Tag: Electric Insights

The general election on 4 July brought in a new government, and with it changes across all areas of policy. Energy and climate change featured prominently in the Labour manifesto, with “making Britain a clean energy superpower” one of their five core missions. This includes committing more money to renewables, planning reforms to get infrastructure built faster, and creating a new state-run energy company. This issue of Electric Insights explores what these changes mean for Britain’s electricity sector.

Share of Britain’s electricity generation during each quarter since 2020.

The Government’s boost to renewables comes just as they hit a major milestone. Since April, wind has been the country’s largest source of electricity on an annual basis, overtaking gas. This means 2024 is likely to be the first ever year when a fossil fuel was not the largest source of power, and would make Britain only the sixth country in the world to be primarily powered by wind.

The energy price crisis has faded from the news headlines, but its effects are still being felt throughout the economy. Some aspects are beginning to improve though: household energy bills fell by 25% over the last year (meaning negative inflation). However, Ofgem’s price cap is set to increase 10% in October, and longer-term effects on commodity prices and interest rate rises mean that renewable energy could remain more expensive for years to come.

One way that electricity prices have come down is that Britain’s 9 GW of interconnectors are now importing cheaper power from abroad, whereas last year we were exporting to help France overcome capacity shortages. Over the last quarter, Britain imported a record 20% of its electricity demand, coming close to overtaking gas in the generation mix.

Gas-fired power generation fell sharply to its lowest level in over 15 years. Just 13 TWh of electricity came from gas over the quarter, 25% less than the previous minimum on record. Britain’s solar PV panels produced more than 10 GW for the first time ever, and fossil fuels fell to a record low of supplying less than 1 GW for the first time ever. These changes signal that National Grid is getting closer to its 2025 ambition of being capable of running with zero carbon emissions.

Altogether, the increase in renewables, clean imports and nuclear meant that the electricity produced last quarter was cleaner than ever. Carbon emissions reached averaged below 90 g/kWh in April – a sign of positive things to come.

The last two years of Conservative governance saw a change in focus for UK energy policy, with boosted targets for renewables followed by rollbacks on key net-zero policies. The new Labour Government’s manifesto set out an ambitious plan to put energy security and climate change at the top of the political agenda. It promised to decarbonise electricity by 2030, gain energy independence from foreign powers, and setup a state-owned company: Great British Energy. After their first months in power, we reflect on what these promises and recent announcements mean for the electricity sector.

Increased funding for renewables

While we know the date of their clean power target, Labour are yet to release estimates of the investment required to meet their goal of decarbonising electricity by 2030. It is likely to be a substantial sum, as the previous Conservative Government had estimated that achieving a clean power grid by 2035 would require £275–375 billion of public and private investment, alongside a further £50–150 billion for electricity networks. Investment in wind and solar power are a key component of these overall costs.

Contract for Differences (CFD) auctions have been the main way to procure renewables since 2014, but the last auction in March 2023 failed to attract any investment in offshore wind, as costs had increased. The previous government had already allocated a record £1 billion to the scheme this year, but the new government has now raised this budget a further 50% – amounting to £23 per person. To get back on track to delivering 50 GW of offshore wind by 2030, the next two CFD auction rounds need to procure 10 GW each. The previous AR6 budget was sufficient to procure just 3–5 GW, and while Labour have increased that budget, it is still only consistent with procuring 4–7 GW.

The budget allocated to CFD auction rounds from AR1 in 2014 to AR6 in 2024. Emerging technologies include floating offshore wind, tidal power and geothermal.

Revised planning rules

Moving the target for zero-carbon electricity from 2035 to 2030 is ambitious. In just over five years we must replace the one-third of electricity still supplied by fossil fuels. The pathway for achieving this is reasonably clear though: the Climate Change Committee provide roadmaps with rapid growth of wind and solar power, backed up by energy storage and clean flexible generation: gas with CCS, biomass and hydrogen. The question is less what to do, and more how to deliver. Enacting these changes quickly requires massive financing, overcoming technical changes in managing the power system, and above all an overhaul of planning regulations which have stifled renewables for years.

Planning reforms have been at the forefront of recent government announcements. At the end of July, the government laid out their proposed reforms to the National Planning Policy Framework (NPPF) and the 2008 Planning Act. Just four days after the general election, the government lifted the de-facto ban of onshore wind. The NPPF applied community ‘tests’ which were so restrictive that in 2023, not a single planning application for an onshore wind farm was submitted in England.

