The fossil fuel sector in Central and South America emitted just under 8 million tonnes (Mt) of methane in 2025, around half of which was from oil and gas facilities in Venezuela. Oil and gas facilities are the main sources of methane emissions in Venezuela, Argentina and Brazil, whereas in Colombia emissions are split roughly evenly between coal mining and oil and gas activities. In Venezuela, the upstream methane emissions intensity of oil and gas operations is nearly six times the global average, and flaring intensity is around 12 times higher. The intensities of operations in Argentina and Ecuador are around twice the global average, while Colombia sits slightly above and Brazil performs slightly below.

Measurement data is limited across Central and South America, reflecting the fact that much of the region’s oil and gas production is located offshore or in areas with persistent cloud cover, where satellite monitoring is challenging. Several recent initiatives aim to address these gaps. Direct measurements of gas cooking stoves have revealed emissions far above the default level set by the Intergovernmental Panel on Climate Change (IPCC). Meanwhile, work integrating satellite observations with Colombia’s national methane inventory has identified underreporting in the energy sector and offers a model for improving national inventories. The United Nations Environment Programme’s International Methane Emissions Observatory (IMEO) is currently conducting a study on the sources of methane emissions in Colombia and the Climate and Clean Air Coalition (CCAC) is supporting efforts to strengthen monitoring, reporting and verification in that country’s mining sector.

All of the region’s major energy producers have signed the Global Methane Pledge, except for Venezuela. Colombia is the only country with an explicit strategy for reducing methane emissions as well as regulations to limit emissions from oil and gas operations. These include explicit technology standards and restrictions on flaring and venting, as well as a requirement for biannual leak detection and repair (LDAR). Brazil is developing regulations to reduce methane emissions from the oil and gas sector, expected by 2026. In its updated Nationally Determined Contribution (NDC), Chile has set a target to reduce methane emissions by 10% by 2035, relative to an expected peak in 2025. At the subnational level in Argentina, the province of Chubut  prohibits methane venting and has established monitoring, measurement, reporting and verification (MMRV) and LDAR requirements. The province of Neuquén has also established a greenhouse gas (GHG) monitoring and mitigation programme for the hydrocarbon sector that mandates emissions reporting, with a view to developing future regulations. Argentina, Brazil and Colombia have also designated points of contact to receive notifications from the IMEO’s Methane Alert and Response System (MARS), including seven subnational contact points in Argentina. All the region’s major producers also participate in the Latin American and Caribbean Methane Emissions Observatory (OEMLAC), which promotes a coordinated approach to reducing methane emissions.

Many national oil companies (NOCs) in the region participate in the Oil and Gas Decarbonisation Charter (OGDC) or the Oil and Gas Methane Partnership (OGMP 2.0), including Petrobras (Brazil), ENAP (Chile), Ecopetrol (Colombia) and EP Petroecuador (Ecuador).

Argentina, Brazil and Ecuador have policies to restrict flaring, although these have had mixed success. From 2015 to 2025, flared volumes plateaued in Brazil, but they increased by 70% in Ecuador and more than tripled in Argentina. Stopping all non-emergency flaring and venting is the single-most effective policy measure for reducing methane emissions in the oil and gas sector. Many uses exist for gas that is currently flared, including: distribution to consumers via existing networks, or as compressed natural gas (CNG) or liquefied natural gas (LNG); power generation near oil and gas sites and/or fuel for on-site heating at plants; and reinjection to maintain reservoir pressure.

Under stated policies, methane emissions in Central and South America would decline by around 15% by 2030, and by more than 30% by 2035. Applying currently available methane abatement technologies today would lower emissions by 75%, with around half of these reductions coming from the oil and gas sector in Venezuela. Almost 70% of these emissions reductions could be achieved at no net cost to producers.

China is the world’s largest emitter of methane, with coal mines accounting for most energy-sector emissions. China produces and consumes around half the global supply of coal. While energy demand and fossil fuel production have risen in tandem, methane emissions have risen at a slower pace and even decreased slightly from 2024 to 2025. In 2025, the fossil fuel sector in China emitted just over 25 million tonnes (Mt) of methane, of which almost 22 Mt came from coal mines (including abandoned underground mines that can continue emitting methane for years after closure).

