UK Electricity decreased 32.15 GBP/MWh or 31.38% since the beginning of 2025, according to the latest spot benchmarks offered by sellers to buyers priced in megawatt hour (MWh). This dataset includes a chart with historical data for the United Kingdom Electricity Price.

A comparative table of weekly UK wholesale market prices across key energy commodities, including gas, electricity, coal, EUA carbon, UKA carbon, and Brent crude oil. The table includes current, previous, and year-on-year values for both day-ahead and year-ahead contracts, as well as 12-month highs and lows.

Wholesale electricity prices in the United Kingdom hit a record-high in 2022, reaching **** British pence per kilowatt-hour that year. Projections indicate that prices are bound to decrease steadily in the next few years, falling under **** pence per kilowatt-hour by 2030.

Daily data showing the System Price of electricity, and rolling seven-day average, in Great Britain. These are official statistics in development. Source: Elexon.

In April 2025, electricity prices in the United Kingdom amounted to **** British pounds per megawatt-hour, a decrease from the previous month. A record high was reached in August 2022 when day-ahead baseload contracts averaged ***** British pounds per megawatt-hour.
Electricity price stabilization in Europe Electricity prices increased in 2024 compared to the previous year, when prices stabilized after the energy supply shortage. Price spikes were driven by the growing wholesale prices of natural gas and coal worldwide, which are among the main sources of power in the region.

… and in the United Kingdom? The United Kingdom was one of the countries with the highest electricity prices worldwide during the energy crisis. Since then, prices have been stabilizing, almost to pre-energy crisis levels. The use of nuclear, wind, and bioenergy for electricity generation has been increasing recently. The fuel types are an alternative to fossil fuels and are part of the country's power generation plans going into the future.

Electricity prices in Europe are expected to remain volatile through 2025, with Italy projected to have some of the highest rates among major European economies. This trend reflects the ongoing challenges in the energy sector, including the transition to renewable sources and the impact of geopolitical events on supply chains. Despite efforts to stabilize the market, prices in countries like Italy are forecasted to reach ****** euros per megawatt hour by February 2025, indicating persistent pressure on consumers and businesses alike. Natural gas futures shaping electricity costs The electricity market's future trajectory is closely tied to natural gas prices, a key component in power generation. Dutch TTF gas futures, a benchmark for European natural gas prices, are projected to be ***** euros per megawatt hour in April 2025. This represents an increase of about ** euros compared to the previous year, suggesting that gas prices will continue to influence electricity rates across Europe. The reduced output from the Groningen gas field and increased reliance on imports further complicate the pricing landscape, potentially contributing to higher electricity costs in countries like Italy. Regional disparities and global market influences While European electricity prices remain high, significant regional differences persist. For instance, natural gas prices in the United States are expected to be roughly one-third of those in Europe by March 2025, at **** U.S. dollars per million British thermal units. This stark contrast highlights the impact of domestic production capabilities on global natural gas prices. Europe's greater reliance on imports, particularly in the aftermath of geopolitical tensions and the shift away from Russian gas, continues to keep prices elevated compared to more self-sufficient markets. As a result, countries like Italy may face sustained pressure on electricity prices due to their position within the broader European energy market.

The Electricity Supply industry has developed considerably since its liberalisation in 1999. Following a period in which the Big Six suppliers dominated, energy regulator Ofgem endeavoured to introduce greater competition to the market as part of attempts to drive down energy bills. Major mergers and acquisitions effectively brought the dominance of the former Big Six suppliers to an end at the end of 2019-20. Along with weakening electricity consumption, swelling competition has applied further pressure on revenue in recent years. Electricity suppliers' revenue is slated to climb at a compound annual rate of 4.7% to reach £49.8 billion over the five years through 2024-25. The introduction of the standard variable tariff price cap in January 2019 squeezed revenue growth. The pandemic exacerbated the drop in revenue, as widespread tariff reductions compounded the effects of reduced electricity consumption. With suppliers bound by the energy price cap, soaring wholesale prices led to widening operating losses in 2021-22, albeit with a modest revenue recovery. A renewed spike in wholesale prices led to a continued wave of insolvencies among energy suppliers going into 2022-23, with 31 suppliers falling victim to the energy crisis. Soaring non-domestic energy bills and significant hikes to the SVT price cap spurred significant revenue growth in 2022-23, while the transfer of customer accounts from failed suppliers reinstated the dominance of major suppliers. The introduction of the Energy Price Guarantee (EPG) and support for business energy customers prevented energy prices from spiralling out of control going into 2023-24. A faster-than-anticipated drop in wholesale electricity prices has eased pressure on operating profit in the current year, contributing to an estimated 10.1% revenue contraction. Revenue is forecast to sink at a compound annual rate of 0.9% to £47.6 billion over the five years through 2029-30. Prices will remain elevated in the medium term as concerns surrounding supplies of Russian fossil fuels into Europe inflate wholesale costs. Wholesale prices are set to stabilise in the long term, spurring tariff reductions. The continued drop in electricity consumption is also set to limit growth prospects in the coming years.