The government are also preparing to ease the procedural constraints for large solar and wind projects. The 2008 Planning Act prevents local councils from approving Nationally Significant Infrastructure Projects (NSIPs) over 50 MW, leading to a backlog of a dozen large-scale wind and solar projects that only the Secretary of State has the power to approve. Many solar farms therefore limit their capacity to 49.9 MW to avoid the cost and delays of planning regulations (e.g. Larks Green and Nuneham). Eight days after the general election, Ed Miliband sent a clear signal to developers of the change in heart, giving consent to 1.35 GW of new solar farms in Lincolnshire and Cambridgeshire, enough to power 400,000 homes. As part of their planning consultation, the government proposed that local authorities should be allowed the final say over larger onshore wind and solar farms, up to 100 and 150 MW respectively.

A focus on energy security

Since Russia’s invasion of Ukraine and the subsequent gas market crisis, the subject of energy independence has become increasingly important to British policymakers. The UK relies on foreign imports for much of its supply of fossil fuels. We import nearly half of the oil and gas we use, and almost all of the coal [1]. We also import one-sixth of our electricity [1], and building more interconnectors between Britain and the continent is part of the plan for handling more wind and solar power.

Share of imports for the UK’s main energy sources in 2023. Circles are sized by annual energy consumed.

The government’s Energy Independence Act pledges independence from foreign energy imports, but it does not yet specify whether this extends to electricity. A power system that trades extensively with its neighbours for stability and to lower costs could reasonably be considered ‘independent’ if the two-way trade is on a roughly equal footing. If four times more electricity is imported than exported (currently the case for Britain) then perhaps it would not.

Reducing imports will require new generating capacity, so a strong commitment to new renewables projects in the next CFD Auction will help. However, Britain also needs more capacity that can generate at times when the wind is not blowing nor the sun shining, so more energy storage plus flexible and controllable power generation is needed to reduce imports.

A new mode of delivery

On the 25 July, Great British Energy was founded, backed by £8.3 billion of new money over this Parliament. It will own, manage, and operate clean power projects, focusing on technologies where markets are less mature to crowd-in private investment. It is hoped this will enable faster buildout, support new technologies such as floating wind, hydrogen, and carbon capture, and invest in clean energy supply chains. Partnering with the Crown Estate, they plan to deliver up to 20–30 GW of extra offshore wind seabed leases by 2030, ensuring that the next round of leases has lower risk for developers.

Great British Energy will also explore opportunities to support energy projects in their early development stages (e.g., by securing planning consent or a grid connection) to accelerate delivery and its Local Power Plan aims to develop up to 8 GW of small- and medium-scale cleaner power, part-owned by local communities. The next few months will see its headquarters established, staff recruited, and stakeholder engagement begin, putting Great British Energy on a delivery footing.

While the dust may have only just settled on the results of the general election, the new government’s earliest commitments signal a clear intent to put clean energy at the heart of policy moving forward.

[1] These statistics are net imports (gross imports minus gross exports).

After a century of either coal or gas being our main source of electricity, wind power is now Britain’s single largest source of electricity generation. Over the 12 months to April, Britain’s wind farms produced 83 TWh of electricity, compared to 81 TWh from gas-fired power stations. Wind produced 32% of the country’s demand, versus 31% from natural gas. It’s important this is measured year-round, as this accounts properly for the intermittency of wind, which ‘doesn’t always blow’.

The annual electricity generated from wind and natural gas in Britain since 2010.

Wind has been the largest source for short periods of time, first producing more than any other source for a single hour back in November 2013. February 2020 was the first full month when wind output beat gas or coal. Taking the top spot for a full year signals a genuine shift in our primary source of electricity. This was down to both wind output growing and reliance on gas falling. Compared to 12 months ago, wind output increased 6% and gas output fell 25%.

The large fall in gas output is due to more electricity being imported from abroad, with imports resuming from France after their nuclear outages last year, plus increases from Norway and the new Viking link to Denmark. Wind output increased both because of stronger wind speeds, particularly during the storms of December 2023 and January 2024, and new capacity coming online. The 1 GW Seagreen wind farm off the coast of Scotland came fully online, and Dogger Bank A in the North Sea started generating its first power.

As of last year, there were ten countries in the world with either wind or solar power as their largest source of electricity. For solar power, these are all among the least developed countries in the Middle East and North Africa. For wind power, they are all coastal European countries. Britain is set to continue this trend at the end of the year, becoming only the sixth country in the world where wind farms are the top source of electricity.