Oil and gas operations in China have a lower upstream methane intensity than the global average, and its coal mines also perform better than average. Deep mines that produce coking coal are linked to higher intensities and present key opportunities for abatement.

China is also the world’s largest individual importer of oil, gas and coal, with annual methane emissions from these imports estimated to be around 11 Mt. Of these, 40% are linked to imports of crude oil from Russia, Venezuela and the Middle East.

China does not participate in the Global Methane Pledge, but it has an action plan to cut methane emissions. This includes a target of 6 billion cubic metres (bcm) of coal mine gas use annually and prioritises methane recovery in the oil and gas sector through measures such as leak detection and repair requirements (LDAR), and limits on flaring. China’s action plan also emphasises methane monitoring, reporting and verification systems. China’s latest Nationally Determined Contribution (NDC) identifies improved coal mine gas utilisation as a measure to support its economy-wide target of reducing net greenhouse gas emissions  7-10% below peak levels by 2035.

China has introduced several policies and regulations for controlling methane emissions from fossil fuels. The Ministry of Ecology and Environment has strengthened the coal mine methane emissions standard, requiring utilisation of gas with methane concentrations of 8% or more (down from 30% previously)  and extraction volumes above 10 cubic metres per minute. Oil and gas operators are subject to limits on flaring and venting.

PetroChina participates in the Oil and Gas Decarbonization Charter (OGDC), and China Gas Holdings Limited is a member of the Oil and Gas Methane Partnership (OGMP) 2.0. Several Chinese oil and gas companies have also set up a Methane Control Alliance to promote the sharing of technology and expertise to reduce emissions.

Under stated policies, methane emissions in China would fall by 10% by 2030, and by more than 20% by 2035. Applying currently available methane abatement technologies today would lower emissions by more than 50%, mainly from the coal sector. More than 90% of the emissions reductions in the oil and gas sector could be achieved at no net cost to producers, compared with about 30% in the coal sector.

The fossil fuel sector in the Eurasian region was responsible for more than 24 million tonnes (Mt) of methane emissions in 2025. Around 60% of these emissions originated in Russia, where the oil and gas sector released just under 10 Mt and coal mines nearly 4 Mt of methane.

Upstream methane intensities for oil and gas are high in several countries, with Turkmenistan having one of the highest intensities in the world, on par with Venezuela. Methane intensity in Azerbaijan is near the global average, while Kazakhstan is the only producer in the region with below-average intensity. Emissions events large enough to be detected by satellites are common in Turkmenistan, representing more than a third of all oil- and gas-related observations from the Methane Alert and Response System (MARS). While satellite coverage of Russia is very limited – due to ice, snow and prolonged periods of limited daylight – 256 methane plumes were observed over its territory in 2025.

All major emitters in Eurasia participate in the Zero Routine Flaring by 2030 Initiative. Russia is the only producer that is not part of the Global Methane Pledge. In the latest Nationally Determined Contribution (NDC) submissions, Kazakhstan has set a target to reduce fugitive methane emissions from the energy and waste sector by 42% by 2035, while Uzbekistan has committed to reduce methane emissions by 30% by 2030. In addition, Russia, Kazakhstan, Uzbekistan, Azerbaijan and Armenia have identified at least some measures to mitigate methane emissions in their NDCs. Azerbaijan’s NDC highlights the implementation of leak detection and repair (LDAR) and technological upgrades to reduce emissions. Kazakhstan’s NDC also identifies LDAR programmes as well as a requirement for 98% flaring efficiency.

Few countries in Eurasia directly regulate methane emissions from the fossil fuel industry. Russia and Kazakhstan impose financial penalties on methane emitters, but these are quite low and exemptions apply. The Fossil Fuel Regulatory Programme (FFRP) is supporting Kazakhstan in the development of regulations that include LDAR, equipment standards and a framework for monitoring, reporting and verification (MRV).

Many national oil companies from the region participate in the Oil and Gas Decarbonisation Charter (OGDC) or the Oil and Gas Methane Partnership (OGMP) 2.0, including SOCAR (Azerbaijan), KazMunayGas (Kazakhstan) and Uzbekneftegaz (Uzbekistan).

