UK Energy Industry:
A Financial & Policy Analysis

Section 01 — Energy Security

Importing vs. Homegrown Energy: A Deepening Dependency

The United Kingdom was once a global energy powerhouse. North Sea oil and gas fields made Britain a net energy exporter through the 1980s and 1990s. That era is over. As domestic fossil fuel production collapses from its 1999 peak, the UK increasingly relies on foreign energy — at significant cost to both the public finances and national security.

In 2024, the UK's net import dependency stood at 43.8% — meaning more than four-in-ten units of energy consumed in the UK originated overseas. This is up from around 35% in 2020, reflecting the accelerating decline of North Sea production. Oil and gas output from the UK Continental Shelf is now 75% below its 1999 peak, and the North Sea Transition Authority projects offshore production will fall by a further third by 2028.

The composition of UK imports is shifting. Gas imports fell 8.4% in 2024 to their lowest level since 2008 — but crude oil imports rose 7.6%, reaching their highest level since 2014. The UK now imports from a more diverse network of partners following the imposition of sanctions on Russian energy after the 2022 invasion of Ukraine, though this diversification comes at a cost premium.

The irony is acute: Britain has some of the best wind resources in the world — enough, in principle, to power the entire country and export surplus. Yet it remains structurally dependent on imports. Wind farms are routinely paid to curtail output because the grid cannot transmit power from where it is generated (mainly Scotland) to where it is needed (mainly England). Meanwhile, gas plants and interconnectors fill the gap — at higher cost.

Section 02 — The Energy Transition

Clean Energy vs. Fossil Fuels: A Decade of Transformation

The UK's electricity system has undergone a remarkable structural shift since 2014. Fossil fuels have more than halved their share. Renewables have more than doubled theirs. In 2024, for the first time in the UK's history, renewables generated more electricity than fossil fuels across a full calendar year. And in September 2024, the last coal-fired power station closed — making the UK the first G7 nation to fully phase out coal power.

The shift has been driven primarily by offshore wind — the UK is the world's second-largest market for offshore wind after China — plus onshore wind, solar, and the policy framework of Contracts for Difference (CfDs) which gave developers long-term revenue certainty. Wind alone supplied 29.2% of UK electricity in 2024 (83.3 TWh), a new record, narrowly behind gas (30.4%) as the single largest source. In 2025, renewables reached 52.5% of electricity generation — the second consecutive year above 50%.

The carbon intensity of UK electricity has fallen by 70% in a single decade — from 419 gCO₂/kWh in 2014 to just 124 gCO₂/kWh in 2024. Total emissions from the electricity sector have dropped from 150 Mt CO₂ in 2014 to under 40 Mt CO₂ in 2024. This is one of the fastest decarbonisations of a major economy's power sector on record.

Despite the clean electricity progress, it is vital to note that electricity accounts for only a fraction of the UK's total energy use. Electricity covers roughly 20% of final energy consumption. The remainder — used for heating (gas in 80% of UK homes), transport (largely petrol and diesel), and industry — remains heavily fossil-fuel-dependent. Total primary energy supply in 2022 was still 39% natural gas and 35% oil. The electricity transition is real and important, but the harder work of decarbonising heat and transport has barely begun.

The 2030 target. The current Labour government has committed to a "clean power" electricity system by 2030 — meaning renewables and other low-carbon sources covering the overwhelming majority of generation. The National Energy System Operator (NESO) has modelled the required build-out: approximately 50 GW of additional offshore wind, 45 GW of solar, expanded grid infrastructure, and 23 GW of battery storage. The planning and grid connection bottlenecks — not the technology or economics — are the primary risks to delivery. Electricity demand is also expected to rise 11% by 2030 and nearly double by 2050 as EVs and heat pumps electrify transport and heating.

Section 03 — Market Structure

Reforming the Wholesale–Retail Relationship

Here lies the UK's deepest energy paradox. The country generates over half its electricity from renewables — which cost nothing to fuel — yet its electricity bills are among the highest in Europe. The culprit is a wholesale market design that allows a single fuel — natural gas — to set the price of all electricity, 97% of the time.

Under the current system of marginal cost pricing, the wholesale electricity price is set by the most expensive generator needed at any given moment to meet demand. That generator is almost always a gas-fired power plant. This means that when wind and solar are generating abundantly — and cheaply — those generators still receive the high gas-linked price. The profits accrue to generators; the cost is passed to consumers.

The chart above illustrates the dramatic sensitivity of consumer bills to wholesale gas markets. When gas prices tripled following the Russian invasion of Ukraine in 2022, UK electricity bills did too — even for households served entirely by wind and nuclear power. Three years later, gas prices have moderated but bills have not returned to pre-crisis levels. The UK remains, as the IMF noted, the "worst hit" country in Western Europe by the energy price crisis.

The Reform Debate

Since 2022, the government has been conducting a formal review of electricity market arrangements — originally called REMA (Review of Electricity Market Arrangements), now superseded by "Reformed National Pricing" (RNP). The central question: how to delink consumer electricity prices from gas, while maintaining investment signals for new generation. The key proposals under consideration have included:

There is however a structural reason for optimism. As the CfD fleet grows — every new wind or solar farm built under a CfD contract is effectively removed from the marginal pricing mechanism — the grip of gas on wholesale prices will naturally weaken. UKERC projects that gas-linked revenues will fall from 90% of generation revenues in 2024 to around 60% by 2028. The reform debate is ultimately about how quickly to accelerate that transition, and how to shield consumers in the meantime.

The Retail Market: Competition Without Protection

Below the wholesale market sits a retail market of 21 active suppliers (as of March 2025). The market was deregulated in the 1990s on the premise that competition would discipline prices. In practice, the 2022 energy crisis exposed severe weaknesses: 29 retail suppliers collapsed between 2021 and 2022, leaving millions of customers transferred to suppliers of last resort and a £2.7bn mutualised cost shared across all bills.

Ofgem introduced the price cap in January 2019 to protect households from excessive tariffs. But the cap — which limits the unit rate and standing charge rather than the total bill — does not prevent prices rising when wholesale costs do. It is a ceiling on supplier margins, not on the cost of energy itself. The parliamentary Energy Security Committee concluded in 2025 that the retail market remains "not fit for purpose" for vulnerable consumers, and that the Warm Home Discount — unchanged in real terms since 2011 while bills have risen over £500 — must be reformed as a priority.