The countries where wind or solar PV are the largest sources of electricity, and their first year of achieving this. Only countries with population above 1 million are shown.

Everything is expensive these days. The UK has gone through a period of high inflation, in part driven by the energy crisis. Food bills, rents and mortgages have all gone up, but for different reasons. Similarly, there have been various pressures on electricity prices, some of which are short-term and are already going into reverse, while others are deeper-rooted and could take years to revert, if at all.

In the short-term, electricity prices rose because of the cost of fossil fuels. Gas prices increased six-fold during 2021 as the world emerged from COVID and Moscow started restricting gas supplies to Europe. Then Russia’s war in Ukraine sent markets into turmoil during 2022.

But over the last year, gas prices have fallen back towards normal levels as demand fell and supplies of LNG (liquid natural gas) from America and the Middle East filled the void. Household bills lag behind wholesale prices, not rising sharply until the end of 2022, but then staying high until the second half of 2023. This is because Ofgem sets its price cap based on the previous 6 months of wholesale prices, and so market shifts take time to reflect onto bills.

The average household bill has fallen by 24% over the last twelve months, from £2,074 to £1,568 per year; however, bills are set to rise again in October to £1,717, eating away at those savings.

Energy prices in the UK since 2020. Prices paid by household consumers (shaded pink) have fallen by 24% over the past year, as electricity and gas wholesale prices (lines showing 1-week average) fell during 2023.

In the medium-term, high energy prices feed into the cost of other goods and services. The cost of commodities, everything from timber to tomatoes, rose sharply during the 2020s, with the CPI inflation rate peaking at 9.6% in October 2022. The average plate of fish and chips hit £9 nationwide, in part because of the cost of energy to run the fryers. The same factors affect the cost of building new power stations – especially seen with wind farms as the cost of concrete, steel and other energy intensive materials hit record prices. The capital cost of wind turbines, solar panels and batteries all increased during 2022, and are only just starting to fall.

In the long-term, it is not so much capital cost, but the cost of capital that will push up the price of renewable energy. When buying a house or a car on finance, the borrowing rate drives the monthly repayments. In just the same way, the cost of financing wind or solar farms is the most influential driver on their cost of electricity – as they need no fuel to operate, and maintenance costs are small relative to upfront costs. The Bank of England increased interest rates 14 times between 2021 and 2023 in an effort to quell inflation, ending the decade of ultra-cheap borrowing after the 2009 global financial crisis. This increase in borrowing cost contributed to last year’s CFD auction delivering no offshore wind capacity and recent wind farms projects being cancelled, as developers can no longer deliver projects for under £50/MWh.

The indicative average capital cost of onshore and offshore wind farms in the UK, based on IRENA and ONS data, and the Bank of England base rate as a measure of the cost of borrowing.

These are not UK-specific issues, inflationary pressures and high interest rates have contributed to rising electricity costs around the world. UK interest rates have started to fall as inflation moves back towards the 2% target. However, the 0.25% cut made in August is a drop in the ocean, and interest rates now stand at the range they were for much of the 1990s and 2000s. The average cost of electricity generation from wind (known as the ‘levelised cost’) has risen by 60% in the last three years due to movements in interest rates, exchange rates and turbine capital costs. In response, the administrative strike price for offshore wind in the latest round of CfD auctions has been raised sharply from £44/MWh to £73/MWh, accompanied by a record budget to ensure that it can attract viable bids.

So, although consumer bills are now catching up with falling wholesale prices, further decreases in energy bills may take longer to materialise.

Electricity imports have reached record levels, with 19.8% of demand met by overseas sources over the three months to June. For the first time ever, more than a tenth of electricity came from France alone, and the cost of imported electricity rose to over £250 million per month. Overall, Britain imported 12.2 TWh last quarter, more than the country’s nuclear output (10.7 TWh), and close to total production from fossil fuels (13.6 TWh). In comparison, exports were just 3 TWh.

Gross electricity imports and exports as a share of British electricity demand each quarter.

For decades, Britain has imported more electricity than it exported, as neighbouring France has plentiful cheap nuclear power. In recent years, the stronger carbon price in the UK (specifically an £18 per tonne surcharge paid by power stations) made it more expensive to generate fossil-fuelled power here. However, the UK left the European carbon market after Brexit and launched its own. While the £18/t surcharge is still in place, Britain’s market now trades at around £20/t lower than Europe’s, bringing the cost of generating electricity from fossil fuels into line with the continent.