Around 40% of Eurasia’s methane emissions from oil and gas in 2025 could have been avoided through measures that would have ultimately paid for themselves. Leak detection and repair (LDAR) is the single-most effective measure for reducing fossil fuel methane in the region and it is highly cost-effective: 80% of the emissions savings from LDAR would have come at no net cost to operators. This includes abatement related to rapid-response systems for addressing large emissions events detected by satellite.

Under stated policies, methane emissions in Eurasia would fall by 15% by 2030, and by 20% by 2035. Applying currently available methane abatement technologies today would lower total emissions by almost 70%, mainly from the oil and gas sector in Russia, and almost half of those reductions could be achieved at no net cost to producers.

Most of the methane emissions from fossil fuels used in Europe are tied to imports. In 2025, methane emissions from the supply chain for oil, gas and coal imports are estimated to be around 7 million tonnes (Mt), almost double those from Europe’s domestic fossil fuel sector.

Around 50% of the fossil fuel methane emissions that occur within Europe come from the oil and gas sector, mostly from downstream operations, while the remainder originates from coal mines, primarily in Poland and Ukraine. Upstream oil and gas operations are the main source of emissions in the United Kingdom and Romania, while abandoned facilities account for almost a quarter of oil and gas emissions in Romania. Norway and the Netherlands have the lowest upstream intensities in the world, while most other countries in the region perform near the global average.

All major producers in Europe have signed the Global Methane Pledge. Starting in 2025, certain provisions of the European Union Methane Regulation began to take effect, including requirements pertaining to mandatory monitoring and reporting of source-level emissions, establishment of leak detection and repair (LDAR) programmes, and restrictions on venting and flaring. As of 5 August 2025, EU Member States are required to establish rules on penalties for non-compliance under the regulation. However, few Member States have set up penalty regimes to date. They are also required to publish an inventory of inactive, plugged and abandoned wells. As of May 2025, importers of oil, gas and coal into the European Union are also required to provide qualitative information on the origin and transport route of imported products, as well as on the application of monitoring, measurement, reporting and verification (MMRV), LDAR and other measures to control methane emissions. EU energy ministers have endorsed certification and trace-and-claim approaches as viable means of demonstrating compliance with upcoming import requirements. Guidance to support compliance by importers and producers in non-EU countries has also been published.

In 2024, the European Union also announced a Methane Abatement Partnership Roadmap, with a blueprint for cooperation between fossil fuel importing and exporting countries aimed at reducing methane emissions.

Under stated policies, methane emissions in Europe would fall by 30% by 2030, and by more than 40% by 2035. Applying currently available methane abatement technologies today would lower emissions by more than 60%, of which around 40% could be achieved at no net cost to producers. Coal mine methane utilisation in Poland and Ukraine alone accounts for almost 35% of the potential reductions.

Fossil fuel operations in the Middle East and North Africa emitted around 20 million tonnes (Mt) of methane in 2025, almost all of it from oil and gas activity. Flaring is a leading source of emissions, accounting for just under a quarter of the total. Performance varies widely: upstream methane intensities in Libya, Algeria and Iran are three to five times higher than Saudi Arabia, Qatar and the United Arab Emirates – all of which perform better than the global industry average.

Emissions events large enough to be detectable by satellite are common in the Middle East and North Africa, representing almost 40% of observations linked to oil and gas by the Methane Alert and Response System (MARS). The region’s geography, with minimal cloud cover and open landscapes, ensures good satellite coverage. In 2025, satellites detected more than 730 emission events linked to oil and gas in Iran, around 630 in Algeria, and more than 80 in Egypt. A satellite campaign supported by the Oil and Gas Climate Initiative (OGCI) with data from GHGSat studied 12 facilities and found that incomplete combustion from burning pits was the main source of emissions in Algeria and Egypt, followed by gas lift system vents and equipment venting. A previous campaign in Iraq found flaring and direct venting as major sources.

