The UK has a well-established upstream oil and gas industry, with commercial production from the UK Continental Shelf (UKCS) since the 1960s. By the end of 2024, all-time cumulative production of oil and gas from the UKCS reached 47.7 billion barrels of oil equivalent (boe).

Although UK production has been in gradual decline since its peak in 1999 (for crude) / 2000 (for natural gas), the UK’s independent regulator, the North Sea Transition Authority (NSTA), estimates proven and probable (2P) UK reserves as at the end of 2024 to be 2.9 billion boe. This is 0.4 billion boe lower than as at the end of 2023 due to production during 2024 not being offset by approval of incremental projects in producing fields. However, prospective resources (undiscovered potentially recoverable resources) are up by 31% from the end of 2023 due to the most recent offshore licensing round in 2022. On the basis of current production models, the NSTA’s datasets project that remaining reserves could sustain production from the UKCS until 2050, albeit on a steeply declining trajectory.

The primary legislation relating to the exploration and development of hydrocarbon resources is the Petroleum Act 1998 (Petroleum Act). The Petroleum Act governs all offshore licensing. It also governs onshore licensing, except as follows:

• onshore licensing in Northern Ireland is subject to a separate regime; and
• onshore licensing in Scotland and Wales has been devolved to those governments under the Scotland Act 2016 and the Wales Act 2017.

The Petroleum Act vests all rights to “search for, bore and get” crude oil and natural gas resources in the Crown. Regulatory responsibility on behalf of the Crown lies with the Department for Energy Security and Net Zero (DESNZ), but much of its authority is exercised by the NSTA. Under the Energy Act 2016, the NSTA was formally granted various functions and powers relating to the administration and enforcement of licences. A Framework Document governs the relationship between DESNZ and the NSTA.

Licences are awarded by the NSTA through competitive licensing rounds that are held almost annually in respect of offshore licences, and less frequently in respect of onshore licences. The most recent offshore licensing round (the 33rd) was held in October 2022 (with licence awards made in October 2023, January 2024 and May 2024) and the most recent onshore licensing round (the 14th) was held in 2014. On occasion, there are separate “out of round” offers and awards of licences.

The UK has offshore licences call Seaward Production Licences and Seaward Exploration Licences. Onshore licences are called Landward Production

Licences and Landward Exploration Licences. The NSTA regulates, influences and promotes the UK’s oil and gas industry, including licence holders.
Licences can be held by a single company or by several working together, but in legal terms there is only ever a single licensee however many companies it may comprise. All companies on a licence share joint and several liability for obligations and liabilities that arise under it.

Offshore production licences are issued after a competitive process, usually a licensing round. They give licence holders exclusive rights to exploration and production within the licence area. They typically run for three successive terms. The initial term is usually for exploration activities such as geotechnical studies and geophysical data reprocessing, undertaking seismic surveys and acquiring other geophysical data, and drilling wells. The licence will expire at the end of its initial term unless the licensee has completed an agreed initial term work programme and surrendered a fixed amount of acreage (generally 50%). The second term is for further exploration and appraisal work. The licence will expire at the end of its second term unless the NSTA has approved a development plan. The third term is intended for production.

Offshore exploration licences are intended for exploration only and do not confer production rights. They are typically for seismic contractors and others who wish to gather data, on a non-exclusive basis, to sell rather than use themselves. They may also be used for production licence holders wishing to explore outside the areas where they hold production licence rights.

Offshore “innovate licences” are also available, which offer greater flexibility in the durations of the initial and second terms and allow for the testing and development of new technologies.

Licences incorporate terms, referred to as the “model clauses”, which are set out in statutory regulations. Licensees must also comply with generally applicable law, including the obligations arising under the legally binding “NSTA Strategy” (see question 18 for further detail on the strategy).

Shale gas discoveries have been made in the UK but are not currently being exploited.

In addition to the usual consents required for onshore oil and gas development, any operator intending to undertake hydraulic fracturing for shale must obtain a Hydraulic Fracturing Consent (HFC) issued by DESNZ, which is only issued once a list of pre-conditions are satisfied. HFCs were introduced under the Infrastructure Act 2015 (by way of amendment to the Petroleum Act 1998), as an additional step to the existing onshore oil and gas regulatory and permitting regime.

On 2 November 2019, the UK government announced that it would take a presumption against issuing any further Hydraulic Fracturing Consents in England, effectively creating a moratorium on shale development. The government has confirmed that the moratorium will remain in place until “compelling new evidence” can be provided to address concerns around the accuracy of predicting the probability or magnitude of earthquakes linked to fracking operations. The licensing of onshore oil and gas has been devolved to Scotland and Wales. The Scottish Government confirmed its final policy position of no support for banning unconventional oil and gas in October 2019, and the Welsh government confirmed that fracking would not be supported in Wales in December 2018.