Much of Britain’s conventional generation has retired in the last decade, with 18 GW of coal, 4 GW of nuclear, and 3 GW of gas power shutting down. Fewer generators means higher prices as there is less competition between suppliers, but capacity changes on the continent are also influencing electricity trade. Much of Europe now has excess power generation, as countries have rapidly expanded their solar PV capacity to reduce reliance on Russian gas. Germany and the Netherlands installed 28 and 14 GW over the last three years (compared to just 2 GW in Britain), so spring and summer are now characterised by negative prices across the continent, which Britain can import at low cost.

On the one hand, Britain’s growing dependence on its neighbours for electricity goes against the government’s push for energy independence. On the other hand, interconnectors help to balance out the variability of wind and solar power, and support the aim to rapidly decarbonise electricity. There is a key distinction to make between importing because we are unable to supply our own needs versus importing to lower the cost of electricity. We are doing the latter – so developing further interconnector capacity is not a vulnerability, it is a strength. It will be a vital part of making Britain a “clean energy superpower” as the government intends. Reaching their 2030 targets of 80 GW of wind and 50 GW of solar will leave the UK with more annual generation than demand, and having the infrastructure in place to export excess production benefits everyone.

Gas power saw a shock slump in output, down 40% between the first and second quarters of this year. Gas produced just 13.3 TWh, which was not only the lowest quarterly output since records began in 2009, but also 25% lower than the previous minimum.

Wind power was the largest source of electricity for the third quarter running, producing more than all fossil fuels combined. Output from biomass, nuclear and solar all increased from the same period last year, as economic conditions improved, technical problems were resolved, and capacity grew, respectively. Biomass almost doubled its output from lows last year and nuclear power produced more than 10 TWh over a quarter for the first time since 2022.

Gas and fossil fuel electricity generation since 2010.

Britain’s electricity supply mix in the second quarter of 2024.

Installed capacity and electricity produced by each technology. [2] [3]

[2] Other sources give different values because of the types of plant they consider. For example, BEIS Energy Trends records an additional 0.7 GW of hydro, 0.6 GW of biomass and 3 GW of waste-to-energy plants. These plants and their output are not visible to the electricity transmission system and so cannot be reported on here.

[3] We include an estimate of the installed capacity of smaller storage devices which are not monitored by the electricity market operator.

Britain’s solar panels surpassed 10 GW of output for the first time. On 2 June, output hit 10.7 GW, boosted by June being relatively cool but with higher than average sunshine hours. The combined output of fossil fuels fell to a record low of 0.89 GW on 5 April, the first time they have produced less than 1 GW in a century. Fossil fuels produced less than one-fifth of electricity during April. Putting these together, the carbon intensity of electricity fell to a record low of 103 g/kWh averaged over the second quarter, going under 90 g/kWh in April. The share of all low carbon reached a new peak of 97%, with generation of 39 GW, up from the previous record of 35 GW.

The tables below look over the past fifteen years, back to 2009, and report the record output and share of electricity generation, plus sustained averages over a day, a month and a calendar year. Cells highlighted in blue are records that were broken in the second quarter of 2024. Each number links to the date it occurred on the Electric Insights website, so these records can be explored visually.

[4] Note that Britain has no inter-seasonal electricity storage, so we only report on half-hourly and daily records. Elexon and National Grid only report the output of large pumped hydro storage plants. The operation of battery, flywheel and other storage sites is not publicly available.

The UK is halfway to reaching Net Zero, having cut its greenhouse gas emissions by 50% since 1990. The Government proudly announced that the UK is the first major country to achieve this, but how far ahead are we, and what about the ‘hidden’ emissions that are released abroad for things we import and consume? Our first article this quarter gives a deep dive on the UK’s emissions reductions and introduces a new global decarbonisation league table.

Much of the success in reducing emissions has come from the electricity sector, which continued its progress by breaking new records for lowest carbon emissions and share of fossil fuels. Our second article looks at the falling carbon intensity of electricity as we move closer to operating a zero-carbon grid.

Wholesale electricity prices continued falling back to normal levels, averaging £65/MWh over 2024 so far. This is now just a touch above the average price during the 2010s when accounting for general inflation (£58/MWh in 2023 money). While energy costs are falling, capacity costs have risen to their highest ever. The latest Capacity Market auction, which decides the fixed payments that generators receive for being able to deliver power at peak times, cleared at £65per kW. With 43 GW of capacity contracted, the total payments due to be made in 2027/28 will amount to almost £3 billion (or £40 per person). This indicates that Britain’s power market is becoming tight and provides an incentive for old stations to remain online, and new ones to be built.

