A July like 2024's enlarges that difference and keeps the question of who ultimately finances the southern deficit on the agenda of the regulator and the government, alongside the construction programme that is meant to close it.

Signals to watch

The southern price curve of late 2024 and 2025 will be read against a short list of observable markers. The first is the dynamics of August and September consumption against the 2% year-on-year baseline that Gazprombank's forecaster described: if demand re-accelerates without heat, the July squeeze had a structural component. The second is the outcome of the 941 MW competitive selection and the construction schedule of the Tavricheskaya and Udarnaya blocks, which define when new capacity physically arrives. The third is the behaviour of prices in the 2024-2025 winter, when a cold snap meeting planned repairs would test the same balance from the other side of the year. The fourth is any further gas tariff decision, because the July experience showed how quickly fuel indexation reaches the exchange price.

Until those markers resolve, the July 2024 record stands as the reference point of the southern market: 2.59 thousand roubles per MWh, nine daily records, and a regulator's conclusion that the price did its job. The market produced a signal; the energy system now has to build the answer.