Nordic Electricity Market Analysis: March 24, 2026

Drafted by Gemini 2.5 Flash and reviewed by Claude Sonnet 4. Sourced from NordPool, SMHI, SvD Näringsliv, DN Ekonomi, SVT Ekonomi, and Second Opinion. Please note: This information is AI-generated and provided as-is without warranty. Readers should independently verify all data before making decisions.

Executive Summary

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The Swedish electricity market in SE3 on March 24, 2026, experienced a notable decrease in day-ahead spot prices, settling at an average of 343.55 SEK/MWh. This marks a significant drop from yesterday’s 383.54 SEK/MWh and is well below the 7-day average of 652.9 SEK/MWh, continuing a trend of high volatility seen over the past week. Prices plunged to a minimum of 35.41 SEK/MWh during midday, creating substantial arbitrage opportunities. Price spreads across bidding areas remained significant, with SE4 experiencing the highest average prices due to persistent transmission constraints. Ancillary service markets showed a dramatic 36% decline in FCR-N prices, while FCR-D Down increased, indicating a shift in system needs towards managing oversupply, further evidenced by extensive mFRR EAM down-regulation. Geopolitical tensions, particularly concerning the Iran conflict, continue to introduce uncertainty in the broader energy market, though their immediate impact on Nordic day-ahead prices was less pronounced today.

Day-Ahead Spot Prices

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Commentary Day-ahead spot prices in SE3 for March 24, 2026, saw a considerable decline, with the average price falling to 343.55 SEK/MWh. This represents an 11.7% decrease from yesterday’s average of 383.54 SEK/MWh and is significantly lower than the 7-day average of 652.9 SEK/MWh. This significant drop is part of a recent trend of high volatility, contrasting sharply with the peak of 1100.8 SEK/MWh on March 20 and the even lower 318.0 SEK/MWh on March 22 (Sunday). The market exhibited extreme hourly fluctuations, with prices plunging to a minimum of 35.41 SEK/MWh at 14:00 CET. The highest price for the day reached 689.87 SEK/MWh at 07:00 CET. The peak average price (08:00-20:00 CET) was 332.17 SEK/MWh, a substantial reduction from yesterday’s 444.82 SEK/MWh. Conversely, the off-peak average increased to 366.31 SEK/MWh from yesterday’s 260.99 SEK/MWh, indicating a flatter price curve with sustained higher prices during the night and early morning hours before the midday dip. The lower prices on March 21 (Saturday, 435.6 SEK/MWh) and March 22 (Sunday, 318.0 SEK/MWh) illustrate a typical weekend effect of reduced demand, with today’s Tuesday price continuing the lower trend from the start of the week. This overall price reduction suggests an increase in available supply or a decrease in demand, particularly during the middle of the day.

Price Spread Across Bidding Areas

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Commentary Significant price spreads persisted across the Swedish bidding areas on March 24. SE1 and SE2 continued to exhibit considerably lower average prices at 97.76 SEK/MWh and 77.36 SEK/MWh, respectively, reflecting their typically higher generation capacity relative to demand. SE3’s average price of 343.55 SEK/MWh was notably higher than the northern areas but significantly lower than SE4, which recorded the highest average at 583.16 SEK/MWh. The maximum price in SE4 reached an extreme 1584.19 SEK/MWh, indicating severe congestion or scarcity in that region at certain hours. The wide price differentials, particularly between SE2 and SE3 (266.19 SEK/MWh difference) and SE3 and SE4 (239.61 SEK/MWh difference), underscore ongoing transmission constraints within Sweden. These bottlenecks limit the flow of cheaper power from northern regions to the more demand-heavy southern areas, creating significant value for local flexibility assets like BESS in SE3 and SE4.

News & Geopolitical Context

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Today’s market was influenced by a mix of planned and unplanned grid events, alongside persistent geopolitical tensions impacting the broader energy landscape.

