The global natural gas industry is facing a new regulatory reality in which methane performance is becoming increasingly important to market access, investment decisions and supply contracts, with jurisdictions accounting for approximately 67 per cent of global natural gas production having adopted or proposed operational rules to address emissions.
The finding, contained in a new report by the International Gas Union (IGU), highlights the growing reach of methane regulation and the challenge of navigating requirements that differ across countries, markets and supply chains.
For Nigeria, which is seeking to expand natural gas production and exports, the implications are significant. As the country strengthens its domestic emissions-reporting requirements, international buyers and regulators are placing greater emphasis on reliable evidence of methane performance. The question is whether Nigerian producers can demonstrate compliance across different regulatory systems without facing unnecessary duplication, uncertainty and additional costs.
In The Global State of Methane Regulation: Convergence or Fragmentation?, the IGU argues that governments and industry are increasingly aligned on the need to reduce methane emissions, but the systems used to measure, verify and regulate those emissions remain fragmented.
The report identifies growing convergence around measurement and operational controls, alongside persistent differences in legal obligations, verification procedures, emissions calculations and the methods used to connect production data with traded gas.
The emerging challenge is not simply how to reduce methane emissions, but how to demonstrate those reductions in ways that regulators, buyers and investors across different jurisdictions will recognise.
Methane regulation moves into the marketplace
The IGU estimates that jurisdictions accounting for approximately 67 per cent of global natural gas production have adopted or proposed operational rules addressing methane emissions. The figure includes both enacted and proposed measures; it does not mean that all the production concerned is already subject to identical or fully enforceable requirements.
The report also cites a 10 per cent decline in global average upstream methane intensity between 2019 and 2025, drawing on the International Energy Agency’s Global Methane Tracker 2026.
The improvement concerns methane emissions relative to production, rather than a corresponding decline in absolute emissions. That distinction is important in assessing progress: emissions intensity can fall even when total emissions do not decline by the same proportion.
Against this backdrop, the IGU identifies five broad approaches through which methane policy is shaping the gas industry: market-access requirements, domestic operational controls, fiscal instruments, buyer-led procurement frameworks, and mandatory emissions reporting and climate-governance systems.
These approaches differ in scope and effect. Operational rules typically require measures such as leak detection and repair, restrictions on venting and flaring, equipment standards and record-keeping. Fiscal instruments place a cost on emissions, while reporting frameworks require covered entities to quantify and disclose greenhouse-gas emissions.
Buyer-led initiatives operate through commercial relationships, with purchasers seeking information about suppliers’ methane performance and management practices.
Market-access regulation introduces another dimension by linking requirements in an importing jurisdiction to supply chains beyond its borders.
The European Union’s Methane Regulation, adopted in 2024, is a prominent example. Its import provisions extend methane-related requirements into international oil and gas supply chains, increasing the importance of reliable emissions data for suppliers seeking access to the European market.
Methane management is consequently becoming more than an environmental reporting exercise. It is increasingly connected to the evidence suppliers may need to demonstrate when competing for buyers, negotiating contracts and securing investment.
Nigeria’s regulatory transition comes into focus
Nigeria is already strengthening its domestic approach to methane management.
The Nigerian Upstream Petroleum Regulatory Commission (NUPRC) issued a directive in April 2026 requiring upstream operators to move towards more standardised, measurement-based methane and greenhouse-gas reporting.
Under the timetable described in the directive, operators are to adopt at least IPCC Tier 2 methodologies from the third quarter of 2026 and transition to Tier 3, or equivalent high-level measurement-based systems, by January 2027.
The changes are intended to improve the transparency, consistency and credibility of emissions inventories and strengthen the basis for methane mitigation across upstream operations.
Their significance extends beyond domestic regulatory compliance. As international buyers increasingly seek evidence of methane performance, the quality of Nigerian producers’ emissions data could become an important consideration in commercial negotiations and investment decisions.
Implementing the requirements, however, will involve more than submitting revised inventories. Operators need appropriate measurement technologies, technical expertise, reliable data systems and credible verification procedures. Regulators must also be able to assess the quality of the evidence and ensure that reported emissions lead to corrective action where necessary.
The IGU report identifies these practical considerations as central to making different methane regimes work together.
For Nigeria, the task is therefore twofold: to demonstrate meaningful progress in reducing methane emissions and to ensure that its reporting and verification arrangements can satisfy the requirements of the markets it seeks to serve.
The report does not establish that Nigerian gas exports face automatic exclusion from particular markets. Nor does it quantify a uniform new compliance cost for Nigerian producers. Those outcomes will depend on the applicable rules, the evidence required, the arrangements adopted by individual operators and the markets in which their gas is sold.
But the direction of travel makes the issue increasingly relevant to Nigeria’s gas ambitions.
The search for common standards
A central reference point in the emerging regulatory landscape is the Oil and Gas Methane Partnership 2.0 (OGMP 2.0), led by the United Nations Environment Programme.
The framework promotes increasingly detailed emissions reporting, progressing from broader estimates towards source-level quantification. Its Level 5 approach adds site-level measurement and reconciliation with source inventories, helping operators investigate discrepancies between measured emissions and reported estimates.
The IGU sees such frameworks as important foundations for greater international compatibility. It cautions, however, against treating technical alignment as automatic legal equivalence.
The EU regulation establishes binding obligations. The Coalition for LNG Emission Abatement towards Net-zero (CLEAN) facilitates information-sharing between liquefied natural gas buyers and suppliers, while MiQ provides a voluntary methane-certification framework.
These initiatives can reinforce one another, but they serve different purposes. Participation in a voluntary programme or a commitment to adopt a particular reporting standard does not, by itself, demonstrate compliance with every applicable regulatory requirement.
