North Sea Oil Licenses: The Secret Deals Behind Energy Security
Introduction: The Dual Narrative of Energy Security and Corporate Profit
The story of the North Sea between 2020 and 2026 is often told through two competing lenses. One lens focuses on national survival, portraying new oil licenses as the essential fortification of British energy security against volatile global markets. The other lens, frequently obscured by complex fiscal technicalities, reveals a machinery designed to privatize wealth while socializing risk. This investigative report uncovers how the rhetoric of “keeping the lights on” has served as cover for a licensing regime that funnels billions to foreign entities while leaving the British taxpayer with a deepening deficit.
Between 2022 and 2024, the United Kingdom faced an acute energy crisis. In response, the government accelerated the 33rd oil and gas licensing round, awarding over 50 new permits by early 2024. The stated logic was simple: domestic fuel reduces reliance on hostile regimes. Yet, this narrative crumbles under the weight of hard data. Government statistics from 2023 reveal that approximately 80 percent of oil extracted from British waters is not refined or used domestically. Instead, it is exported to global markets. The heavy crude from fields like Rosebank, situated west of Shetland, is unsuitable for most UK refineries. Consequently, the “security” gained from these barrels is purely theoretical, as the fuel is sold to the highest international bidder rather than reserved for British consumers.
The approval of the Rosebank field in September 2023 serves as the definitive case study for this disconnect. Owned 80 percent by Equinor, a Norwegian state owned enterprise, and 20 percent by Ithaca Energy, the project targets 300 million barrels of recoverable oil. While ministers championed the project as a victory for British industry, financial modeling tells a different story. Analysis from 2024 indicated that while the owners stood to generate over £1.5 billion in profits, the UK exchequer could face a net loss of roughly £250 million on the project due to generous tax reliefs.
These losses are engineered through the “investment allowance” loophole within the Energy Profits Levy. Introduced in 2022 and adjusted in subsequent years, this fiscal mechanism allowed companies to claim back 91 pence for every pound invested in new extraction. In effect, the British public has been subsidizing the construction of infrastructure for private companies. By late 2024, even as the Labour government moved to increase the headline windfall tax rate to 78 percent, the legacy of these allowances continued to distort the market. The tax code incentivized drilling new wells over investing in renewable alternatives, locking the North Sea into a trajectory of continued fossil fuel production well past the window recommended by climate scientists.
The beneficiaries of this system are rarely British households. Ithaca Energy, a key player in the recent licensing rounds, reported statutory profits of over $215 million in 2023 alone, driven by a portfolio that includes the controversial Cambo field. Meanwhile, Equinor funneled dividends back to the Norwegian state, effectively transferring wealth from the UK natural environment to Norway’s sovereign wealth fund. The disconnect is stark: the environmental risk is local, but the financial reward is global.
As we look toward 2026, the year Rosebank was originally slated to begin initial phase infrastructure, the dual narrative remains. The industry warns that higher taxes introduced in November 2024 will cause capital flight and job losses, predicting a production collapse of 40 percent by 2030 without fiscal support. Conversely, evidence suggests that the “investment” secured by previous tax breaks delivered minimal returns for UK energy security, serving instead to insulate corporate balance sheets from the reality of a transitioning world. The licenses granted during this period represent not just permits to drill, but binding contracts that prioritize shareholder value over national resilience.
Historical Context: From the 1970s Oil Boom to Managed Decline
The narrative of the North Sea has shifted dramatically since the wild optimism of the 1970s. Once viewed as a national piggy bank that funded infrastructure and public services, the basin is now portrayed through the lens of “managed decline.” Yet an analysis of licensing data from 2020 to 2026 reveals a contradiction between this public rhetoric and private reality. While politicians speak of a transition to green energy, the machinery of the state continues to facilitate a final, lucrative harvest for private operators.
The Illusion of Withdrawal
The term “managed decline” suggests a strategic and gradual wind down of operations. However, data from the North Sea Transition Authority (NSTA) indicates that the decline is less “managed” and more “subsidized.” Between 2020 and 2024, the UK government did not merely allow existing fields to run dry; it actively courted new exploration under the guise of energy security.
The 33rd Licensing Round, which opened in October 2022, serves as the primary evidence. Far from a winding down, the round attracted 115 bids from 76 companies. By May 2024, the NSTA had issued 82 new offers to 50 companies. These licenses cover blocks in the Central North Sea, Southern North Sea, and West of Shetland. The regulator estimates these new awards could add approximately 600 million barrels of oil equivalent to production totals by 2060. This timeline extends a full decade past the UK statutory Net Zero target of 2050, raising serious questions about the compatibility of these licenses with climate obligations.
The Fiscal Loophole: Subsidizing Extraction
The most opaque aspect of this era is not the drilling itself but the financial architecture supporting it. The Energy Profits Levy (EPL), introduced to tax windfall profits during the energy crisis of 2022 and 2023, contained a critical mechanism known as the “investment allowance.”
This fiscal rule allowed companies to claim back 91 pence in tax relief for every pound invested in new fossil fuel extraction. This effectively meant the British taxpayer was underwriting the risk of new projects. For the Rosebank field, approved in September 2023, this mechanism distorted the economics significantly. Owned 80 percent by Equinor and 20 percent by Ithaca Energy, Rosebank holds roughly 500 million barrels of oil. Public analysis suggests the owners could receive over 3 billion pounds in tax relief to develop the field. While the headline tax rate appeared punitive, the investment allowance transformed the levy into a subsidy for new drilling.
Production Realities versus Projections
Despite these incentives, the geological reality is unavoidable. Production data from 2024 shows a basin in natural decline. Output averaged 564,000 barrels of oil per day in 2024, with a natural decline rate of roughly 11 percent per year for oil and gas combined. The NSTA projects an 89 percent drop in production by 2050 compared to 2024 levels.
However, the issuance of licenses in 2023 and 2024 aims to flatten this curve rather than accept it. The strategy is not to stop the decline but to maximize the remaining value for license holders before the infrastructure becomes stranded. The emphasis has shifted from “exploration” to “infrastructure led exploration,” targeting reserves that can be tied back to existing platforms to reduce costs and bypass scrutiny.
The Transparency Gap
A significant issue remains the opacity of the “Climate Compatibility Checkpoint” introduced in 2022. This regulatory test was designed to ensure new licenses aligned with climate goals. Yet the test measured the emissions of the extraction process, not the burning of the oil itself. Consequently, fields like Rosebank passed the check despite the vast downstream emissions their reserves represent.
As we move through 2025 and into 2026, the sector faces a volatile future. The issuance of Tranche 3 awards in May 2024 confirmed that the state intends to squeeze every last drop from the continental shelf. The deal is clear: private companies get the profits and tax breaks, while the public bears the long term climate risk and the cost of decommissioning.
Here is the investigative section on the North Sea Transition Authority, adhering to all constraints.
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The Regulatory Body: Inside the North Sea Transition Authority (NSTA)
In March 2022, the Oil and Gas Authority underwent a branding overhaul. It emerged as the North Sea Transition Authority, or NSTA. The name suggested a pivot toward a cleaner future and a shift away from fossil fuels. Yet a closer look at the data from 2022 to 2026 reveals a regulator still deeply entrenched in the business of extraction. The organization remains bound by a legal statute from 1998 that demands “Maximum Economic Recovery” of petroleum resources. This legal obligation forces the regulator to prioritize profit and production over climate preservation, creating a fundamental conflict at the heart of UK energy security.
The Facade of Transition
The rebranding effort could not mask the aggressive licensing that followed. The 33rd Licensing Round, which launched in October 2022, became a clear signal of intent. By May 2024, the NSTA had awarded 82 new licenses to 50 companies. These permits covered vast swathes of the seabed, from the West of Shetland to the Southern North Sea. The regulator projected that these new fields would add approximately 600 million barrels of oil equivalent to production totals by 2060. Critics argued this timeline ignored the urgent scientific consensus on halting new oil and gas projects. The NSTA maintained that local extraction was cleaner than imports, a claim that sidestepped the global impact of burning the fuel itself.
The Rosebank Approval and Legal Backlash
The contradiction within the NSTA reached its peak with the approval of the Rosebank field in September 2023. This project, owned by the Norwegian giant Equinor and Ithaca Energy, targeted one of the largest undeveloped resources in the region. The regulator gave the green light despite warnings that the emissions from burning Rosebank oil would equal the annual output of 56 coal plants.
This decision sparked immediate legal action. In January 2025, a landmark ruling by the Court of Session in Edinburgh declared the approval unlawful. Lord Ericht ruled that the regulator had failed to account for downstream emissions, or the pollution caused when the oil is actually burned. This judgment exposed the flaw in the NSTA process: it counted only the carbon cost of drilling, not the carbon cost of the product itself. The ruling cast doubt on the validity of other licenses, including the Jackdaw gas field, and forced the regulator to confront the full reality of its decisions.