Prior to its November 2019 announcement, the UK government was encouraging shale gas exploration, and had introduced a number of measures to support such exploration, including:

• sharing the proceeds of the wealth generated with communities affected;
• proposing legislation to change planning law and policy to facilitate shale development; and
• setting up a new Shale Environmental Regulator in 2018.

The key regulator for the upstream oil and gas industry is the NSTA. The NSTA is a government-owned company and exercises almost all of the regulatory functions relevant to the upstream industry. It was granted these powers under the Energy Act 2016. The North Sea Future Plan published on 26 November 2025 (see question 18) announces further changes to the NSTA’s powers and role to reflect the changing nature of the UKCS, although details of these changes remain outstanding. The Department for Business, Energy & Industrial Strategy (BEIS) plays an indirect role in the upstream oil and gas sector, particularly in overseeing broader policy areas related to energy, climate change, and regulation. However, DESNZ remains the government department with regulatory control over the industry and is responsible for the overall policy and legislative framework within which the NSTA operates. The NSTA also has responsibilities relating to the application of environmental legislation (carried out through a unit called the Offshore Petroleum Regulator for Environment and Decommissioning (OPRED)) and in respect of decommissioning activities. The relationship between DESNZ and the NSTA is governed by a Framework Document.

Other regulators also play important, but more specific, roles – the Health and Safety Executive (HSE) is responsible for health and safety matters, the Maritime and Coastguard Agency have authority in respect of emergency response and the Offshore Major Accident Regulator (a partnership of HSE and OPRED) is responsible for safety.

The government does not directly participate in the upstream oil and gas industry, other than having an economic interest in the development of oil and gas by collecting tax revenues (see question 9). The UK does not have a government-owned oil and gas company; all oil and gas development is carried out by privately owned or foreign-state owned companies under the licensing regime described in question 2. However, The Great British Energy Act received Royal Assent on 15 May 2025, formally establishing a new publicly-owned but operationally independent national energy company, known as Great British Energy. At this stage its role is limited to investing in and operating “clean energy” assets and not to participate in the oil and gas industry.

In order to apply for a licence, a company must satisfy the NSTA that it has a place of business within the UK, which will be satisfied it the company (i) has a staffed presence in the UK; (ii) is registered at Companies House as a UK company; or (iii) has a UK branch of a foreign company registered at Companies House. An applicant will only be awarded a licence by the NSTA if it meets certain financial, fitness, technical and other considerations.

In addition, there have been some recent legislative changes which are relevant in the context of foreign participation in the upstream oil and gas industry. In January 2022 the National Security and Investment Act came into force, giving government powers to scrutinise certain transactions and projects on national security grounds. The Act sets out a regime under which “mandatory” notification of certain transactions (including direct and indirect acquisitions) is required within specified sectors. Following notification or “call-in” of a qualifying transaction by the government, a full national security assessment may be made, which may result in the transaction being blocked or allowed subject to certain conditions.

Upstream oil and gas transactions may be caught in instances where a qualifying entity carries out at least one of the following activities: (i) owns, operates or develops an upstream petroleum facility; (ii) enables the operation of an upstream petroleum facility; (iii) enables the development of an upstream petroleum facility (for “new” facilities only); or (iv) holds a Petroleum Act licence for an upstream petroleum facility. In each case the relevant facility must also be onshore in the UK or offshore supplying oil and gas to the UK and meet a 3 million tonne throughput threshold. Proposed reforms to the Act were proposed by the UK Government in July 2025 with a 12-week consultation period concluding on 14 October 2025. The outcome is yet to be detailed but no significant change specific to the oil and gas sector is expected.

In light of the North Sea Piper Alpha, and Gulf of Mexico Deepwater Horizon, disasters in 1988 and 2010 respectively, the UK has a stringent environmental and health and safety regime.

The key features of the environmental regime are to protect the land, air, and water and marine environments, including though the use of environmental impact assessments (EIAs) which may be required before operations are authorised.

OPRED is responsible for implementing offshore environmental legislation. Onshore environmental compliance is regulated by the Environment Agency (EA) in England, Natural Resources Wales (NRW) in Wales and the Scottish Environment Protection Agency (SEPA) in Scotland.