In April 2025, the average wholesale electricity price in France amounted to 42.21 euros per megawatt-hour, a decrease from the previous month. The electricity price was more than twice as high during the same month the previous year.

UK Gas fell to 76.96 GBp/thm on June 30, 2025, down 1.29% from the previous day. Over the past month, UK Gas's price has fallen 5.35%, and is down 1.38% compared to the same time last year, according to trading on a contract for difference (CFD) that tracks the benchmark market for this commodity. UK Natural Gas - values, historical data, forecasts and news - updated on June of 2025.

Electricity Production in the United Kingdom increased to 64050 Gigawatt-hour in the fourth quarter of 2024 from 50000 Gigawatt-hour in the third quarter of 2024. This dataset has Electricity Production values for United Kingdom.

Non-domestic consumers with consumption between *** megawatt-hours and ***** megawatt-hours tended to pay higher electricity prices than those users with consumption greater than ****** megawatt-hours. As of 2023, electricity prices for these consumers amounted to ***** pence per kilowatt-hour and ***** pence per kilowatt-hour, respectively. Generally, for both consumption rates, electricity prices presented a trend of growth with a peak in 2023.

The electricity delivery process has experienced a major shift in recent years, driven by a push to reduce emissions. Governments across Europe are actively moving away from conventional sources of electricity generation, leading to a decline in the continent's dependency on fossil fuels. According to the International Energy Agency (IEA), renewables accounted for 41.7% of electricity generation in Europe in 2022, up from 32.9% in 2017. The rise of renewables has spurred an influx of renewable generators and necessitated increased investment in electricity networks. This has lifted revenue for transmission and distribution network operators. Revenue is forecast to rise at a compound annual rate of 8.7% over the five years through 2025, reaching €2.8 billion. Falling wholesale prices and a reduction in overall electricity consumption spurred a drop in revenue during the pandemic. Excess demand for natural gas as economies loosened pandemic-related restrictions spurred a strong rebound in wholesale electricity prices in 2021, translating to a jump in revenue. Wholesale prices recorded a renewed spike following Russia’s invasion of Ukraine, spurring a surge in revenue generated by electricity producers and suppliers. Renewable generators were able to rake in extra profits from electricity sold to wholesale markets at inflated prices, counterbalancing a significant rise in costs for fossil fuel generators and electricity suppliers. Wholesale prices have since come-down as Europe has diversified its fuel mix away from Russian gas. Revenue is forecast to decline by 5.1% in the current year. Revenue is forecast to increase at a compound annual rate of 0.3% over the five years through 2030 to €2.9 billion. The revised Renewable Energy Directive of the EU has set a goal for 69% of electricity to be generated from renewables by 2030. Electricity generators will continue expanding their renewables capacity, while investment in upgrading the electricity network to accommodate the rapid shift to renewables will boost income for transmission and distribution network operators. Rising renewable electricity generation will place downward pressure on wholesale prices, though the electrification of heat and transport is set to spur an uptick in demand for electricity across the continent.

These data were collected for a project investigating bidding behaviour in the electricity wholesale markets in England and Wales between 1996 and 2004, concentrating on the period between April 1999 and March 2001. This sub-period covered the last two years of the Electricity Pool of England and Wales, a compulsory centralised market which was abolished in favour of the New Electricity Trading Arrangements (NETA) based upon voluntary bilateral trading, as far as possible. Proponents of the change believed that the Pool had been subject to manipulation and would inevitably produce less competitive results than a more normal market.

This study comprised two parts: an in-depth investigation of bids made by individual stations, using existing industry data, and a high-level modelling exercise to simulate prices over the entire period, for which a new dataset of information on power stations, costs, and demand levels was collected. This dataset allowed the simulation of prices over the period, and to compare the simulations with actual prices. The principal investigators' hypothesis, supported by the results, was that if an unchanging simulation model provided a good fit to actual prices over the entire period, then the change in market rules did not affect the underlying relationship between market conditions and prices.

The statistics on which the new dataset was based were collected by the Office of Gas and Electricity Markets (Ofgem) and National Grid Transco.

Details of the project and links to publications may be found on the ESRC award web page.

This dataset provides values for ELECTRICITY PRICE reported in several countries. The data includes current values, previous releases, historical highs and record lows, release frequency, reported unit and currency.

Spain Electricity decreased 24.92 EUR/MWh or 18.34% since the beginning of 2025, according to the latest spot benchmarks offered by sellers to buyers priced in megawatt hour (MWh). This dataset includes a chart with historical data for Spain Electricity Price.

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Electricity Trading Market Size 2025-2029

The electricity trading market size is forecast to increase by USD 123.5 billion at a CAGR of 6.5% between 2024 and 2029.