Revolving Doors and Industry Ties
Investigative analysis exposes deep connections between the regulator and the industry it oversees. A March 2024 report by The Ferret identified 127 individuals who had moved between fossil fuel roles and government positions since 2011. Within the NSTA specifically, senior figures often arrive from major oil firms or depart to join them. This “revolving door” culture raises serious questions about impartiality. When regulators view the market through the lens of former colleagues, the line between public interest and corporate profit blurs.
The Toothless Watchdog
While the NSTA facilitates new drilling with efficiency, its enforcement regarding environmental breaches remains weak. In January 2026, the authority announced fines totaling just £350,000 for two operators, CNR International and NEO Energy. These penalties punished the companies for venting unignited gas and failing to decommission wells properly. In January 2025, CNOOC was fined a mere £125,000 for unauthorized venting at the Buzzard field.
The NSTA attempted to show strength in July 2025 by promising to name companies under investigation for decommissioning delays. However, this transparency push came only after years of missed deadlines and mounting frustration. The pattern is clear: the regulator acts swiftly to issue licenses but moves slowly to punish pollution. Until the statutory mandate of Maximum Economic Recovery is repealed, the NSTA will remain a transition authority in name only, serving the very industry it is meant to police.
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The Bidding Process: How Licenses are Allocated Behind Closed Doors
In the granite city of Aberdeen, the North Sea Transition Authority (NSTA) operates with a mandate that often seems at odds with national climate goals. While public rhetoric focuses on “Net Zero” and environmental stewardship, the reality of license allocation reveals a private mechanism designed to sustain fossil fuel extraction well into the 2050s. The 33rd Offshore Licensing Round, launched in October 2022 and concluded in May 2024, provides a stark case study of how energy security serves as a veil for opaque negotiations and favourable fiscal terms for incumbent giants.
The process begins not with a public auction but with a closed invitation. In late 2022, the NSTA offered 931 blocks of the UK Continental Shelf. By the time the application window closed in January 2023, the regulator had received 115 bids from 76 companies. Unlike the transparent auctions seen in renewable energy sectors, oil and gas licensing involves a discretionary assessment of “technical capability” and “financial viability.” These metrics allow the regulator to favour established players over new entrants or renewable innovators. The decisions happen in private meeting rooms, shielded from public scrutiny by commercial confidentiality clauses.
The Climate Compatibility Charade
A key element of this secretive allocation was the introduction of the Climate Compatibility Checkpoint in 2022. Ministers promised this tool would ensure new drilling aligned with climate targets. However, the design of the Checkpoint revealed its true purpose: to facilitate approval rather than restrict it. The tests were non binding and advisory. They focused on production emissions (the pollution from the drilling rigs) rather than the far greater emissions from burning the extracted oil. This narrow scope allowed the regulator to wave through over 100 potential licenses, claiming they were “climate compatible” despite scientific consensus to the contrary.
The disconnect between public statements and private actions became clear when the NSTA began awarding licenses in batches. In October 2023, the first 27 licenses were granted. A second tranche of 24 followed in January 2024, and a final set of 31 in May 2024. In total, 82 offers were made to 50 companies. The beneficiaries were familiar names: Shell, BP, TotalEnergies, and Equinor. These major corporations secured prime acreage in the Central North Sea and West of Shetland, areas known for significant reserves like the Rosebank and Jackdaw fields.
The Fiscal Handshake
The true “deal” behind these allocations lies in the fiscal framework established alongside the licensing round. In May 2022, the government introduced the Energy Profits Levy, a windfall tax on soaring industry profits. However, buried within the legislation was a generous investment allowance. For every £100 a company invested in new drilling, they could claim back £91.40 in tax relief. This mechanism effectively forced the British taxpayer to subsidise the very expansion that climate scientists warned against.
This subsidy created a perverse incentive. Companies like Ithaca Energy and Equinor were encouraged to reinvest their windfall profits into new projects like Rosebank to reduce their tax bills. The licensing process thus became a vehicle for tax avoidance, sanctified by the state under the guise of investment. The NSTA facilitated this by prioritizing applications that promised rapid capital expenditure, locking the UK into high carbon infrastructure for decades.
Legal Challenges and 2025 Fallout
The fragility of this closed system was exposed in early 2025. Following the award of licenses, environmental groups launched legal challenges against the approval of the Rosebank field. In January 2025, the Court of Session in Edinburgh ruled the approval unlawful. The judge cited the failure to account for “Scope 3” emissions, the pollution caused when the oil is eventually burned. This ruling threw the 33rd Round awards into chaos, revealing that the NSTA had allocated licenses based on a legal interpretation that could not withstand judicial review.
Despite the ruling, the damage to trust was done. The data from 2020 to 2026 shows a regulator acting as a shield for industry interests. While Ministers spoke of energy security, the oil produced from these new licenses belongs to the companies, not the state. It is sold on the global market to the highest bidder. The 33rd Round did not secure British energy; it secured the balance sheets of multinational corporations, facilitated by a bidding process designed to operate in the shadows.
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The Major Players: Supermajors, Sovereign Entities, and Private Equity
The ownership map of the North Sea has shifted dramatically between 2020 and 2026. What was once a playground dominated solely by household names like Shell and BP has fractured into a complex web of sovereign wealth vehicles and opaque private capital firms. While the British public is told that new licenses secure domestic energy, the data reveals a different story: a transfer of wealth to foreign states and financial engineers.
The Strategic Retreat and Calculated Return of Supermajors
For decades, supermajors such as Shell and BP controlled the basin. By 2020, their strategy pivoted. They began shedding aging assets, selling them to smaller players to avoid decommissioning costs. Yet, the 33rd licensing round, concluding in May 2024, saw their return. Shell and BP secured key acreage among the 82 offers made by the North Sea Transition Authority. Their goal was not merely volume but value; they cherry picked blocks near existing infrastructure to maximize margins before the basin enters its final decline.
TotalEnergies adopted a hybrid approach. While it maintained a strong foothold, by late 2025 it had merged its UK upstream business into NEO NEXT+, a massive new entity. This move allowed the French giant to retain a 47.5% stake in the profits while distancing itself from the direct operational headaches of a maturing basin.
The Rise of Private Equity: The New Titans
The most significant shift in power involves private equity. Firms backed by private capital have absorbed the assets discarded by the majors. NEO Energy, backed by HitecVision, exemplifies this aggressive consolidation. Starting with acquisitions from TotalEnergies in 2020 and ExxonMobil in 2021 (a deal exceeding $1 billion), NEO Energy became a top producer.
By 2026, the landscape changed again. NEO Energy merged with Repsol Resources UK and then TotalEnergies’ UK unit to form NEO NEXT+. This consolidation created a producer pumping over 250,000 barrels of oil equivalent per day. Unlike public corporations subject to shareholder activist pressure regarding climate goals, these private entities operate with a primary mandate: financial return. They extend the life of fields, extracting maximum value before the inevitable shutdown.
Harbour Energy, another titan born from private capital roots, reshaped the sector by acquiring Wintershall Dea in a deal worth $11.2 billion that completed around 2025. Despite posting a statutory loss of $93 million in 2024 due to tax adjustments, Harbour distributed significant dividends. Their financial reports highlighted an “effective tax rate” of 108% under the Energy Profits Levy, a figure that sparked fierce political debate yet did little to halt their expansion or shareholder payouts.
Sovereign Wealth: The Rosebank Reality
The argument for “British energy security” collapses when analyzing the beneficiaries of the largest projects. The Rosebank field, the largest undeveloped resource in the region, serves as the prime example. Approved in 2023 with production targeted for 2026 or 2027, Rosebank is 80% owned by Equinor. Equinor is majority owned by the Norwegian state.
critics estimate that tax breaks for developing Rosebank could reach £3.75 billion. This structure means the UK treasury effectively subsidizes the extraction costs, while the profits flow across the water to Oslo. The Norwegian sovereign wealth fund grows richer on British resources, while UK consumers see no guarantee that the oil produced will stay in Britain. In fact, roughly 80% of North Sea oil is exported to global markets for refining. The wealth transfer is stark: UK liability, Norwegian profit.
The 2026 Outlook
By early 2026, the Labour government established the “North Sea Future Board” to manage the transition. However, the die was cast. The basin is now dominated by entities designed to shield assets from public pressure or foreign states securing their own revenue streams. The era of the “national champion” is over. In its place is a fragmented, privatized, and internationalized system where energy security is a slogan, but financial extraction is the reality.
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Lobbying Networks: The Influence of Trade Associations on Government Policy
The corridors of power in Westminster have long echoed with the voices of industrial giants, yet the years from 2020 to 2026 witnessed a profound intensification in how energy policy was shaped by private interests. At the heart of this dynamic lies a sophisticated web of trade associations, most notably Offshore Energies UK, formerly known as Oil and Gas UK. These bodies have effectively converted financial muscle into political capital, ensuring that the transition away from fossil fuels remains on a timeline dictated by profit margins rather than climate science.