The HSE is Britain’s national regulator for workplace health and safety. The principle underpinning the regime is that all workers have a right to work in places where risks to their health and safety are properly controlled, including through risk assessments, training, and insurance. HSE is an executive non-departmental public body, sponsored by the Department for Work and Pensions. HSE’s Energy Division (ED) is responsible for implementing health and safety legislation for oil and gas operations. OPRED and HSE work closely together.

Central to the regime is the requirement to have a “safety case” in place that demonstrates the ability and means to control major accident risks effectively and have it accepted by HSE. The Energy Act 2023 gives the Secretary of State power to make regulations that require: (i) persons responsible for offshore installations to have an emergency plan setting out arrangements for responding to incidents which cause, or may cause, marine oil pollution; and (ii) reporting of such incidents.

The government derives revenue from oil and gas resources through the application of various taxes. There are no royalties and nor is there any form of production sharing. The taxes that apply are as follows:

• Ring Fence Corporation Tax (RFCT) – RFCT is applied to the profits of oil and gas activities in the UK in place of corporation tax (which would otherwise apply). These profits are “ring fenced” as a separate trade such that only losses relating to oil and gas activities (and not losses from any other form of activity) can be set off against the profits from those oil and gas activities. Various deductions are permitted, including in respect of capital expenditure, research and development and decommissioning. For some technically challenging fields there are various other “field allowances” available as a form of tax incentive for their development. The current rate of RFCT is 30%.

• Supplementary Charge – The Supplementary Charge is in addition to the RFCT rate as an additional charge on an oil and gas company’s ring fence profits. The rate has been amended over time and is currently 10%.

• Petroleum Revenue Tax (PRT) – PRT is a further tax on profits in addition to RFCT and the Supplementary Charge, but only applies to fields where the development was approved before 16 March 1993. PRT was permanently zero-rated from 1 January 2016, but was not abolished, and remains relevant, because some companies still require access to their tax history for carrying back trading losses and decommissioning costs.

• Energy (Oil and Gas) Profits Levy (EPL) – EPL was introduced in May 2022 to tax the extraordinary profits of oil and gas companies operating in the UK and on the UK Continental Shelf. The levy is currently set at a rate of 38%, bringing the headline rate of tax on upstream oil and gas activities to 78%. The levy has two investment allowances: the 29% investment allowance and the 66% decarbonisation investment allowance. The levy is due to expire on 31 March 2030 but will, and is expected to, end sooner if oil and gas prices fall to thresholds set out in the Energy Security Investment Mechanism (ESIM). The EPL will be replaced by a new Oil and Gas Price Mechanism (OGPM) which is revenue-based and will apply an additional tax rate of 35% above price thresholds of $90/barrel for oil and 90p/therm for gas.

In addition to these taxes there are also annual rental fees payable, calculated by reference to the area of the licence. These fees are on an increasing scale of rates per square kilometre, in order to promote relinquishment of areas that licensees are not actively exploring or developing. The NSTA is also funded by an industry levy on UKCS offshore licence holders apportioned between pre-production (11%) and in-production (89%), based on an assessment of the costs that the NSTA incurs in relation to each group. For 2025-2026, the levy is £40m.

In general, there are no such restrictions or obligations. However, the Government does have emergency powers under the Energy Act 1976, which it can use to control supply and demand of petroleum products, although the use of these powers is reserved for exceptional circumstances where there is a severe threat to fuel or other energy supplies.
Companies must also still comply with international trade regulations, such as sanctions regimes affecting exports to certain countries.

Decommissioning offshore oil and gas installations and pipelines is governed through the Petroleum Act 1998. The UK’s international obligations on decommissioning are governed principally by the 1992 Convention for the Protection of the Marine Environment of the North East Atlantic (OSPAR Convention). OPRED is the regulator with responsibility for decommissioning. The regime is underpinned by the general principles that decommissioning should aim to achieve a clear sea bed (acknowledging that this will not always be achievable given the complexities involved) and that the “polluter pays”, consistent with domestic UK law and international obligations.

Operators, licence holders, owners of offshore installations and pipelines, co-venturers, and their affiliated entities, as well as former owners and their affiliates, can be made jointly and severally liable to decommission offshore installations and pipelines. Regulatory approvals are required before decommissioning is carried out.

The UK government has the power to require those liable to carry out decommissioning to provide financial security to support their decommissioning obligations.

Licence holders and others with potential liability to carry out decommissioning customarily enter into decommissioning security agreements to make provision for future decommissioning liabilities, although entering into such agreements is not a regulatory requirement.

Tax relief is available in respect of the costs of decommissioning once those costs are incurred. The UK Government has made available decommissioning relief deeds (DRDs) to industry participants to provide certainty as to the future availability such tax relief.