That distinction matters for companies operating across multiple markets. Even where the underlying emissions data are similar, different authorities and buyers may require different reporting formats, verification arrangements or calculations.
The result could be duplicated work and additional compliance complexity without a corresponding improvement in the quality of emissions information.
The IGU’s proposed solution is greater mutual recognition: regulators should accept credible, independently verified evidence produced under equivalent systems, with additional requirements reserved for genuine gaps.
Such recognition would not eliminate the need for effective oversight. Its purpose would be to make compliance more consistent without weakening the standards used to assess methane performance.
The question is how to achieve that balance: reduce duplication while preserving the integrity of emissions data, independent verification and enforcement.
Tracing emissions through complex gas supply chains
One of the most difficult questions concerns the relationship between methane emissions at the production stage and the gas eventually delivered to an importer.
International gas supply chains can involve multiple producers, traders, processing facilities and commercial transactions. Establishing a direct link between an importing company and the original producer may therefore be difficult.
A European Commission recommendation issued in July 2026 addresses this challenge by identifying two approaches to demonstrating compliance: trace-and-claim and certification.
Trace-and-claim follows relevant information and quantities through commercial transactions. Certification allows compliance attributes to be certified separately from the physical commodity and subsequently used to demonstrate compliance, subject to the applicable criteria and assessment by the relevant competent authority.
The distinction matters because a workable compliance system must accommodate complex trading arrangements without sacrificing accountability.
The IGU argues that physical segregation should not necessarily be the only means of establishing credible attribution. However, alternative systems must be supported by auditable allocation methods, reliable records and safeguards against duplicate claims.
For Nigerian LNG and other gas exports, the practical question is how production-level emissions information will be connected to commercial deliveries and which forms of evidence will be accepted by buyers and regulators.
Clarity on these arrangements could help producers plan compliance investments, assess potential market requirements and negotiate long-term contracts with a better understanding of their obligations.
Detection must lead to action
The report also highlights the role of satellite monitoring and international initiatives in identifying major methane emission events.
The United Nations Environment Programme’s Methane Alert and Response System (MARS) uses satellite observations to identify and attribute significant emissions, notify relevant governments and operators, and encourage investigation and corrective action.
Such systems can improve the ability to identify major emission events that might otherwise go undetected. But observation alone does not establish that emissions have been eliminated.
The IGU cites a UNEP assessment published in 2025 which found that responses had been recorded for 12 per cent of MARS alerts during the period assessed.
That figure concerns responses to alerts, not the proportion of emissions eliminated, and should not be interpreted as a measure of performance in 2026.
The wider lesson is that detection must be followed by investigation, repair and verification. Regulators and operators need to establish not only whether an emission event was identified, but also whether it was addressed and whether the corrective action was effective.
For gas-producing countries, this places a premium on operational capacity, enforcement and reliable evidence of results. It also underlines the difference between possessing sophisticated monitoring technology and achieving measurable emissions reductions.
IGU proposes an international framework
To bridge the gaps between regulatory systems, the IGU proposes five building blocks for an international measurement, monitoring, reporting and verification (MMRV) framework.
The first is a common measurement core that would allow recognised reporting approaches to be used across jurisdictions. The second is a system for mutual recognition of qualified verifiers, supported by expanded verification capacity.
The third is greater compatibility in emissions-intensity calculations, including transparent treatment of differences in boundaries, denominators and allocation methods.
The fourth is a shared data structure for tracking emissions information through supply chains, allowing producer declarations, certification records and relevant monitoring evidence to be used across different systems.
The fifth is a response protocol for major methane emission events, with progress assessed through evidence of corrective action rather than acknowledgement of alerts alone.
The proposed framework would build on existing systems rather than introduce another parallel reporting regime.
The IGU also argues that regulators should publish clear methodologies and transition arrangements before related obligations or penalties become enforceable, giving suppliers and buyers sufficient certainty to make investment and contracting decisions.
Its position reflects a central tension in methane policy: how to improve emissions accountability while avoiding unnecessary duplication and uncertainty in a global industry whose production, infrastructure and trading arrangements differ considerably between regions.
For regulators, the challenge is to ensure that interoperability does not become a route around substantive requirements. For industry, it is to demonstrate that equivalent evidence can deliver the same level of confidence without requiring companies to reproduce the same information repeatedly.
The real test for Nigeria’s gas ambitions
For Nigeria, the implications extend beyond the adoption of new reporting requirements.
The country will need to demonstrate that its emissions inventories are credible, its measurement methods are consistently applied, its verification arrangements are robust and identified methane releases are addressed.
It will also need clarity about how its domestic systems relate to the requirements of prospective export markets and whether evidence produced under Nigerian rules can be recognised by international buyers and regulators.
These questions deserve closer scrutiny from regulators, producers and buyers. How prepared are Nigerian operators for the transition to more detailed measurement? Is there sufficient independent verification capacity? What investments will be required? And how will international buyers assess the evidence supplied by Nigerian producers?
The IGU report does not answer all these questions, nor does it establish that regulatory fragmentation has already restricted Nigerian exports or increased costs across the industry. It does, however, identify a landscape in which methane performance and the credibility of supporting evidence are becoming increasingly important to commercial decisions.
The challenge for Nigeria is to ensure that domestic implementation keeps pace with international expectations while allowing producers to understand and plan for the requirements of different markets.
Ultimately, the success of global methane regulation will depend on more than how many jurisdictions introduce rules. It will depend on whether those rules deliver verifiable emissions reductions, whether regulators can enforce them effectively and whether credible evidence can be recognised across borders.
For Nigeria, that is the emerging test: not simply whether its gas industry can report methane emissions, but whether it can demonstrate measurable progress in reducing them—and prove that progress to the markets it wants to reach.