Monthly-average wholesale power prices in the day-ahead market, adjusted for inflation and in nominal terms.

Our third and fourth articles look at two new technologies which could form part of Britain’s future energy landscape. The Government announced over £20m of funding for clean hydrogen as part of its Net Zero Hydrogen Fund. Our third article looks at the seven large-scale projects this fund will enable, and the role hydrogen could play. Finally, the £2m Renewables for Subsea Power (RSP) has achieved success after 12 months of testing off Orkney. This project combines wave energy generators with under-sea energy storage to power marine equipment, and is a stepping stone towards harnessing power from the oceans to complement other renewables.

In February, the Government announced the UK was the first major economy to halve greenhouse gas emissions. Between 1990 and 2023, emissions fell by 50% while the economy grew by almost 80%. This marks a key success: we are roughly half-way through the period from 1990 to 2050 by which the UK must hit Net Zero, and we are roughly half-way there. This follows on from the UK’s electricity system more than halving its carbon intensity during the 2010s.

How have we reduced emissions?

Emissions have fallen across all sectors, but electricity leads the way with a 78% reduction between 1990 and 2023. It went from being the largest source of emissions as recently as 2014 to contributing less to climate change than agriculture. Power sector emissions fell rapidly due to coal phase out in the 1990s and 2010s, and the rise of renewables. Industry’s emissions have also fallen strongly with the shift away from energy-intensive manufacturing, although this coincides with the workforce halving from around 5 million in 1990. “Other” sources of emissions have also fallen rapidly, as methane from natural gas fields and landfill sites is better handled.

The UK’s two largest sources of emissions are now heating its buildings and fuelling its vehicles, and both are proving much slower to decarbonise. Clean electricity is now making headway in both sectors though, as sales of electric heat pumps and electric vehicles continue to grow.

The UK’s greenhouse gas emissions have fallen across all sectors, although at very different paces.

How does the UK compare internationally?

Based on these successes, the Government’s claim was that the UK has reduced emissions faster than any major economy. They used 1990 as the comparison year as this is when the Kyoto Protocol – the world’s first treaty on climate change – came into force. This is an arbitrary date though, and one that is convenient for the UK as it coincides with a large shift away from coal.

The global decarbonisation league table instead compares each country’s emissions in 2022 (the most recent year for global data) against their maximum historical emissions, reflecting the fact that countries have peaked (and will continue to do so) at different times. This is fairer. For example, the Government notes that US emissions have not fallen since 1990, but this neglects the fact that after rising to a peak in 2005, US emissions have fallen rapidly, by 18% in the last 17 years.

On this fairer comparison, the UK still ranks first among the world’s largest nations, with emissions having fallen 52% from their peak. European nations fill the top seven spots, with France and Germany coming 2nd and 3rd to the UK.

Japan and the US are on their way, having reduced their emissions by almost a fifth, and many countries across Asia, South America and Africa are also beginning to decarbonise. However, the world’s largest countries – China and India – still have rising emissions as their economies continue to grow rapidly while powered predominantly on fossil fuels. China’s emissions could begin falling this year due to rapid uptake of renewables and electric vehicles, which would mark a major milestone in the race against climate change.

While the UK takes top spot in the league table of major economies, it is not unique in having halved its emissions. Some smaller countries have decarbonised faster, although not for the best of reasons. Ukraine’s emissions have fallen by 81%, in part because their population has fallen by 7 million, and more recently because of Russia’s war. North Korea and Venezuela have also decarbonised further than the UK (by 76% and 61% respectively), but both because of faltering economies. Denmark is the only prosperous country to have gone further, also decarbonising by 61%, but it is only one-tenth the size of the UK.

The decarbonisation league table: Reduction in national carbon emissions from all-time peak, across the thirty largest countries which each emit over 200 MtCO2 per year. Calculated using data from the Global Carbon Budget.

But what about the emissions we import?

It is a common counter-argument: yes we have reduced emissions within the UK but only by shifting them abroad to manufacture all the goods that we import. This is true, to an extent. The UK’s “consumption-based emissions” focus on what we consume here, regardless of where it was made. These imports add around 40–45% to the UK’s emissions, raising them from 4.6 to around 6.6 tonnes of CO2 per person in 2023. Our imports also knock us off the top spot for decarbonisation: the UK’s consumption-based emissions have fallen by 32% since 1990 (when records began), compared to 35% in Russia and 36% in Spain. However, this still means the UK ranks 3rd out of the thirty largest countries.