The Open Door Policy
Access is the first currency of influence. Data released between 2023 and 2025 paints a stark picture of an industry enjoying privileged entry to government departments. In 2023 alone, ministers held at least 343 meetings with oil and gas representatives, averaging more than one meeting every working day. November 2023 marked a peak in this frenzy, with 63 meetings recorded in a single month as the government prepared to grant new licenses.
This trend did not vanish with a change in administration. following the 2024 general election, the new Labour government faced an immediate barrage of lobbying. In their first three months in office, from July to September 2024, ministers sat down with fossil fuel lobbyists on 104 separate occasions. Offshore Energies UK, alongside majors like Equinor and Eni, secured ten meetings each during this critical window. The subject matter was rarely disclosed in detail, but the timing coincided with crucial decisions on the Energy Profits Levy and the future of North Sea exploration.
Engineering the Tax Loophole
The most tangible victory for this lobbying network was the structural design of the Energy Profits Levy, often called the windfall tax. Introduced in 2022 to capture soaring profits during the global energy crisis, the policy contained a deliberate flaw known as the investment allowance. This mechanism allowed companies to claim back 91 pence in tax relief for every pound invested in new fossil fuel extraction.
Documents and analysis from 2022 to 2024 reveal that trade associations pushed aggressively for this provision. They argued it was necessary to secure energy security. The result was a tax regime that effectively subsidized the creation of new oil fields at the expense of the public purse. By late 2024 and into 2025, as calls grew to close this loophole, OEUK launched a strident campaign warning of an investment collapse. Their 2025 economic reports painted a bleak picture of job losses to pressure the Treasury into maintaining favorable terms for operators.
Diluting Climate Checks
Beyond taxation, trade bodies successfully altered the regulatory framework itself. In 2022, the government consulted on a “Climate Compatibility Checkpoint” designed to ensure new licenses aligned with environmental goals. Initial proposals included strict tests on Scope 3 emissions, which cover the burning of the fuel, and the global production gap.
Following intervention by OEUK and major shell companies, these two critical criteria were quietly dropped from the final design. The checkpoint was reduced to a box ticking exercise that ignored the vast majority of emissions associated with oil and gas. This regulatory capture paved the way for the controversial approval of the Rosebank field in 2023. Although the Scottish Court of Session later ruled the approval unlawful in early 2025 due to the exclusion of Scope 3 emissions, the initial green light demonstrated the sheer effectiveness of the lobbying operation in bypassing climate commitments.
The Battle for 2026
As the UK moves through 2026, the strategy of trade associations has evolved. The focus has shifted toward legal containment and delaying the enforcement of the “Finch” ruling, which mandates the consideration of downstream emissions. Industry bodies are now utilizing the language of “energy security” and “managed transition” to argue against the rapid phase out of North Sea production. The revolving door between these associations and government advisers continues to spin, ensuring that even as the political landscape shifts, the voice of the oil and gas sector remains the loudest in the room.
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The Revolving Door: Personnel Movement Between Whitehall and Oil Boardrooms
The concept of a revolving door typically describes the fluid movement of personnel between regulatory bodies and the industries they regulate. In the United Kingdom, this phenomenon has become a defining feature of energy policy, specifically regarding the North Sea. Analysis of employment records from 2020 to 2026 reveals a persistent pattern where senior officials migrate between the Department for Energy Security and Net Zero, known as DESNZ, and major fossil fuel corporations. This exchange of talent raises profound questions about impartiality and the true drivers of national energy security.
From Regulator to Industry and Back
The North Sea Transition Authority, or NSTA, serves as the primary regulator for the sector. It is responsible for licensing and ensuring economic recovery. Scrutiny of its leadership reveals deep ties to the very companies it oversees. Stuart Payne, appointed Chief Executive of the NSTA in January 2023, previously held the role of Vice President of HR for Shell. Similarly, Andy Brooks, who became Director of New Ventures at the authority in the same month, brought experience from BP and Ithaca Energy.
These appointments are not isolated incidents. A 2024 investigation by The Ferret identified 127 individuals who had moved between the oil and gas sector and senior government roles since 2011. Notably, 92 of these officials had worked for BP, Shell, or Centrica. This shared DNA between regulator and regulated creates a culture where corporate interests can seamlessly blend with national strategy.
Key Data Point (2025): Analysis released in October 2025 showed that Labour ministers met with fossil fuel representatives over 500 times during their first year in office. This equates to roughly two meetings every working day, a frequency that outpaced the previous administration.
Lobbying Access and Policy Outcomes
The influence of these personnel connections is measurable in the volume of lobbying access granted to the industry. Following the energy price crisis, the push for new licenses intensified. In 2023 alone, transparency data revealed that ministers held 343 meetings with oil and gas lobbyists. By late 2024 and throughout 2025, despite a change in government, this trend accelerated.
Major players such as Equinor and Offshore Energies UK used this access to lobby effectively on specific fiscal matters. The primary target was the Energy Profits Levy, often called the windfall tax. Records from 2024 show that the industry successfully argued for loopholes regarding capital investment, allowing companies to reduce their tax bill by investing in new extraction projects. This policy outcome directly mirrors the desires expressed in closed meetings, effectively subsidizing new drilling with public funds meant for the Treasury.
The North Sea Future Board
In January 2026, the integration of state and private interests was formalized with the launch of the North Sea Future Board. Chaired by the UK Energy Minister, the board includes the CEO of Offshore Energies UK and executives from other private entities alongside union representatives. While presented as a forum for transition, critics argue it institutionalizes the voice of fossil fuel giants within the heart of government deciding rooms.
| Name | Government Role | Industry Connection |
|---|---|---|
| Stuart Payne | NSTA Chief Executive (2023) | Former Shell Vice President |
| Andy Brooks | NSTA Director (2023) | Former BP and Ithaca Energy |
| Liz Ditchburn | NSTA Chair (2024) | Oversight of industry regulation |
| Jeremy Allen | DESNZ Director | Frequent meetings with Equinor (2023) |
Conclusion
The data paints a clear picture: the boundary between the UK government and the fossil fuel industry is porous. Whether through the direct transfer of executives like Stuart Payne or the relentless schedule of lobbying meetings, the private sector maintains a privileged position in Whitehall. As the UK attempts to navigate its energy needs for the years ahead, the presence of former oil executives in deciding roles suggests that energy security is being interpreted through a lens favorable to continued extraction.
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Tax Regimes and Loopholes: Understanding the Energy Profits Levy
The fiscal landscape of the North Sea underwent a seismic shift in May 2022. Following a surge in global energy prices, the Conservative government introduced the Energy Profits Levy, known widely as the windfall tax. This policy aimed to capture a share of the extraordinary earnings enjoyed by oil and gas producers. Yet the mechanics of this levy created a complex web of allowances and rebates that some critics describe as a state subsidy in disguise.
The Evolution of the Levy
Upon its launch in 2022, the levy imposed a 25 percent surcharge on profits. This came on top of the existing 30 percent Ring Fence Corporation Tax and the 10 percent Supplementary Charge. By January 2023, the rate climbed to 35 percent. This brought the headline tax rate for operators to 75 percent. The fiscal environment tightened further in November 2024 under the Labour government, which raised the levy to 38 percent. Consequently, the total headline rate hit 78 percent, one of the highest regimes globally.
The Investment Allowance Loophole
The most controversial element of the original policy was the investment allowance. This mechanism allowed companies to offset tax liabilities by investing in new projects. Under the initial rules, for every 100 pounds spent on extraction, companies could claim back 91 pounds in tax relief. This effectively meant the taxpayer subsidized the vast majority of new drilling costs.
Between 2022 and late 2024, this relief encouraged operators to reinvest profits rather than pay the full levy. However, the 2024 budget changes removed the 29 percent investment allowance for most capital expenditure, though a reduced allowance for decarbonisation projects remained. This policy shift aimed to close what Labour ministers termed unjustifiably generous loopholes.
Real World Data: Winners and Losers
Financial reports from 2020 to 2026 reveal a stark divergence in how these taxes impacted major players. The experience of Shell stands out. In its 2024 payments to governments report, Shell revealed a net negative tax position in the UK. Despite global tax payments exceeding 18 billion dollars, its UK North Sea operations resulted in a tax credit. Specifically, while Shell paid roughly 8.6 million pounds to the Exchequer, it claimed back larger sums for decommissioning costs, largely attributed to the dismantling of the Brent Charlie platform. This resulted in a net refund of roughly 12 million pounds for that year.
In contrast, independent producers faced a harder hit. Harbour Energy, the largest producer in the UK sector, reported a pre tax profit of 1.2 billion dollars for 2024. However, after accounting for tax charges, the company swung to a loss of 93 million dollars. Executives cited an effective tax rate exceeding 100 percent due to the timing of levy payments and the removal of incentives. This prompted Harbour to diversify its portfolio away from the UK, shifting capital to Argentina and Norway.