The market is witnessing significant growth due to several key trends. The integration of renewable energy sources, such as solar panels and wind turbines, into the grid is a major driver. Energy storage systems are increasingly being adopted to ensure a stable power supply from these intermittent sources. Concurrently, the adoption of energy storage systems addresses key challenges like intermittency, enabling better integration of renewable sources, and bolstering grid resilience. Self-generation of electricity by consumers through microgrids is also gaining popularity, allowing them to sell excess power back to the grid. The entry of new players and collaborations among existing ones are further fueling market growth. These trends reflect the shift towards clean energy and the need for a more decentralized and efficient electricity system.

What will be the Size of the Electricity Trading Market During the Forecast Period?

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The market, a critical component of the global energy industry, functions as a dynamic interplay between wholesale energy markets and traditional financial markets. As a commodity, electricity is bought and sold through various trading mechanisms, including equities, bonds, and real-time auctions. The market's size and direction are influenced by numerous factors, such as power station generation data, system operator demands, and consumer usage patterns. Participants in the market include power station owners, system operators, consumers, and ancillary service providers. Ancillary services, like frequency regulation and spinning reserves, help maintain grid stability. Market design and news reports shape the market's evolution, with initiatives like the European Green Paper and the Lisbon Strategy influencing the industry's direction towards increased sustainability and competition.
Short-term trading, through power purchase agreements and power distribution contracts, plays a significant role in the market's real-time dynamics. Power generation and power distribution are intricately linked, with the former influencing the availability and price of electricity, and the latter affecting demand patterns. Overall, the market is a complex, ever-evolving system that requires a deep understanding of both energy market fundamentals and financial market dynamics.

How is this Electricity Trading Industry segmented and which is the largest segment?

The industry research report provides comprehensive data (region-wise segment analysis), with forecasts and estimates in 'USD billion' for the period 2025-2029, as well as historical data from 2019-2023 for the following segments.

Type

  Day-ahead trading
  Intraday trading


Application

  Industrial
  Commercial
  Residential


Source

  Non-renewable energy
  Renewable energy


Geography

  Europe

    Germany
    UK
    France
    Italy
    Spain


  APAC

    China
    India
    Japan
    South Korea


  North America

    US


  South America



  Middle East and Africa

By Type Insights

The day-ahead trading segment is estimated to witness significant growth during the forecast period.

Day-ahead trading refers to the voluntary, financially binding forward electricity trading that occurs in exchanges such as the European Power Exchange (EPEX Spot) and Energy Exchange Austria (EXAA), as well as through bilateral contracts. This process involves sellers and buyers agreeing on the required volume of electricity for the next day, resulting in a schedule for everyday intervals. However, this schedule is subject to network security constraints and adjustments for real-time conditions and actual electricity supply and demand. Market operators, including ISOs and RTOs, oversee these markets and ensure grid reliability through balancing and ancillary services. Traders, including utilities, energy providers, and professional and institutional traders, participate in these markets to manage price risk, hedge against price volatility, and optimize profitability.

Key factors influencing electricity prices include weather conditions, fuel prices, availability, construction costs, and physical factors. Renewable energy sources, such as wind and solar power, also play a growing role in these markets, with the use of Renewable Energy Certificates and net metering providing consumer protection and incentives for homeowners and sustainable homes. Electricity trading encompasses power generators, power suppliers, consumers, and system operators, with contracts, generation data, and power station dispatch governed by market rules and regulations.

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The day-ahead tra

Bioenergy electricity generation has recorded mixed performance in recent years amid rising environmental opposition and a shifting policy landscape. Despite being classified as a renewable energy source, bioenergy has faced criticism for its carbon emissions, which often exceed those of fossil fuels. Strong government support and converting major coal-generating units to biomass plants fostered strong growth before 2018. However, new bioenergy projects have since struggled to gain traction, hampered by intensified opposition from environmentalists and a pivot in renewables strategies towards offshore wind. Revenue is forecast to dip at a compound annual rate of 0.6% to £2.5 billion over the five years through 2024-25. Growth in bioenergy electricity generation volumes started slowing down in 2020-21 before declining over the two years through 2023-24. Revenue has followed a slightly different trajectory, with soaring wholesale electricity prices contributing to a surge in revenue among bioenergy electricity generators that aren’t subject to fixed prices. Contracts for Difference (CfD)-backed biomass plants struggled during this period, with the generation of electricity sold at fixed rendered temporarily uneconomical when feedstock prices peaked. Revenue is set to grow by 12.1% in 2024-25, aided by a new 299-megawatt biomass plant in Teesside, which began generating electricity under a CfD in September 2023. Revenue is slated to climb at a compound annual rate of 3.2% over the five years through 2029-30, reaching £2.9 billion. The integration of Carbon Capture and Storage (CCS) technology will be vital to addressing environmental criticisms and securing bioenergy's role in the UK's renewable energy mix. The government’s plan to create a competitive market for CCS by 2035 signals a supportive stance, evidenced by recent approvals for Drax to convert biomass units to Bioenergy with Carbon Capture and Storage (BECCS). However, the exact nature of future subsidies remains uncertain.