All countries in the region participate in the Global Methane Pledge except for Algeria, Iran and Syria. Many also take part in the Zero Routine Flaring by 2030 Initiative. However, fewer countries have developed regulations focused on limiting oil and gas methane emissions. In its latest Nationally Determined Contribution (NDC), Qatar has defined a target to achieve near-zero methane emissions across all assets in the oil and gas sector, including by mandating Oil and Gas Methane Partnership (OGMP) 2.0 reporting and leak detection and repair (LDAR) programmes. Qatar also has technology standards, as does Kuwait, which also requires LDAR in the upstream sector. The NDCs of Saudi Arabia and the United Arab Emirates also include measures on methane abatement. Egypt and Iraq have announced that they are currently working on developing new regulations. Egypt is also preparing a roadmap for reducing methane emissions. In 2025, Jordan and Libya also designated points of contact for receiving notifications of large emissions from the International Methane Emissions Observatory’s MARS programme, joining Algeria, Bahrain, Iraq, Kuwait and Oman. The International Energy Agency (IEA) is working alongside the Clean Air Task Force (CATF) and Climate and Clean Air Coalition (CCAC) to support Iraq’s efforts to mitigate oil and gas emissions.

Flaring and venting restrictions are common in most countries, but flared volumes have increased by around 20% since 2015. Many of the region’s national oil companies have joined the Oil and Gas Decarbonisation Charter (OGDC) or the Oil and Gas Methane Partnership (OGMP) 2.0, including ADNOC (United Arab Emirates), the National Oil Corporation (NOC) of Libya, Saudi Aramco (Saudi Arabia), Bapco Energies (Bahrain) and Petroleum Development Oman.

Three countries – Iran, Iraq and Algeria – together produce around 10% of the world’s oil but account for 40% of global flaring volumes and related methane emissions. Most flares in these countries operate on a continuous basis and many are located within 20 kilometres of existing gas pipelines.

Under stated policies, methane emissions in the Middle East and North Africa would fall by 25% by 2030, and by more than 30% by 2035. Deploying currently available methane abatement technologies today would lower emissions by 80%, with around 60% of these reductions achievable at no net cost to producers. In some countries, however, access to these technologies remains challenging – due to sanctions restricting Iran’s access to key equipment, for example, and Iraq’s lack of civil infrastructure to utilise captured methane.

North America’s fossil fuel sector emitted almost 24 million tonnes (Mt) of methane in 2025, of which just under 85% came from the United States. North American unconventional oil and gas production accounted for 12 Mt, around half of the total. Major sources of emissions include tanks that vent to the atmosphere, leaks and natural gas-powered pneumatic devices that release methane during normal operations.

Canada has the lowest upstream methane intensity in the region, while the United States is close to the global average and Mexico sits above it. Airborne measurements indicate that intensities in the United States can vary by an order of magnitude between producing basins. Since 2022, the Methane Alert and Response System (MARS) has tracked 1 300 super-emitting oil and gas-related events in the United States – about 10% of the global total – with around 461 classified as “actionable,” meaning the source was identified and considered still likely to be emitting.

Canada has recently amended its federal regulations on methane emissions from upstream oil and gas facilities. The amended regulations set higher standards for fugitive emissions management and repairs and prohibit venting apart from exceptional circumstances. The amendments also offer an alternative compliance pathway to facilities that meet a prescribed methane intensity threshold by permitting them to design their own abatement approach. Canada’s latest Nationally Determined Contribution (NDC) restates its goal of reducing methane emissions from the oil and gas sector by 75% by 2030 compared to 2012. The United States has deferred the deadlines for compliance with various regulatory requirements under the Environmental Protection Agency (EPA)’s Final Rule for Oil and Natural Gas Operations until 22 January 2027. Congress also overturned an EPA rule implementing the “Waste Emissions Charge” mandated by the Inflation Reduction Act. However, policies and support for emissions reductions remain in place at state level, including measures such as flaring restrictions.

Mexico is now implementing its existing regulations on methane to meet its international commitments. Its latest NDC reaffirms Mexico’s target to reduce methane emissions by 30% by 2030 compared to 2020 and eliminate routine gas flaring, in accordance with PEMEX’s 2024 Sustainability Plan. It also sets out Mexico’s commitment to reduce fugitive emissions in oil and gas production through best operating practices and detection and mitigation technologies.

Under stated policies, methane emissions in North America would fall by almost 20% by 2030, and plateau to 2035. Applying currently available methane abatement technologies today would lower emissions by 75%. However, less than 15% of these reductions could be achieved at no net cost to producers. This share is much lower than in other regions because relatively low natural gas prices in North America mean that the cost of abatement often exceeds the market value of the methane that can be recovered and sold.