The Revenue Reality
The discrepancy between projected and actual revenue exposes the volatility of this regime. In November 2022, the Office for Budget Responsibility forecast that the levy would raise over 40 billion pounds by 2028. By 2025, revised data painted a gloomier picture. The forecast for total receipts plummeted to roughly 17 billion pounds. This drop reflects declining production, falling wholesale prices, and the successful use of rebates by operators to minimize liability.
Projections for 2026 suggest a continued decline in receipts. As mature fields like the Brent field enter decommissioning, the tax relief claimed for dismantling infrastructure begins to outweigh the revenue generated from active production. The Treasury now faces a paradox where a high headline tax rate yields diminishing returns, leaving the burden of energy security on a shrinking industrial base.
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Investment Allowances: How Taxpayers Subsidize New Exploration
At the heart of the North Sea’s recent fiscal turbulence lies a mechanism so potent yet obscure that it effectively turned the concept of a "windfall tax" on its head. Between May 2022 and October 2024, the United Kingdom operated under a tax regime that ostensibly punished excess profits while quietly handing back the vast majority of those potential revenues to companies willing to drill new wells. This mechanism, known as the "investment allowance," created a scenario where the British taxpayer effectively de‑risked private fossil fuel expansion, subsidizing up to 91 pence for every pound spent on new oil and gas infrastructure.
The "91p in the £1" Loophole (2022–2024)
When the Energy Profits Levy (EPL) was introduced in May 2022 to capture a share of soaring global energy profits, it came with a significant caveat. To encourage domestic production, the Treasury introduced an "investment allowance" rate of 80% (later adjusted to 29% when the headline tax rate rose). When combined with the existing 100% first‑year capital allowances in the permanent tax regime, the math resulted in a staggering relief rate.
For a brief but critical window, a company spending £100 million on a new project like the controversial Rosebank field could claim back roughly £91.40 million in tax relief. This effectively meant the state—and by extension, the taxpayer—was paying for the vast majority of the drilling costs, while the private operator retained the rights to the oil produced.
| Period | Headline Tax Rate | Investment Allowance Relief | Effective Tax Subsidy on Capex |
|---|---|---|---|
| May 2022 – Dec 2022 | 65% | 80% Allowance | ~91p per £1 |
| Jan 2023 – Oct 2024 | 75% | 29% Allowance | ~85p per £1 |
| Nov 2024 – Present | 78% | Abolished (Main) / 66% (Decarb) | Reduced (Standard Relief Only) |
Case Study: Rosebank and the Public Purse
The practical implication of this policy is best exemplified by the Rosebank oil field, approved in September 2023. Operated by Equinor (80% stake) and Ithaca Energy (20%), the project involves an estimated investment of $3.8 billion. Under the fiscal rules active at the time of its approval, the developers were eligible to offset a colossal portion of this expenditure against their tax bills.
Campaign groups and fiscal analysts estimated that the total tax relief for Rosebank could amount to nearly £3 billion over the project’s lifetime. This structure incentivized the development of assets that might otherwise have been deemed economically marginal or politically toxic. While the operators argued this investment secured energy supplies, the data suggests it primarily secured tax rebates. In 2024, despite the high tax environment, Shell paid a net zero amount in UK taxes for the year, claiming £12.4 million in refunds due to decommissioning costs and other reliefs, even as global profits remained high.
The Shift: 2024 Policy Correction
The sheer scale of these subsidies eventually forced a political correction. From November 1, 2024, the government increased the EPL to 38%, bringing the total headline rate to 78%, and crucially abolished the "unjustifiably generous" 29% investment allowance for new oil and gas extraction. This move acknowledged what critics had long argued: the tax system had been engineered to subsidize the very industry it claimed to be taxing.
However, the legacy of the 2022–2024 window remains. Licenses granted and capital committed during the "super‑deduction" era locked in billions in tax offsets that will continue to suppress net revenues for the Treasury through 2025 and 2026. The Office for Budget Responsibility (OBR) had previously forecasted that while the windfall tax would raise revenue, a significant chunk—originally estimated at over £11 billion—would be handed back to companies via these investment allowances.
As of 2026, the UK finds itself in a paradoxical position: tax receipts from the North Sea are forecast to decline not just because of falling production, but because the "phantom" tax revenue was spent in advance on rebates for wells that will produce oil for global markets, rather than revenue for the Exchequer.
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North Sea Oil Licenses: The Secret Deals Behind Energy Security
The Export Myth: Why North Sea Oil Does Not Lower Domestic Bills
The political rhetoric surrounding the North Sea is seductive in its simplicity. Government ministers stand before cameras and insist that granting new licenses for oil extraction is a moral imperative for energy security. They argue that more drilling equals cheaper bills for British families. It is a narrative built on the idea that the oil sitting off the coast of Scotland flows directly into UK refineries, then to petrol pumps in Leeds or heating systems in Edinburgh, shielding consumers from volatile international prices. But data from 2020 to 2026 reveals this story is not just misleading; it is fundamentally false.
The reality of the global oil market ensures that British consumers pay the same price for a barrel of North Sea oil as a buyer in Singapore or Rotterdam. The “British” oil is not reserved for Britain. It is a global commodity, sold to the highest bidder. Even more damaging to the government narrative is the inconvenient logistical fact that the UK exports the vast majority of what it produces.
The 80 Percent Exodus
Between 2020 and 2024, the export rate of UK crude oil hovered relentlessly high. Analysis of government trade data from 2023 confirmed that approximately 80 percent of North Sea oil is shipped overseas. This is not an accident of logistics but a feature of the market. The crude oil extracted from the North Sea is primarily “light sweet” crude. This high value variety is prized by foreign refineries for its ease of processing into petrol and diesel.
Conversely, the UK refining infrastructure was built decades ago to process heavier, cheaper crude varieties. Consequently, the UK actually imports the majority of the crude oil it refines, often from Norway or the United States. We sell our own expensive oil to buy cheaper foreign oil to process. This disconnect means that increasing North Sea production does nothing to alter the supply dynamics within the UK itself. Every new barrel extracted is simply another unit of stock for the global market, with zero mechanism to force it to remain on British soil or to be sold at a discount to British citizens.
Rosebank: The Flagship Anomaly
The approval of the massive Rosebank field in late 2023 serves as the perfect case study for this disconnect. Equinor, the Norwegian state owned giant behind the project, stated plainly that the oil from Rosebank would be sold on the open market. With reserves estimated at nearly 500 million barrels, it is the largest undeveloped field in the region. Yet, campaigners and industry analysts alike pointed out a stark truth: 90 percent of Rosebank reserves are oil, not gas, and the overwhelming majority will be exported.
When pressed on this in 2024, Energy Secretary Claire Coutinho made a rare admission. She conceded on national television that the new licensing regime “would not necessarily bring energy bills down.” This moment of candor contradicted the central pillar of the government strategy, which had explicitly linked new licenses to household financial relief during the cost of living crisis.
The Global Price Trap
The price of oil is determined by benchmarks like Brent Crude. This price is set globally, influenced by OPEC production cuts, conflict in the Middle East, or demand surges in China. The UK contributes less than 1 percent to global oil supply. Even if the UK doubled its output overnight, it would be a drop in the ocean, incapable of moving the global price dial by even a fraction of a cent. Therefore, a British family filling their car in 2025 pays a price dictated by Saudi Arabia and Texas, regardless of how many drilling rigs are operating off the coast of Aberdeen.
The North Sea Transition Authority (NSTA), the regulator responsible for licensing, has also been clear about the limits of domestic production. Their projections from 2024 indicated that new fields would only slow the natural decline of production, not reverse it, and certainly not enough to impact price. The energy security argument collapses when scrutinized; true security comes from reducing reliance on a volatile global commodity, not extracting more of it to sell to strangers.
The verdict is clear: The license to drill is a license to export. The profits flow to multinational shareholders, the tax revenue (often diminished by investment allowances) goes to the Treasury, and the oil goes abroad. The British public is left with the environmental risk and the same high bills as before.
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North Sea Oil Licenses: The Secret Deals Behind Energy Security
Energy Security vs. Market Reality: Where the Oil Actually Goes
The political rhetoric surrounding the North Sea is seductive in its simplicity. Ministers stand before the cameras, hard hats on, and promise that issuing hundreds of new licenses will secure the energy future of the United Kingdom. The narrative suggests that every barrel pumped from British waters flows directly into British pipes, fueling British cars and heating British homes. They claim this protects the nation from volatile global prices and hostile foreign actors.
Data from 2020 to 2026 reveals a starkly different reality. The “secret deal” is not a conspiracy in a smoke filled room but a mechanism of the open market that the government chooses to ignore in its public messaging. The truth is that the United Kingdom does not own the oil in its waters. Private corporations do. And they sell it to the highest bidder.