The construction and operation of offshore pipelines is governed by the Petroleum Act. Under the Petroleum Act, a Pipeline Works Authorisation (PWA) issued by the NSTA is required for the construction of a pipeline. The PWA is typically awarded to the licensee that has been appointed as the operator of the licensee group and permits the licensee group to use the pipeline. The Pipeline Safety Regulations 1996 apply equally to the safe construction and operation of onshore and offshore pipelines.

Onshore pipelines are governed by the Pipelines Act 1962 (Pipelines Act) and the regulatory and consent matrix is more complex. Consultation is required with the local authorities, landowners and occupiers that will be affected by the proposed pipeline and, in most cases, a construction authorisation under the Pipelines Act will be required. For some pipelines, a development consent under the Planning Act 2008 may instead be necessary.

The UK imports LNG through three terminals, the Isle of Grain terminal near Rochester and the Dragon and South Hook terminals in Milford Haven. The UK does not export LNG, and consequently there are no LNG liquefaction plants.

The regulatory framework for onshore LNG regasification and conventional importation is set out in the Gas Act 1986. The requirements reflect the Third EU Gas Directive and the Gas (Third Party Access) Regulations 2004 (TPA Regulations). These provide for regulated third-party access based on published terms and non-discriminatory prices, although an exemption is available where the use of the facility by other users is not necessary for the operation of an economically efficient gas market or where certain specific requirements are met, including where the facility will increase the UK’s security of supply and where the level of risk is such that the investment needed to construct the facility (or new capacity) would not be available in the absence of an exemption. All of the UK’s existing LNG import terminals are exempt from the TPA Regulations. New onshore LNG development proposals will require development consent, issued by the relevant determining authority, which is likely to be the Planning Inspectorate.

In relation to offshore LNG facilities, and specifically the unloading and regasification of LNG, the relevant framework is set down in the Energy Act 2008, which was introduced to update the existing legislative framework in the UK to reflect the changed nature of the UK energy market, and is intended to facilitate the future development of offshore fixed or floating LNG receiving terminals. The developer of any new offshore LNG terminal will need both a licence to unload gas and a lease of the seabed from the Crown Estate (the body that manages the Crown’s property rights).

The construction and operation of onshore and offshore LNG facilities must also comply with the environmental and health and safety requirements which are generally applicable to petroleum installations.

Developers must obtain a licence from the NSTA for offshore gas storage, and a grant of the appropriate rights from the Crown Estate. General terms and conditions (model clauses) applicable to such licences are set out in regulations issued under the Energy Act 2008.

Onshore gas storage is permitted and regulated under the Gas Act 1986 (Gas Act) and under planning legislation such as the Planning act 2008. Rights to the relevant land are required to be obtained. Negotiated third party access rights are provided for under the Gas Act, although exemptions can be sought.

Gas storage is also regulated by generally applicable environmental and health and safety law.

The Rough facility (18 miles off the coast of East Yorkshire) is the UK’s largest gas storage facility and provides half of the UK’s total gas storage. The UK’s largest onshore gas storage facility is the Stublach facility operated by Storengy which stores gas in salt caverns in the Cheshire basin.

The gas transmission system in Great Britain is a network of high pressure gas pipelines known as the national transmission system (NTS), owned by National Gas Transmission. Distribution occurs through lower pressure, smaller, regional gas distribution networks (GDNs) or even smaller networks built to service industrial parks or housing developments. Ownership of the GDNs rests with a concentrated number of companies and owners of the smaller industrial/housing networks are known as independent gas transporters.

This system is regulated by the Office of Gas and Electricity Markets (Ofgem) under the authority of the Gas and Electricity Markets Authority (GEMA). The regime provides for third party access in a highly regulated fashion, including in respect of calculating transmission and connection charges.

The transmission and distribution system in Northern Ireland is regulated separately, by the devolved government in Northern Ireland.

In Great Britain, gas entering the wholesale gas market (including via pipelines and LNG imports) has one price for gas irrespective of its source which operates as a benchmark. This is called the National Balancing Point price of gas and is usually quoted in price per therm of gas. In the wholesale gas market, gas transporters and shippers have to abide by conditions laid out in the industry-governed Uniform Network Code, as well as relevant UK and EU legislation and conditions of the various licences.

The retail market is privatised and has been competitive since the late 1990s. Consumers can choose their gas supplier from a selection of competitive and independent market participants. Suppliers buy gas from the wholesale market or from gas producers and deliver that gas to end users. Suppliers set their own prices. Certain price caps exist.