Geopolitical and Macroeconomic News: The ongoing conflict involving Iran, Israel, and the US continues to be a dominant theme, with several reports highlighting its potential for escalation and broader economic impact. News from March 24th indicates Iran’s denial of negotiations with the US, coupled with “special plans” against Israel and its allies. An Iranian missile strike in Tel Aviv and continued Israeli attacks on Lebanon further escalate tensions. This follows reports from March 23rd about President Trump’s threats to close the Strait of Hormuz, causing a stock market fall and higher oil prices, though he later announced a five-day pause on attacks against Iranian energy targets. The Swedish Foreign Minister warned of a potential long-term major war, leading to increased costs for diesel and fertilizer for Swedish farmers, and a risk of stagflation in the Eurozone. These developments, while not directly altering Nordic day-ahead electricity prices in the short term, create a highly uncertain macroeconomic environment that could impact fuel costs and investor sentiment in the long run.

Energy Industry News:

• Nuclear Power Plans in Sweden: Kärnfull Next has applied to the government to build 4-6 small modular nuclear reactors near Valdemarsvik (SE3), hailed as a “historic day” by the acting Climate and Environment Minister. This signifies a long-term strategic shift towards nuclear energy in Sweden, which could eventually reduce reliance on fluctuating renewable sources and potentially stabilize prices.
• District Heating Losing Market Share: A report from Second Opinion indicates that district heating is losing market share to heat pumps as heating demand decreases. This trend could shift electricity demand patterns, potentially increasing electricity consumption for heating in individual households.
• Biofuel Concerns: An SVT investigation revealed that Neste, a major bio-fuel producer, is using prohibited palm oil instead of recycled frying oil for aviation fuel, raising concerns about deforestation and environmental impact. This could lead to stricter regulations or higher costs for sustainable biofuels, affecting the broader energy mix.

Market Announcements (UMMs) & Grid Events: Several planned and unplanned unavailabilities were reported, impacting generation and transmission across various NordPool areas and beyond:

• SE3 Specific Events:
  • Planned Production Unavailability: Ringhals block 4 - G42 (SE3) reported planned maintenance starting March 24th at 15:49 CET. This is a significant nuclear power unit and its outage could impact local supply.
  • Planned Production Unavailability: Rya KVV (SE3) has planned maintenance for modification of burners and tubes, starting March 23rd at 14:49 CET.
  • Other Market Information: Vattenfall AB reported “Other market information” for SE3 with events starting March 23rd at 10:00 CET and stopping March 26th at 14:00 CET (multiple entries). The exact nature is not detailed but implies ongoing market adjustments.
  • Planned Transmission Unavailability (Dismissed): A planned unavailability for transmission from SE3 to DK1, published March 24th at 09:41 CET, was dismissed due to foreseen maintenance.
  • Ingrid Capacity AB: “Other market information” for SE3, SE4, active from Feb 24th to March 26th. This likely refers to battery capacity.
• SE1 and SE2 Events:
  • Unplanned Production Unavailability: Porjus - G12 (SE1) experienced unplanned failures, reported at 01:29 CET and 07:35 CET.
  • Unplanned Production Unavailability: Husum Pulp (SE2) reported multiple unplanned operation problems at 15:30 CET and 16:24 CET.
  • Unplanned Production Unavailability: Blackfjället (SE2) had an unplanned substation trip on March 23rd at 16:01 CET.
  • Planned Production Unavailability: Messaure - G2 (SE1) and Björnberget (SE2) (dismissed due to postponement) had planned maintenance.
• Norwegian (NO) Events: Multiple planned and unplanned unavailabilities were reported for production units (Holen - G1, Skjomen - G1, Tysso 2 - G2, Songa, Saurdal - G2/G3/G4, Kvilldal - G2) and consumption units (Hydro Alu. Karmøy, Alcoa Mosjøen), as well as planned transmission unavailability between NO2 and NO5. Of particular note are unplanned power supply failures at Hydro Alu. Karmøy (NO2) and issues with control systems at Skjomen - G1 (NO4).
• Finnish (FI) Events: Planned maintenance for Alholmens Kraft - B2, Jämsänkoski Paper Mill, Anjalankoski Paper Mill, and Niinimäki Windfarm. Unplanned consumption unavailability at Stora Enso Oulun tehtaat and Tornio / TW.
• Danish (DK) Events: Planned maintenance for Amagervaerket - Blok 4 (DK2).
• Belgian (BE) Events: Numerous planned and unplanned unavailabilities for various production units (COO, FLEMALLE TH1, DROGENBOS 1, ZANDVLIET 1, SCHELDELAAN EXXONMOBIL) and “Other market information” indicating ongoing market adjustments.
• Irish (IE) Events: Unplanned unavailability for Southwall BESS (IS2) reducing availability to 15MW on both charge and discharge, reported on both March 23rd and 24th. This is a critical event for BESS operators. Dublin Waste to Energy and Coolkeeragh also reported unplanned failures.
• Other European Events: Planned transmission unavailabilities in Poland-Lithuania, Lithuania-Latvia, Estonia-Latvia, and Netherlands-Great Britain. Planned production unavailability in Netherlands (EEMS 4) and unplanned for EEMS 20.