The fossil fuel sector in South and Southeast Asia emitted around 13 million tonnes (Mt) of methane emissions in 2025, with more than 60% originating from coal mines and the rest from oil and gas operations. India and Indonesia were the biggest emitters. Methane emissions in the region have risen in recent years, driven by rising energy demand and fossil fuel production. However, across the region, both fossil fuel production and associated methane emissions are expected to start declining in the coming years.

Upstream methane intensities for oil and gas in Southeast Asia are around the global average, with lower intensities in Malaysia and Brunei, where operations are largely offshore. In India and Pakistan, methane intensities are around twice the global industry average. Methane intensities from coal production are particularly high in Viet Nam – almost four times the global average – owing to the country’s geology and limited coal mine methane capture. In India and Indonesia, intensities are below the global average, while in Mongolia, coal intensity is higher. Across the region, most emissions come from surface mines, where abatement options are more limited.

All major emitters in the region participate in the Global Methane Pledge except for India and Thailand – although Thailand has identified some opportunities for lowering methane emissions, such as minimising fugitive emissions from oil and gas activity. Thailand also granted in-principle approval to the Draft Climate Change Act that inter alia mandates measurement, reporting and verification (MRV) for regulated entities, including in the energy sector.

Bangladesh and Viet Nam have developed action plans to address methane emissions with quantified reduction targets. Viet Nam’s plan encourages the collection of associated gas from oil operations, investment in leak detection and repair (LDAR), and methane drainage and recovery before and during underground coal mining. Viet Nam also has a policy that includes provisions on emissions monitoring and reporting. Bangladesh’s methane emissions reduction plan refers to reducing leaks and recovering vented associated gas. In its updated Nationally Determined Contribution (NDC), Bangladesh has set a conditional target of 70% reduction in fugitive emissions from gas leakages in the energy sector by 2035. Indonesia has a rule to increase the utilisation of associated gas. In addition, Indonesia’s updated NDC recognises reduction in flaring and venting from the upstream oil and gas sector and reduction in fugitive emissions from coal mining as mitigation measures for the energy sector. The Philippines is developing policies for methane abatement with a focus on improving measurement of methane emissions and has also made efforts to develop a National Action Plan and Methane Roadmap.

Over the past year, the Association of Southeast Asian Nations (ASEAN) has launched a range of regional initiatives to address energy sector methane emissions. For instance, the ASEAN Centre of Energy (ACE) convened a high-level regional policy dialogue, jointly published a methane management roadmap for the oil and gas sector, and launched the Omega project with the Climate and Clean Air Coalition (CCAC)  to identify gaps in addressing methane emissions in the region and enhance the capacity of national oil companies  (NOCs)  to achieve methane abatement. 

Many NOCs from the region participate in the Oil and Gas Decarbonisation Charter (OGDC) or the Oil and Gas Methane Partnership (OGMP) 2.0, including ONGC (India), PETRONAS (Malaysia), Pertamina (Indonesia), PPL (Pakistan) and PTTEP (Thailand). PETRONAS, Pertamina, and PTTEP also spearhead the ASEAN Energy Sector Methane Leadership Programme (MLP) that is intended to enhance the capacity of NOCs to manage and reduce their methane emissions.

Under stated policies, methane emissions in South and Southeast Asia would fall by 10% by 2030, and by almost 20% by 2035. Applying currently available methane abatement technologies today would lower emissions by more than 50%, of which 60% of reductions could be achieved at no net cost to producers.

In 2025, fossil fuel operations within sub-Saharan African countries emitted around 5 million tonnes (Mt) of methane, of which around 70% came from oil and gas operations and the remainder from coal mines (mainly from South Africa). Methane emissions from fossil fuels in the region fell early in the decade but have since risen again, in line with fluctuations in oil and gas activity in Nigeria, the region’s largest emitter. Emissions from the traditional use of biomass account for almost 50% of energy-related methane in sub-Saharan Africa.

Upstream methane intensity is high across many of the region’s leading oil and gas producers. In Nigeria, Congo and Gabon, intensities are two- to three-times the global industry average. Several countries have the potential to increase their production significantly in the coming years, including Nigeria, Senegal and Uganda.