The retail gas market in Britain is regulated by the Office of Gas and Electricity Markets (Ofgem) which is an independent National Regulatory Authority. Ofgem’s priority is to protect customers’ interests, including through the promotion of effectively functioning competitive markets.

Ofgem is governed by GEMA whose members are appointed by the Sectary of State at DESNZ. GEMA’s powers and duties are largely provided for in statute, such as the Gas Act 1986, the Electricity Act 1989, the Utilities Act 2000, the Competition Act 1998, the Enterprise Act 2002 and the Energy Acts of 2004, 2008, 2010 and 2011) as well as ruling European Community legislation in respect of energy regulation.

The current principal objective of the NSTA is to maximise the economic recovery of UK petroleum whilst accelerating the transition to cleaner energy sources and assisting the Secretary of State in meeting the net zero target. Following a consultation process in May 2020, the NSTA determined that economic recovery of oil and gas need not be in conflict with the transition to net zero, and the oil and gas industry has the skills, technology and capital to help unlock solutions required to help the UK achieve the net zero target. The NSTA Strategy relating to this objective came into force in February 2021 and was reviewed in May 2024 with no changes proposed. However, a further consultation process, known as ‘Building the North Sea’s Energy Future’, was conducted in Spring 2025 and resulted in the “North Sea Future Plan”. Alongside committing to a much more “interventionist” approach to scale up clean energy industries and responsibility manage decommissioning, a new North Sea Future Board (comprising government, industry members and trade unions) is to be formed. The NSTA will be given a new statutory objective to also consider workers, communities and supply chains in its decisions.

There are three key challenges that have been identified by the government and industry in relation to the oil and gas sector in the UK:

• Balancing the objective of maximising economic recovery of petroleum with the commitment to achieve net-zero emissions by 2050 – the UK government is pushing for a transition to cleaner energy sources whilst increasing recovery. This requires significant investment and adaptation to new technologies including, in particular, supporting oil and gas workers and technologies to develop an integrated North Sea energy supply chain in offshore wind, CCUS and hydrogen.

• Energy Security – the UK’s energy security has been questioned, particularly after the energy crisis triggered by the Russian invasion of Ukraine, continued global conflict and increased sanctions and trade restrictions. The government has been looking for ways to increase domestic production of oil and gas to reduce reliance on imports and increasingly volatile oil prices in the face of maturing fields in the North Sea, while still balancing environmental concerns.

• Investment Uncertainty – In the period following the covid-19 pandemic and the Russian invasion of Ukraine, the increased profits received by oil and gas companies were heavily scrutinised, leading to the EPL “windfall tax”. The EPL has widely been cited by industry as a deterrent to reinvestment in the UKCS, which has led some companies to deploy capital abroad or into mergers and consolidation rather than new UKCS projects. There is hope that the Oil and Gas Price Mechanism that will replace the EPL will offer increased price stability and a fair return when oil and gas prices are unusually high.

In 2019, following Parliament’s declaration of a ‘climate emergency’ and recommendations from the independent Committee on Climate Change (CCC), the government legislated for net zero greenhouse gas emissions by 2050. As part of meeting that target, the UK Government appears committed to utilise existing offshore oil and gas infrastructure and the highly skilled workforce in the North Sea to make use of an estimated 78 billion tonnes of carbon storage potential (as of November 2025). The UK Government has also developed various business models to support the economic viability of CCUS projects in the UK and, in December 2024 and April 2025 respectively, the initial two CCUS government-backed projects (ECC and Hynet) reached financial investment decisions.

In addition, the UK Hydrogen Strategy published in 2021 and updated in 2024 sets out the approach to develop a low carbon hydrogen sector focused on meeting 10GW of production capacity by 2030. Key features of the UK Hydrogen Strategy include providing up to £240 million to support the development and construction of new low carbon hydrogen production plants and the development of a Hydrogen Production Business Model, a revenue support mechanism that enables successful hydrogen producers to enter into Low Carbon Hydrogen Agreement with the government counterparty (the Low Carbon Contracts Company) who will provide top-up payments to meet agreed price thresholds, enabling price stability. Other key measures include managing declining North Sea production to maximise value, minimising greenhouse gas emissions and reducing reliance on hydrocarbon imports. Oil and gas accounts for around 72% of the UK’s total energy needs, and the NSTA Strategy has emphasised that, although the UK will be transitioning to net zero, for the foreseeable future, oil and gas will remain a crucial part of the UK’s energy mix and that the oil and gas industry’s capital, skills and technology will be vital in achieving the net zero target.