The Export Exodus
The most damning statistic undermining the energy security argument is the export rate. According to official trade figures and analysis by groups like Global Witness, approximately 80% of the oil extracted from the North Sea is exported. It leaves British shores immediately. In 2024 alone, despite the political push for “homegrown energy,” the vast majority of crude pumped from the UK Continental Shelf was loaded onto tankers destined for the Netherlands, Germany, and China.
This exodus occurs because of a fundamental mismatch in infrastructure. British refineries were largely constructed to process heavier types of crude. The oil found in the North Sea is typically “light and sweet.” Consequently, it is more profitable for companies like Shell and BP to sell this premium product on the international market than to refine it domestically. To meet its own fuel needs, the UK imports heavier crude from Norway and the United States.
2024 Market Snapshot: While the UK produced roughly 738,000 barrels of oil per day, domestic consumption hovered near 1.4 million barrels. Yet, refineries processed only about 4 million tonnes of UK origin crude for the entire year. The math shows that “more drilling” does not equal “more domestic supply.”
The Rosebank Illusion
No project illustrates this disconnect better than Rosebank, the largest undeveloped field in the region. Approved in 2023 amidst fierce controversy, Rosebank became the poster child for the energy security argument. The government claimed it would bolster national resilience.
However, the field is owned primarily by Equinor, a company in which the Norwegian state holds the dominant share. Equinor has openly stated that oil from Rosebank will be sold on the global market. There is no pipeline connecting Rosebank to the British mainland network. The oil will be pumped into a floating vessel and offloaded onto tankers. From there, it goes wherever the price is highest. The British taxpayer subsidizes the development through generous investment allowances, but the product itself provides no guarantee of domestic supply.
The Global Price Trap
The second pillar of the government narrative is that more North Sea oil will lower prices for consumers. This claim ignores the mechanics of the Brent benchmark. Oil is a fungible global commodity. Its price is set by international supply and demand, not by the output of a single basin.
Even if the UK maximized production from every license awarded in the 33rd Licensing Round of 2023 and 2024, the additional volume would be a drop in the global ocean. It would not shift the price at the pump in Leeds or London by a fraction of a penny. When global prices spiked in 2022 due to geopolitical conflict, UK produced oil was sold at those same inflated international rates. The companies made record profits while British drivers paid record prices.
A Decline Written in Geology
Looking ahead to the remainder of 2026, the geology of the North Sea dictates a continued decline. The basin is mature. The North Sea Transition Authority noted that new licenses are merely slowing the rate of depletion rather than reversing it. The new awards given to companies like TotalEnergies and Ithaca Energy in May 2024 will take years to become operational. By the time they do, the domestic demand for oil is projected to fall as the transition to electric vehicles accelerates.
The insistence on new licenses serves corporate balance sheets rather than national security. By locking the UK into a fossil fuel economy that exports its best assets while importing what it actually uses, the current policy exposes the country to the very global volatility it claims to avoid.
The following investigative report examines the approval of the Rosebank oil field, analyzing the opaque financial structures, political maneuvering, and legal battles that defined the project between 2020 and 2026.
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North Sea Oil Licenses: The Secret Deals Behind Energy Security
Case Study: The Approval of the Rosebank Field
The approval of the Rosebank oil field in September 2023 stands as a defining moment in British energy policy, exposing the deep disparity between public rhetoric on energy security and the private financial mechanics of the fossil fuel industry. Located 80 miles northwest of Shetland, Rosebank is the largest undeveloped field in the region, holding approximately 300 million to 500 million barrels of crude oil.
While the Conservative government under Rishi Sunak championed the project as a necessary step for domestic energy independence, an analysis of the licensing terms reveals a different reality. The core of the controversy lies in the financial architecture constructed between the state and the operators, Equinor (80% stake) and Ithaca Energy (20% stake).
The Export Loophole
The central argument for approval was “energy security,” a narrative suggesting that Rosebank oil would lower prices for British consumers. However, internal government admissions in 2024 painted a starkly different picture. In a written parliamentary answer, the government conceded that it had no power to force private companies to allocate North Sea oil for domestic use. Since Rosebank crude is not suited for UK refineries, approximately 80% of the oil was destined for export to international markets.
This reality meant that while British taxpayers assumed the vast majority of the financial risk through tax subsidies, the profits would flow to Equinor, a Norwegian state owned entity, and Ithaca Energy. In 2022 alone, Equinor reported global pre tax profits of £62 billion, yet the UK fiscal regime allowed them to offset significant tax liabilities against new drilling investment.
Legal Challenges and the 2025 Ruling
The opacity of the approval process triggered immediate legal action. Environmental groups Uplift and Greenpeace launched judicial reviews in late 2023, arguing that the government unlawfully failed to consider “downstream emissions”—the pollution caused when the oil is eventually burned. The case highlighted a secretive aspect of the regulatory process: the refusal of the North Sea Transition Authority (NSTA) to count these emissions in their environmental impact assessments.
In January 2025, the Scottish Court of Session delivered a landmark verdict. The court ruled that the decision to approve Rosebank was unlawful. The judge cited the failure to assess the climate impact of the combustion of the oil, which would produce over 200 million tonnes of carbon dioxide over the field’s lifetime—more than the combined annual emissions of the world’s 28 lowest income countries.
The Aftermath
Following the 2025 ruling, the future of Rosebank remains in flux. Equinor was forced to pause development plans to resubmit environmental statements. The delay pushed the expected “first oil” date well beyond the initial 2026 target. This legal defeat for the government exposed the fragility of licensing deals made behind closed doors without full transparency regarding environmental costs and economic benefits.
The Rosebank case study illustrates that the true “secret deals” were not illicit handshakes but complex fiscal instruments and regulatory omissions designed to prioritize corporate asset value over genuine national energy security or climate obligations.
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Case Study: The Controversial Pause and Resumption of Cambo
The narrative surrounding the Cambo oil field represents a masterclass in corporate maneuvering and political sleight of hand. Located 125 kilometers northwest of the Shetland Islands, this field became a flashpoint for environmental activism during the COP26 climate summit in Glasgow. However, the public story of a climate victory in 2021 obscures a quieter, more profitable reality that unfolded between 2022 and 2026.
The Public Retreat
In December 2021, Royal Dutch Shell announced its decision to withdraw from the Cambo project. At the time, Shell held a 30 percent stake in the venture, with Siccar Point Energy holding the remaining 70 percent. The official statement cited that the “economic case for investment” was not strong enough. Activists celebrated this as a direct result of public pressure following the intense scrutiny of COP26. The project, capable of yielding 170 million barrels of oil equivalent over 25 years, appeared dead in the water.
Yet, the license did not expire. It merely entered a state of dormancy while the financial landscape shifted. The pause was not a cancellation but a strategic wait for better terms.
The Hidden Subsidy Mechanism
The geopolitical shock of the Russian invasion of Ukraine in early 2022 provided the perfect cover for policy reversal. Under the guise of energy security, the UK government introduced the Energy Profits Levy in May 2022. While publicly billed as a windfall tax on soaring energy profits, the legislation contained a critical loophole known as the “investment allowance.”
This fiscal mechanism allowed oil and gas companies to claim back 91 pence in tax relief for every 1 pound invested in new fossil fuel extraction. Effectively, the British taxpayer began subsidizing 91 percent of the cost of new drilling operations. This transformed the economics of fields like Cambo overnight. A project deemed “uneconomic” by Shell in late 2021 became a goldmine by mid 2022, provided the operator was willing to spend capital on development.
The Quiet Acquisition
Enter Ithaca Energy, a subsidiary of the Delek Group. In April 2022, just before the tax breaks were formalized, Ithaca announced the acquisition of Siccar Point Energy for approximately 1.5 billion dollars. This deal transferred the controlling 70 percent stake in Cambo to Ithaca. By November 2023, Ithaca consolidated its control further by acquiring the remaining 30 percent stake from Shell, giving it 100 percent ownership of the field.
The “secret deal” here was not a handshake in a smoke filled room but a blatant manipulation of fiscal policy. The tax loophole meant that the acquisition and subsequent development costs could be heavily offset against the windfall tax liabilities Ithaca faced from its other North Sea assets. The exit of Shell allowed a less consumer facing entity to take over, shielding the project from the same level of reputational damage while capitalizing on the new tax incentives.
Current Reality: 2024 to 2026
As of 2026, Cambo is no longer a paused project but an active asset in the Ithaca Energy portfolio. The field is set to use a Sevan FPSO vessel for extraction. Despite the rhetoric of “homegrown energy,” the oil extracted from Cambo is heavy crude, unsuited for UK refineries, and will likely be sold on the global market rather than lowering domestic bills.
The “pause” in 2021 served its purpose. It defused immediate political heat, allowed a transfer of ownership to a company with a higher risk appetite, and waited for a tax regime that effectively de-risked the capital investment. The Cambo case study reveals that energy security is often a secondary concern to the primary objective: securing favorable fiscal terms for extraction.
Environmental Impact Assessments: Rubber Stamping or Rigorous Review?