The sheer volume of UMMs, particularly the unplanned outages in production and consumption units across the Nordic and interconnected markets, suggests a period of heightened operational challenges and reduced system flexibility. The planned maintenance at Ringhals 4 in SE3 is a significant local event.

Ancillary Services

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FCR-N

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The average FCR-N price for March 24 was 19.52 EUR/MW, with a minimum of 18.74 EUR/MW and a maximum of 20.24 EUR/MW.

Commentary Compared to the 7-day historical data, today’s FCR-N average of 19.52 EUR/MW is significantly lower than the previous day’s 30.5 EUR/MW, representing a dramatic 36% decline, and also well below the 7-day average of 25.0 EUR/MW. This sharp decrease suggests an increased supply of FCR-N capacity or reduced demand for the service, potentially influenced by overall system stability or the entry of new providers, making the market less lucrative for frequency containment. The price range remained relatively narrow, indicating a stable but lower-priced market.

FCR-D

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FCR-D Up averaged 5.08 EUR/MW (min 3.01, max 7.32 EUR/MW). FCR-D Down averaged 9.87 EUR/MW (min 8.03, max 12.97 EUR/MW).

Commentary FCR-D Up prices today averaged 5.08 EUR/MW, which is higher than yesterday’s 3.6 EUR/MW and closer to the 7-day average of 4.0 EUR/MW. FCR-D Down prices averaged 9.87 EUR/MW, a notable increase from yesterday’s 5.6 EUR/MW and also higher than the 7-day average of 7.6 EUR/MW. This divergence, with FCR-N falling and FCR-D Down rising, suggests a shift in system needs from general frequency stability to a more specific requirement for downward regulation, likely due to increased intermittent generation and lower overall demand.

mFRR CM

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mFRR CM Up averaged 2.72 EUR/MW (min 1.99, max 2.97 EUR/MW). mFRR CM Down averaged 2.73 EUR/MW (min 1.0, max 3.0 EUR/MW).

Commentary mFRR Capacity Market prices remained relatively low and stable. The average prices for both Up and Down regulation were around 2.7 EUR/MW. This indicates sufficient available capacity in the mFRR market, with no significant scarcity premiums.

mFRR EAM

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The average imbalance price was 6.97 EUR/MWh, with a minimum of -5.0 EUR/MWh and a maximum of 72.22 EUR/MWh. Total activated up regulation was 0.0 MW, while activated down regulation was 3411.0 MW. The system was in down-regulation for 12 hours and up-regulation for 1 hour. The average spread against day-ahead prices was -30.14 EUR, with a maximum up spread of 3.1 EUR and a maximum down spread of -60.6 EUR.