The UK now emits just 0.9% of global CO2, so it is essential that all countries, especially the largest ones, rapidly reduce their emissions. That said, our leading role in the industrial revolution means the UK’s share of cumulative emissions since 1850 is five times higher, and this is the measure which matters for global temperatures and extreme weather. It is therefore fitting that the UK is again leading the world in reducing emissions, showing that economic growth can go hand in hand with reducing environmental impacts.

The UK’s carbon emissions since Victorian times, alongside the emissions estimated for what we consume, regardless of origin. Data from the Global Carbon Budget.

Electricity has played a major role in the UK’s national decarbonisation, and the power sector is continuing on its path towards zero emissions. Last year’s generation mix was the cleanest on record, and 2024 continued this trend with emissions staying below 150 g/kWh for the third quarter running.

National Grid reported a new record low for carbon intensity on 5 April of just 21 g/kWh [1]. Just 10 days later this record was broken again, reaching 19 g/kWh on 15 April. The latter was recorded on a sunny Tuesday afternoon. Demand was near its highest for the day, at over 39 GW, but wind and solar generation combined were able to meet 70% of this. Nuclear power contributed another 13%, and 10% of demand was imported (counted as zero-carbon when calculating British emissions). Biomass supplied about 3% and hydro another 1%, leaving only 3% of demand to be met by gas and coal.

Wind, solar and imports accounted for four-fifths of demand, which appears to be the current limit for these “nonsynchronous” electricity sources. Power stations which use turbine generators (fossil, biomass, hydro or nuclear) are synchronised to the grid, rotating at exactly the same speed: the system frequency. Maintaining that frequency depends on the power flowing into the grid being perfectly balanced with the demand drawn from it. The sudden failure of a generator can lead to a sharp drop in frequency, which could lead to widespread blackouts if not corrected for. Turbines store some energy in the form of “inertia” due to their heavy rotating mass, and this reduces the rate at which the frequency is falling, giving more time for other corrective actions.

Non-synchronous sources of electricity (wind, solar, interconnectors) are instead connected via power electronics and do not naturally provide inertia, which leaves the system more vulnerable. System operators therefore limit the amount of non-synchronous energy they will accept at any given time to keep a minimum level of inertia, even if this means constraining off wind power. Moving forwards, fastacting batteries can reduce the need for inertia, and system operators have been developing other techniques for running a low-inertia power system. Over the last few years, Eirgrid has steadily increased the maximum proportion of wind power it is prepared to admit onto the Irish power system.

The falling share of synchronous generation in the British electricity mix since 2010.

This is not just an issue at the extremes when carbon records are being broken. Over the last year, Britain has been seen twice as many hours when electricity falls below 50 g/kWh, at which point synchronous generation is typically below 30%.

Looking at the biggest countries in Europe, Britain’s emissions from the power sector are comparable to those in Spain. Both countries see a wide range in carbon intensities: power is clean when the weather allows for it, and is higher carbon otherwise. Germany and Italy have notably higher carbon intensities, never going below even 100 g/kWh. Despite having high shares of renewables, they are still heavily reliant on coal. Conversely, France almost always benefits from very low carbon electricity due to the high share of nuclear power.

Across the Atlantic, all of the USA’s largest markets have dirtier electricity than Great Briain, as they are both behind on renewables share and behind on coal phase out.

The growing frequency of “very low carbon” generation (under 50 g/kWh) is part of a shift that has been progressing for the last decade – the near-total phase out of coal power and continuing growth in renewable generation. Electricity in Germany or Texas has a similar mix of carbon intensities that Britain had 8 years ago, back in 2016. Poland and the US Midwest are closer to Britain a decade ago. The cleanest electricity in the US is in California, but this is not yet seeing hours with under 50 g/kWh, roughly where Britain was two years ago.

Technical constraints on balancing the grid mean there is a limit on how low carbon our electricity can go. National Grid are working to overcome these barriers, and by next year they aim to be capable of running the power system for hours at a time with zero carbon emissions, meaning that it can remain stable with just the synchronous generation from nuclear, biomass and hydro. This will require many changes: more flexibility (storage, interconnection, and demand side response), and innovation both in system management and market designs.

Left: The range of carbon intensity across all hours of 2023 in Britain, compared to the five largest electricity markets in Europe and the United States.
Right: The distribution of carbon intensity of electricity in Britain since 2010, split between winter and summer months.

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[1] Note, we report this as 28 g/kWh when accounting for the emissions from generating the electricity we import.