The machinery of British energy policy has shifted gears rapidly between 2020 and 2026. Under the guise of national security and economic stability, the government unleashed a flurry of activity in the North Sea. The narrative sold to the public suggests that every new drill site undergoes forensic scrutiny. Officials claim that only the most environmentally sound projects survive the regulatory gauntlet. However, an analysis of data from the North Sea Transition Authority and the Offshore Petroleum Regulator for Environment and Decommissioning suggests a different reality. The evidence points toward a system designed for approval rather than interrogation.
The Illusion of scrutiny in the 33rd Round
The 33rd Oil and Gas Licensing Round launched in October 2022. It offered hundreds of blocks for exploration. By 2024, the government had awarded dozens of new licenses. The central safeguard in this process is the Environmental Impact Assessment. In theory, this document ensures that drilling does not cause irreparable harm to marine ecosystems or climate goals. In practice, the rejection rate for these assessments is statistically negligible. Between 2020 and 2025, the regulator rarely blocked a project solely on environmental grounds. Instead, they requested minor clarifications, allowing companies to amend paperwork and proceed without altering the fundamental mechanics of extraction.
Critics describe the relationship between the regulator and the industry as uncomfortably close. The fees paid by oil companies fund the very bodies tasked with policing them. This structural conflict creates an ecosystem where the priority is facilitating extraction rather than limiting it.
The Rosebank Controversy and Scope 3 Emissions
The approval of the Rosebank oil field in September 2023 serves as the definitive case study. Situated northwest of Shetland, Rosebank contains approximately 300 million barrels of oil. Equinor, the Norwegian state owned giant, spearheaded the project. The Environmental Statement submitted by Equinor focused heavily on operational emissions. They promised to electrify the rig to reduce the carbon footprint of the extraction process itself.
However, the assessment completely ignored the emissions created when consumers actually burn the oil. These represent the vast majority of the pollution. Until mid 2024, the regulator allowed companies to exclude these downstream emissions, known as Scope 3, from their impact assessments. The government rubber stamped Rosebank based on a fraction of its total climate impact. This bureaucratic slight of hand allowed ministers to claim the project was compatible with Net Zero targets while approving a carbon bomb.
The Supreme Court Intervention
The legal landscape shifted violently in June 2024. The UK Supreme Court delivered a landmark judgment in the case of R (on the application of Finch) v Surrey County Council. The court ruled that regulators must consider the combustion emissions of fossil fuel projects within their Environmental Impact Assessments. This ruling retroactively exposed the inadequacy of the North Sea licensing regime between 2020 and 2023.
Following this judgment, the legality of the Rosebank and Jackdaw approvals collapsed. In August 2024, the government confirmed it would not defend legal challenges brought by environmental groups against these fields. This admission was a tacit acceptance that the previous rigorous review was nothing of the sort. The assessments had failed to measure the primary purpose of the project: the burning of hydrocarbons.
A Broken Checkpoint
The government introduced a Climate Compatibility Checkpoint in 2022 to quiet dissent. Officials promised this mechanism would align future licensing with the Paris Agreement. Yet, data released in 2023 showed the checkpoint failed to stop the 33rd Licensing Round. The test was designed with specific exclusions that guaranteed pass marks for the industry. It measured the emissions of producing UK oil against global averages but ignored the absolute increase in global atmospheric carbon.
By 2026, the legacy of this era is clear. The Environmental Impact Assessment became a bureaucratic shield for political decisions. It offered the veneer of scientific due diligence while systematically ignoring the only metric that matters for climate security: the total volume of carbon entering the atmosphere. The regulatory process did not filter out dangerous projects. It simply provided the paperwork to legitimize them.
The Climate Compatibility Check: Legal Challenges and Judicial Reviews
For years, the narrative governing the North Sea was one of seamless synergy between extracting oil and meeting climate goals. In September 2022, the UK government unveiled its flagship mechanism to bridge this divide: the Climate Compatibility Checkpoint. Designed to screen new licenses, it promised a rigorous environmental test for every new project. Yet, an investigation into its design reveals a deliberate omission that served as a “secret deal” to keep the drills turning. The checkpoint explicitly excluded Scope 3 emissions—the carbon released when the oil is actually burned. By focusing solely on the emissions from the drilling machinery itself (Scope 1 and 2), the test was engineered to ensure that even the largest carbon bombs could pass. This regulatory sleight of hand allowed the 33rd licensing round to proceed in late 2022, offering up over 100 new licenses under a veneer of green compliance.
The Finch Ruling: A Supreme Court Shockwave
The legal fiction that a producer is not responsible for the combustion of their product crumbled in June 2024. In the landmark case R (Finch) v Surrey County Council, the UK Supreme Court delivered a verdict that sent shockwaves through the boardrooms of Shell, Equinor, and Ithaca Energy. By a tight 3 to 2 majority, the judges ruled that Environmental Impact Assessments for fossil fuel projects must include Scope 3 emissions.
Lord Leggatt, writing for the majority, dismantled the industry defense that combustion was too uncertain to measure. He argued that burning the oil was not just likely, but “inevitable.” This ruling instantly invalidated the logic underpinning the Climate Compatibility Checkpoint. It stripped away the legal cover that had protected North Sea licenses for decades. The judgment meant that the government could no longer approve projects like the Horse Hill development in Surrey—or by extension, massive offshore fields—without accounting for the climate damage caused by the fuel itself.
The Fall of Rosebank and Jackdaw
The theoretical risk of Finch became a concrete reality in January 2025. The Court of Session in Edinburgh issued a decisive ruling regarding two of the most contentious projects in the UK continental shelf: the Rosebank oil field and the Jackdaw gas field.
Rosebank, situated northwest of Shetland, holds approximately 500 million barrels of crude. Its approval in September 2023 had been the final major act of the previous Conservative administration’s energy policy. Jackdaw, a Shell project, had been approved in 2022. Following the precedent set by Finch, the Scottish court declared the approvals for both fields unlawful. The judges accepted the argument brought by groups like Greenpeace and Uplift that the original consents were legally flawed because they ignored downstream emissions.
In a dramatic pivot, the new Labour government, elected in mid 2024, chose not to defend the lawsuits. This left the oil majors standing alone in court. The government accepted that the approvals breached the law, a move that effectively quashed the development consents. As of early 2026, work on these fields has ground to a halt. The developers are now forced to restart the regulatory process, this time producing transparent data on the millions of tons of carbon dioxide their products will release.
2026: A Broken Timeline
The delay has wrecked the industry timeline. Rosebank was originally slated to begin production around 2026 or 2027. Now, with fresh environmental statements required and further litigation likely, the first oil is nowhere in sight. The “energy security” argument, often used to justify these fast track approvals, has backfired. Instead of securing immediate supply, the reliance on legally fragile secret deals has resulted in paralysis.
Data from the North Sea Transition Authority shows that production decline rates have continued unabated, while the promised economic boom from new licenses has stalled in the courts. In January 2026, the newly formed North Sea Future Board met for the first time, tasked not with maximizing recovery, but with managing a transition that is now legally enforced rather than politically managed. The era of ignoring the burn is over; the courts have turned the lights on.
Shadow Owners: Transparency Issues Regarding Ultimate Beneficial Ownership
The ownership architecture of the North Sea has undergone a quiet but radical transformation. Once the domain of publicly listed giants like Shell and BP, the basin is now increasingly controlled by a complex web of private equity firms, foreign state entities, and opaque corporate structures. By early 2026, data reveals a stark reality: the entities guaranteeing UK energy security are often unknown to the British public, hidden behind layers of offshore holding companies and confidentiality agreements.
The Private Equity Takeover
The most significant shift in the last six years has been the migration of assets into private hands. Research from the Common Wealth think tank indicated that by 2024, nearly 30% of North Sea licenses were held by companies backed by private equity. Unlike Public Limited Companies (PLCs), these firms face fewer disclosure requirements. They are not obligated to publish the same granular level of environmental, social, and governance (ESG) reports, nor are they subject to the immediate pressure of public shareholders.
This opacity creates a “accountability void.” For instance, during the 33rd licensing round, which concluded its final tranche awards in May 2024, several winning bids came from entities with complex ownership structures. Companies like Perenco, a private major with a significant UK footprint, operate without the stock market scrutiny faced by their listed peers. While legally compliant, this structure means that ultimate beneficial owners (UBOs) can remain shielded from public view, making it difficult to trace profits or pin down liability for environmental decommissioning costs.
Foreign State Influence
Parallel to the rise of private equity is the consolidation of assets by foreign state owned enterprises. By 2025, over 40% of North Sea licenses were effectively owned by entities based outside the UK. A substantial portion, approximately 11%, belonged to foreign governments, including Norway, the United Arab Emirates, and China. While Equinor (Norway) operates with high transparency, other state actors bring geopolitical complexities into British waters.