Commentary The mFRR Energy Activation Market (EAM) data clearly indicates a system in significant oversupply. With 3411.0 MW of activated down regulation and only 0.0 MW of up regulation, the need to reduce generation was dominant. This is further supported by 12 hours of down-regulation compared to just 1 hour of up-regulation. The average imbalance price of 6.97 EUR/MWh and the substantial negative average spread of -30.14 EUR against day-ahead prices confirm that the real-time market was consistently cheaper than the day-ahead market, particularly during periods of oversupply. The most extreme down-regulation spread was -60.6 EUR at 07:00 CET, reflecting strong pressure to reduce generation. This pattern is consistent with the very low day-ahead prices observed during midday, indicating a system struggling to absorb excess power.

Weather Conditions

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Commentary Forecasted weather for SE3 on March 24, 2026, indicates mild spring conditions with average temperatures ranging from 5.1°C to 5.4°C across major cities. Wind speeds are moderate, averaging between 4.8 m/s and 6.6 m/s. Precipitation is expected, particularly in Göteborg (5.1 mm), while Linköping and Stockholm anticipate minimal rainfall. Cloud cover is generally high (6-8%). Comparing this to the 7-day weather history, today’s average temperature of approximately 5.2°C is in line with the period average of 5.1°C. Notably, yesterday, March 23rd, experienced significantly higher precipitation at 7.2 mm. This higher hydro inflow from yesterday likely contributed to the increased power supply and subsequently lower day-ahead spot prices observed today. Moderate wind speeds are expected to support wind power generation, further contributing to the overall supply, while mild temperatures generally lead to lower heating demand, reducing overall consumption pressure.

Grid & Market Events

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• Planned Production Unavailability: Ringhals block 4 - G42 (SE3) (Published: 2026-03-24 15:49 CET) - Planned maintenance on a significant nuclear power unit in SE3. This will reduce local generation capacity.
• Other market information: Vattenfall AB (SE3) (Published: 2026-03-24 15:59 CET, 2026-03-24 13:13 CET, 2026-03-24 09:40 CET, 2026-03-23 14:36 CET) - Multiple notifications from Vattenfall regarding events in SE3, active from 23.03.2026 10:00 CET to 26.03.2026 14:00 CET. These suggest ongoing operational adjustments or market-related information impacting the SE3 area.
• Planned Production Unavailability: Rya KVV (SE3) (Published: 2026-03-23 14:49 CET) - Planned maintenance for modification of burners and tube, impacting a significant combined heat and power plant in SE3.
• Other market information: Ingrid Capacity AB (SE3, SE4) (Published: 2026-03-23 15:46 CET) - Active from 24.02.2026 00:00 CET to 26.03.2026 00:00 CET, likely relating to battery energy storage system (BESS) operations or capacity.
• Unplanned Production Unavailability: Husum Pulp (SE2) (Published: 2026-03-24 16:24 CET, 2026-03-24 15:30 CET) - Unplanned operational problems at a production facility in SE2, potentially reducing power supply from the north.
• Unplanned Production Unavailability: Porjus - G12 (SE1) (Published: 2026-03-24 07:35 CET, 2026-03-24 01:29 CET) - Unplanned failures at a hydropower plant in SE1.
• Planned Transmission Unavailability: SE3 → DK1 (Dismissed) (Published: 2026-03-24 09:41 CET) - A planned maintenance on the interconnector between SE3 and DK1 was dismissed. This is positive for cross-border capacity.
• Planned Transmission Unavailability: SE3 → NO1, SE2 → NO3, NO5 → NO3, NO3 → NO5 (Published: 2026-03-23 21:48 CET) - Disconnection due to reconstruction of old grid infrastructure, impacting transmission capacity between Sweden and Norway.
• Unplanned Production Unavailability: Southwall BESS (IS2) (IE) (Published: 2026-03-24 14:17 CET, 2026-03-23 10:47 CET) - Reduced availability (to 15MW) for both charge and discharge at an Irish BESS. While not directly in SE3, it highlights operational challenges for BESS operators. Dublin Waste to Energy and Coolkeeragh also reported unplanned failures.