Apart from South Africa, all major emitters in the region participate in the Global Methane Pledge. Many also take part in the Zero Routine Flaring by 2030 Initiative, including Angola, Nigeria, Congo and Gabon. Some countries have developed action plans to reduce methane emissions, including Côte d’Ivoire, Ghana and Nigeria, with Senegal developing its own. Côte d’Ivoire, Ghana and Nigeria have also established targets for methane emissions reduction. In its latest Nationally Determined Contribution (NDC), Côte d’Ivoire has communicated a target of 50% reduction in fugitive methane emissions from the energy sector by 2035. In 2025, Angola also designated a contact point for receiving notifications of large emissions from the International Methane Emissions Observatory (IMEO)’s Methane Alert and Response System (MARS), joining Nigeria, South Africa and Mozambique.

Nigeria has developed methane regulations specifically for the oil and gas sector. These include emissions and equipment standards, requirements for leak detection and repair (LDAR), fiscal incentives for the utilisation of associated gas and measurement and reporting obligations. In its latest NDC, Nigeria commits to achieving zero routine gas flaring by 2030 and a reduction in fugitive emissions (leaks and venting) from the oil and gas industry of 60% by 2035 and 95% by 2050. Nigeria is now implementing these regulations to meet those commitments. Ghana is developing regulations and technical guidelines to curb oil and gas methane emissions. Senegal is also drafting rules that set standards for emissions measurement and control equipment, and that govern the release of combustion products into the atmosphere.

Several other countries in the region also limit flaring, including Gabon and Equatorial Guinea. Angola’s NDC also commits to a reduction of 394 million standard cubic feet per day (MMSCF/day) in flaring at oil fields by 2035. Many national oil companies (NOCs) participate in the Oil and Gas Decarbonisation Charter (OGDC) or the Oil and Gas Methane Partnership (OGMP) 2.0, including Sonangol (Angola), NILEPET (South Sudan) and NAMCOR (Namibia). Nigeria LNG has achieved the OGMP 2.0 Gold Standard Reporting Level 5, while NNPC, the national oil company, is also a member of the scheme.

Under stated policies, methane emissions in Sub-Saharan Africa would fall by around 35% by 2030, and by 40% by 2035. Applying currently available methane abatement technologies today would lower emissions by 65%, of which nearly 70% could be achieved at no net cost to producers.

Fossil fuel operations in the Asia Pacific region (excluding China and South and Southeast Asia) released more than 2 million tonnes (Mt) of methane in 2025. Around 75% of those emissions came from coal production, with the remainder from the oil and gas sector. Australia’s coal sector alone emitted 1.7 Mt of methane in 2025, particularly from underground and open-cut mines in Queensland and New South Wales. Most of the methane emissions in Japan and Korea are tied to imports since these countries have little domestic fossil fuel production. In 2025, upstream methane emissions associated with oil and gas imports are estimated at around 2 Mt, seven times those from Japan and Korea’s domestic oil and gas sectors.

Australia is the fourth-largest coal producer in the world but has an emissions intensity that is roughly half the global average.

All major emitters in the region participate in the Global Methane Pledge. In 2025, Australia released an action plan to reduce emissions from its resources sector, including coal, oil and gas. The plan includes measures to cut methane emissions, such as reducing fugitive emissions, expanding pre-drainage in coal mines, abating ventilation air methane (VAM), and improving detection and measurement technologies. Korea’s methane roadmap targets a 30% reduction in methane emissions by 2030 from 2020 levels through a fugitive emissions management plan, improved measurement, reporting and verification (MRV) systems, and support for methane abatement technologies, among other measures. Japan is also developing a roadmap to cut emissions from the liquefied natural gas (LNG) supply chain. In 2025, the Japan- and Korea-supported Coalition for LNG Emission Abatement towards Net-zero (CLEAN) released project-level data on the methane intensity and methane management practices at 22 projects that supply the two countries.

Under stated policies, methane emissions in the Asia Pacific region would fall by more than 25% by 2030, and by more than 30% by 2035. Deploying currently available methane-abatement technologies today would lower emissions by 50%, largely from Australian fossil fuel operations, particularly coal mines. Around 75% of emissions cuts in the oil and gas sector can be achieved at no net cost to producers, compared with just under 10% in the coal sector.