The energy security paradox is evident. The UK government prioritizes domestic production to reduce reliance on imports, yet the profits and strategic control of “British” oil often lie with foreign treasuries. In 2023 and 2024, significant stakes in key infrastructure were held by Taqa (UAE) and CNOOC (China). When political tensions rise, the leverage these nations hold over UK energy assets becomes a matter of national concern, yet the licensing process has historically focused on financial capability rather than geopolitical alignment.
The “Tieback” Loophole and Shadow Drilling
The political landscape shifted dramatically with the election of a Labour government in 2024, which pledged to end new exploration licenses. However, the industry adapted through “tiebacks” and “Transitional Energy Certificates,” a mechanism introduced in late 2025 to allow drilling near existing infrastructure. This policy created a secondary market for older licenses, often snapped up by smaller, less transparent operators willing to extract remaining reserves from aging fields.
These transactions often occur below the radar. Throughout 2025, assets changed hands in private deals where the buyer’s ultimate funding source was obscured. The Register of Overseas Entities, intended to crack down on anonymous foreign ownership of UK property, proved less effective in the offshore energy sector. Loopholes allowed nominee directors and offshore trusts to mask the true beneficiaries of these lucrative tieback contracts.
Legal Interventions as Sunshine
The courts have become the primary instrument for transparency. The January 2025 ruling by the Scottish Court of Session, which declared the approval of the Rosebank and Jackdaw fields unlawful, forced a rare moment of clarity. The legal discovery process exposed the inadequacy of emissions assessments and, inadvertently, highlighted the intricate ownership web of the developers involved. Ithaca Energy, a partner in Rosebank, is majority owned by the Delek Group, heavily leveraged and distinct from the traditional stability associated with North Sea majors.
As investment plummeted to record lows in 2025, reaching just £100 million for exploration, the players remaining in the basin were those with the highest risk appetite and the lowest desire for publicity. The “shadow owners” are now the custodians of the North Sea’s final chapter, operating in a twilight zone where profit maximization meets minimal public oversight.
The Decommissioning Timebomb: Who Will Pay for the Cleanup?
The rusting steel skeletons of the North Sea stand as monuments to a bygone era of immense profit. For decades, these platforms pumped black gold that fueled the British economy, but as 2026 begins, the flow of oil has slowed to a trickle. What remains is a sprawling industrial graveyard and a financial liability of staggering proportions. The question is no longer about how much wealth can be extracted from these waters, but rather who will foot the bill for removing the infrastructure left behind. Investigative analysis of data from 2020 to 2026 reveals a disturbing reality: while private companies reaped the rewards, the British taxpayer is being maneuvered into underwriting the cleanup.
The Multibillion Pound Liability
The scale of the task is immense. According to the North Sea Transition Authority (NSTA), the cost of fully decommissioning the remaining infrastructure in the UK Continental Shelf is monumental. In its July 2025 update, the NSTA estimated that operators would spend £27 billion between 2023 and 2032 alone. The total remaining cost for full decommissioning from 2025 onwards stands at approximately £44 billion. These figures are not static; they are climbing. The 2025 report highlighted a worrying trend where cost estimates for the decade had risen by £3 billion compared to the previous year, driven by inflation and higher rates for heavy lift vessels.
This expenditure covers the plugging of thousands of wells and the removal of millions of tonnes of steel and concrete. In 2024, the industry spent a record £2.4 billion on this work, yet this is merely the down payment on a debt that will stretch into the 2060s. Wood Mackenzie, an energy intelligence group, valued the total sector liability at nearly $58 billion through the early 2060s in their January 2025 analysis.
Passing the Liability
A subtle but dangerous game of financial musical chairs has played out across the basin since 2020. Major energy giants like Shell and BP have gradually divested their aging assets, selling them to smaller, independent operators. On paper, the responsibility for cleanup transfers to the new owner. However, these smaller entities often lack the deep pockets of the supermajors. If a smaller operator collapses under the weight of decommissioning costs, the liability risks reverting to the state.
This is not a theoretical risk. The financial ecosystem of the North Sea has become increasingly fragile. The introduction of the Energy Profits Levy in 2022, which taxed extraordinary profits at 78 percent, accelerated the closure of older fields. While this windfall tax captured revenue during the energy crisis, it also pushed marginal assets closer to insolvency. By early 2026, reports indicated a stark contraction in investment, with 2025 marking the first year since 1960 with zero exploration wells drilled. As revenue streams dry up for smaller firms, their ability to fund cleanup operations diminishes.
The Taxpayer Guarantee
The mechanism binding the taxpayer to these corporate obligations is the Decommissioning Relief Deed (DRD). Introduced by the government to encourage investment, these legal contracts guarantee that companies will receive tax relief on their decommissioning spending, regardless of future changes in tax law. As of March 2023, the government had signed 105 such deeds. They effectively promise that the Treasury will cover a significant portion of the cleanup bill through tax rebates.
The sums involved are astronomical. In July 2024, HMRC projected the Exchequer cost of decommissioning tax relief at £10.8 billion. This figure comprises £5.7 billion in direct tax repayments and a £5.1 billion reduction in offshore corporate tax receipts. While this is a decrease from the £21.8 billion estimated in 2023 (due to fluctuating oil prices and tax takes), it remains a massive transfer of public wealth to private entities for the purpose of cleaning up their own mess.
A Legacy of Risk
The years 2020 to 2026 have exposed the structural weakness in UK energy security strategy. By allowing assets to pass from strong hands to weak ones, regulators have allowed a systemic risk to fester. The NSTA has urged operators to consolidate campaigns to save money, but as of 2026, the sector faces severe supply chain constraints. Heavy lift vessels are in short supply globally, driving prices up and pushing timelines out. Every delay adds to the final bill.
Ultimately, the North Sea is transitioning from a source of revenue to a sinkhole of expenditure. The profits have been privatized and distributed to shareholders over the last fifty years. Now, as the rigs fall silent and the rust takes hold, the costs are being socialized. Without rigorous enforcement and financial safeguards, the British public stands to inherit not just a cleaner ocean, but the most expensive industrial cleanup in national history.
Geopolitical Triggers: The Ukraine War’s Effect on Licensing Speed
The Russian invasion of Ukraine in February 2022 did not just disrupt global markets; it provided the perfect cover for a radical shift in British energy policy. Prior to the conflict, the United Kingdom faced intense pressure to wind down North Sea operations following the COP26 summit in Glasgow. Yet the tanks rolling toward Kyiv offered Westminster a new narrative: energy security. Under the guise of national resilience, the government initiated a rapid acceleration of offshore licensing that prioritized speed over scrutiny, culminating in controversial awards that continue to shape the sector through 2026.
The Dash for Gas
In the immediate aftermath of the invasion, the “British Energy Security Strategy” emerged as the foundational document for this pivot. The centerpiece was the 33rd Oil and Gas Licensing Round, launched in October 2022. While previous rounds had been cautious, this iteration was expansive. The North Sea Transition Authority (NSTA) offered over 900 blocks for exploration. By the time the process concluded in May 2024, the regulator had awarded 82 licenses to 50 companies, including majors like Shell, BP, and Equinor.
The speed of these awards was unprecedented in the modern era. The NSTA expedited the process by prioritizing areas with known reserves, specifically targeting four “priority clusters” to ensure production could begin faster. Officials argued this was essential to replace Russian imports. However, internal government data revealed a starker reality: approximately 80% of the oil extracted from these new fields would be traded on the international market rather than used domestically. The “security” argument was a geopolitical shield for commercial expansion.
Legislating the Rush
To institutionalize this aggressive approach, the Conservative government introduced the Offshore Petroleum Licensing Bill in late 2023. The legislation aimed to mandate annual licensing rounds, effectively removing the discretion of future regulators to pause exploration on climate grounds. While the bill passed the House of Commons in February 2024, it faced fierce opposition and ultimately stalled during the general election campaign later that year. Nevertheless, the signal to the industry was clear: extract as much as possible, as fast as possible.
Legal Roadblocks and the Rosebank Ruling
The haste to approve projects led to critical oversight failures. The approval of the massive Rosebank field in September 2023 became the focal point of this tension. Owners Equinor and Ithaca Energy pushed forward, but the expedited “Climate Compatibility Check” proved legally fragile. in January 2025, the Scottish Court of Session ruled the approval unlawful. The court found that the government had failed to assess Scope 3 emissions, which cover the burning of the fuel rather than just its extraction. This landmark ruling forced companies to resubmit environmental assessments, stalling the very projects the government had tried to fast track.
The 2026 Pivot: Transitional Energy Certificates
Following the political shift in mid 2024, the new Labour administration faced a dilemma: honoring a manifesto pledge to stop new exploration licenses while managing industry pressure. The solution arrived in November 2025 with the “North Sea Future Plan.” While officially banning new exploration licenses, the policy introduced “Transitional Energy Certificates.”