Commentary The grid and market events for March 24th highlight a mixed picture of operational stability. The planned maintenance at Ringhals 4 and Rya KVV in SE3 are significant, as they remove substantial generation capacity from the local market, potentially creating upward price pressure during peak demand periods. However, the dismissal of the planned transmission unavailability between SE3 and DK1 is a positive development, maintaining crucial cross-border capacity. Unplanned outages at Husum Pulp (SE2) and Porjus (SE1) could reduce power imports from northern Sweden, potentially increasing pressure on SE3’s generation and exacerbating price spreads if congestion occurs. The ongoing “Other market information” from Vattenfall for SE3 suggests that the market is actively responding to various operational factors. The reduced availability of the Southwall BESS in Ireland, while geographically distant, serves as a critical case study for BESS operators, highlighting the operational risks and challenges that can impact overall system flexibility and ancillary service provision, emphasizing the importance of robust maintenance and operational planning.

Implications for BESS in SE3

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The market conditions on March 24, 2026, presented a complex but potentially profitable environment for Battery Energy Storage System (BESS) operators in SE3.

The significant drop in day-ahead spot prices, particularly the plunge to a minimum of 35.41 SEK/MWh at 14:00 CET, created substantial arbitrage opportunities. BESS operators could have charged their systems during these ultra-low-price hours and discharged during the evening peak (e.g., 17:00-19:00 CET, when prices were between 521.48 SEK/MWh and 566.21 SEK/MWh) or the morning peak at 07:00 CET, which reached 689.87 SEK/MWh. This offers a potential price spread of over 650 SEK/MWh for a single cycle, highly favorable for energy shifting strategies.

In the ancillary service markets, FCR-N prices softened considerably to an average of 19.52 EUR/MW, a 36% drop from yesterday, suggesting less lucrative opportunities compared to previous days. However, FCR-D Down prices increased to 9.87 EUR/MW, indicating a higher demand for downward regulation. A 1 MW BESS unit providing FCR-D Down could have earned approximately 236.88 EUR (9.87 EUR/MW * 24 hours) today. This aligns with the significant down-regulation observed in the mFRR EAM. BESS units capable of providing FCR-D Down could have found reasonable revenue streams, especially during periods of oversupply.

The mFRR EAM was dominated by down-regulation (3411.0 MW activated, 12 hours of down-regulation), with a substantial negative average spread of -30.14 EUR/MWh against day-ahead prices. This indicates a strong need for the system to shed load or reduce generation in real-time. For BESS operators, this presents significant opportunities to participate in down-regulation by charging their batteries, effectively consuming excess power and earning revenue from the negative imbalance. The single hour of up-regulation at 08:00 CET with a positive spread of 3.1 EUR/MWh also highlights brief windows for up-regulation services.

The persistent and wide price spreads between SE1/SE2 and SE3/SE4 (e.g., 266.19 SEK/MWh between SE2 and SE3) underscore the value of BESS in mitigating transmission constraints by providing local flexibility and reducing the need for costly imports. Furthermore, the unplanned unavailability of the Southwall BESS in Ireland serves as a critical reminder of operational risks. For SE3 BESS operators, ensuring high reliability and robust maintenance schedules is paramount to capitalize on market opportunities and avoid revenue losses from unexpected outages.

Outlook

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The immediate outlook for the SE3 market suggests continued volatility, influenced by the ongoing planned maintenance at Ringhals 4 and Rya KVV, which will reduce local generation capacity. While the dismissal of the SE3-DK1 interconnector outage is positive, unplanned outages in northern Sweden (SE1, SE2) could constrain imports. Geopolitical tensions, particularly the Iran conflict, remain a significant long-term risk factor for energy prices, although their direct impact on Nordic day-ahead prices might be dampened by local supply-demand dynamics and weather. Mild weather forecasts for the coming days should keep demand in check, but the interplay of generation outages, transmission constraints, and renewable output will continue to drive price formation and ancillary service needs.