This mechanism allows operators to drill “tie backs” to existing infrastructure. These satellite fields, reachable from current platforms, bypass the ban on new licenses. By early 2026, industry lobbying had successfully framed these extensions as necessary for a “managed transition.” Critics argue this creates a loop hole where significant new reserves are tapped under the banner of maintenance. The result is a hybrid system: the headline “annual licensing” is gone, but the flow of oil continues through these quieter, less visible regulatory backdoors.
Political Divides: Labour’s Proposed Ban vs. Conservative Maximization
The ideological chasm between the Conservative government of 2020 to 2024 and the Labour administration elected in July 2024 redefined the operational landscape of the North Sea. For four years, the stated priority in Westminster was to “maximise economic recovery” from the United Kingdom Continental Shelf. This strategy, driven by the energy security anxieties following the invasion of Ukraine, culminated in the 33rd Offshore Licensing Round. The Conservative leadership argued that domestic extraction was far cleaner than importing liquefied natural gas, which carries a carbon intensity four times higher than local production. In late 2023, this policy resulted in the approval of the Rosebank field, the largest undeveloped resource in the region, containing approximately 300 million barrels of oil.
The political narrative shifted abruptly with the Labour victory in July 2024. Prime Minister Keir Starmer entered Downing Street with a manifesto pledge to halt all new exploration licenses immediately. While the new administration promised to honour existing contracts to avoid compensation claims, the issuance of fresh permits ceased completely. By late 2024, the North Sea Transition Authority had paused all licensing rounds, effectively freezing the pipeline for future discovery. The policy aimed to position the UK as a “clean energy superpower” by diverting focus toward the newly established Great British Energy, a public entity headquartered in Aberdeen with an initial capitalization target of £8.3 billion over the parliament.
The divide widened further through fiscal policy. In November 2024, Chancellor Rachel Reeves increased the Energy Profits Levy, raising the headline tax rate on oil and gas producers from 75 percent to 78 percent. Crucially, the government removed the generous investment allowances that had previously permitted companies to offset tax liabilities by reinvesting in fossil fuel infrastructure. Industry bodies like Offshore Energies UK warned that this removal created an investment “cliff edge.” The consequences materialized in the 2025 fiscal data. Despite the higher tax rate, revenue from the levy was forecast to fall to £2.7 billion in the 2025 to 2026 period, a drop of 40 percent compared to the previous year, as capital flight accelerated and production volumes declined faster than anticipated.
Legal challenges in 2025 exposed the fragility of the “existing licenses” compromise. In January 2025, the Court of Session in Scotland delivered a landmark ruling regarding the Rosebank development. The court found the original approval unlawful because the environmental impact assessment had failed to account for “Scope 3” downstream emissions, which occur when the oil is eventually burned. This decision left the project in limbo and signaled to investors that even approved licenses were vulnerable to judicial review. The ruling forced the Labour government into a complex position: defending a project approved by their predecessors while maintaining their own stance against new oil.
By early 2026, the practical reality of the transition had come into sharp focus. Data from the regulator indicated that without new fields, the UK would rely on imports for 97 percent of its gas needs by 2050. Proponents of the ban argued this necessitated a faster buildout of wind capacity through Great British Energy. However, critics pointed to the immediate economic contraction in northeast Scotland, where supply chain firms faced a gap between the decommissioning of oil rigs and the full scaling of renewable projects. The debate had moved from theoretical targets to tangible trade offs, with the UK actively dismantling one energy system before the successor was fully operational.
Conclusion: The Future of the North Sea in a Net Zero World
By February 2026, the narrative surrounding the North Sea has shifted from a promise of prosperity to a managed decline. The aggressive licensing strategy seen between 2023 and 2024, culminating in the controversial 33rd Licensing Round, granted over 80 new permits under the guise of energy security. Yet, two years later, the data exposes a stark disconnect between political rhetoric and geological reality. The basin is not a treasure chest waiting to be reopened; it is a fading asset where the cost of extraction rises as yields plummet.
The “energy security” argument, once the primary shield for ministers defending new exploration, has dissolved under scrutiny. Official trade figures from 2024 and 2025 confirm that the United Kingdom exports approximately 80 percent of its North Sea oil production. The crude extracted from fields like Rosebank, approved in late 2023 with reserves estimated at 300 million barrels, is not refined domestically to lower British fuel bills. Instead, it enters the global market, sold to the highest bidder in the Netherlands or Germany. The British public bears the environmental risk and the fiscal cost of tax incentives while the physical resource flows overseas.
Fiscal policy remains the mechanism driving this contradiction. The Energy Profits Levy, intended as a windfall tax, contained a critical flaw that allowed companies to claim 91 pence in tax relief for every pound invested in new fossil fuel extraction. This “super deduction” effectively subsidized the drilling of wells that climate scientists warned were incompatible with the 1.5C target. By late 2025, despite a change in government leadership and the release of the “North Sea Future Plan” in November, the legacy of these fiscal structures continued to protect operator profits over public revenue. The introduction of “Transitional Energy Certificates” allowed for continued production via tiebacks to existing infrastructure, ensuring that while new exploration licenses were halted, the extraction from established fields could persist for decades.
The trajectory for 2026 involves a painful collision between these legacy contracts and the binding Net Zero mandates. The North Sea Transition Authority projected a production decline of roughly 7 percent to 12 percent annually, a geological inevitability that no amount of licensing can reverse. The 2025 production figures dropped to new lows, yet the decommissioning bill looms larger than the revenue generated. The state now faces a scenario where tax receipts from the sector are overtaken by the tax rebates owed to companies dismantling their aging platforms. This financial inversion turns the North Sea from a sovereign asset into a sovereign liability.
Corporate strategy has adapted by pivoting to “blue hydrogen” and carbon capture, utilizing the depleted reservoirs for storage. However, this transition is slow. The licenses awarded in 2024 have locked capital into traditional extraction projects that risk becoming stranded assets before they turn a profit. The Rosebank field, still facing legal and social opposition in early 2026, symbolizes this paralysis. It represents billions in capital expenditure tied to a commodity the world has promised to abandon.
Ultimately, the frenzied licensing of the early 2020s did not secure the future; it merely mortgaged the present. The North Sea remains a vital component of the energy mix, but its role has changed. It is no longer a source of infinite growth but a complex decommissioning challenge that requires careful management rather than reckless expansion. The deals signed in the shadow of the energy crisis have bound the UK to a fossil fuel infrastructure that contradicts its own climate laws, leaving the nation drifting between a past it cannot recover and a green future it struggles to finance.
Here is an HTML list of 10 real news references and investigative reports.
These articles cover the themes implied by your topic: the granting of controversial licenses (like Rosebank), the lobbying and financial incentives (the “deals”), and the counter-arguments regarding whether this actually provides “energy security” (given that most North Sea oil is sold on the global market).
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References: North Sea Oil Licenses & Energy Security
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The Guardian (2023) –
Rosebank oilfield approved by regulators despite climate concerns
Covers the approval of the UK’s largest undeveloped oil field, detailing the “deal” involving tax breaks that allow Equinor to deduct 91p for every £1 invested. -
BBC News (2023) –
Rosebank: Does the UK need more oil and gas?
Investigates the “Energy Security” claim, noting that 80% of North Sea oil is exported and sold on international markets rather than kept for UK use. -
OpenDemocracy (2022) –
Oil and gas lobbyists met ministers more than 100 times during energy crisis
Investigates the “Secret Deals” aspect by tracking the intense access fossil fuel lobbyists had to government officials while licenses were being negotiated. -
Reuters (2023) –
Britain grants new North Sea oil and gas licences in energy security push
Reports on the government’s issuance of 27 new licenses, framing the official narrative of “energy security” against industry decline. -
DeSmog (2023) –
Rishi Sunak’s Family Firm Signed Billion-Dollar Deal with BP Before PM Opened New North Sea Drilling
An investigative piece exploring potential conflicts of interest and financial ties between political leadership and energy majors like BP. -
Financial Times (2023) –
Sunak to grant hundreds of new North Sea oil and gas licences
(Paywall) Details the political strategy behind the licensing rounds and the backlash regarding the compatibility with Net Zero pledges. -
Global Witness (2023) –
UK government giving billions in tax giveaways to oil and gas companies
Analyzes the “Investment Allowance” loophole in the windfall tax, explaining the financial mechanics that incentivize new drilling over renewable investment. -
Sky News (2022) –
Jackdaw gas field: Final regulatory approval given for Shell project
Covers the approval of the controversial Jackdaw field, highlighting the tension between energy prices and environmental commitments. -
Carbon Brief (2023) –
Factcheck: Claims that new North Sea oil and gas is ‘good for the environment’
Deconstructs the government’s argument that local drilling has a lower carbon footprint than imports, a key justification used in licensing deals. -
Unearthed (Greenpeace) (2023) –
BP and Shell profits: How the windfall tax failed to capture the bonanza
Investigates how the structure of the Energy Profits Levy allowed major companies to retain record profits through new extraction licenses.
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