Satellites Caught the Oil Industry Leaking 50% More Methane Than It Reported. The Fix Would Pay for Itself.
MethaneSAT and GHGSat surveyed thousands of oil and gas facilities from orbit. Measured emissions ran 50% above industry-reported inventories. At international gas prices, the full fix would pay for itself. The industry is choosing to waste billions per year in sellable product.
One hundred and forty-five million tonnes. According to the IEA's Global Methane Tracker 2025, that is how much methane the energy sector released in 2024. Oil operations contributed 45 million tonnes. Natural gas added 35 million. Coal pushed 40 million more. Downstream pipelines and end-use equipment leaked another 15 million on top.
Those numbers come largely from inventories: spreadsheets compiled by companies and governments, built on emission factors and activity data. For decades, that was the best anyone could do.
It is not anymore.
Two Satellites, 3,114 Facilities, and a Very Bad Report Card
In February 2026, a team led by Luis Guanter published the first comprehensive results from MethaneSAT's 15-month mission in Atmospheric Chemistry and Physics. The EDF-funded satellite, which operated from March 2024 through June 2025, carried a spectrometer sensitive enough to detect methane at 100-by-400-meter resolution across a 200-kilometer swath.
What it found was not reassuring. Turkmenistan's South Caspian basin showed persistent super-emitters visible on pass after pass. Five sources in Venezuela's Maturin basin were simultaneously emitting more than 5 tonnes per hour each. Three sources in Iran's Zagros Foldbelt exceeded 20 tonnes per hour. In the Permian Basin of west Texas, MethaneSAT recorded persistent, not intermittent, super-emissions from the Midland sub-basin.
A second dataset arrived two months earlier. In December 2025, Dylan Jervis and colleagues at GHGSat published in Science the results of surveying 3,114 individual oil, gas, and coal facilities worldwide. Their satellite constellation detected 8.3 million tonnes of methane per year from those sites alone. Coal facilities emitted detectable plumes 48% of the time. Oil and gas facilities emitted only 16% of the time, but were far more intense when they did.
Taken together, satellite-measured methane from oil and gas operations runs roughly 50% above what standard emission inventories report. When the IEA revised its own downstream estimates, new satellite data from Kayrros forced a correction from 8 million to 13 million tonnes for pipeline emissions alone.
Why the Gap Matters
Methane drives approximately one-third of warming since preindustrial times (IPCC AR6). Over 20 years, each tonne traps 80 times more heat than CO2. Its short atmospheric lifetime (~12 years) means cutting methane delivers faster cooling than cutting any other greenhouse gas.
Nearly 160 countries signed the Global Methane Pledge at COP26, committing to cut collective methane 30% below 2020 levels by 2030. Detailed implementation plans on the books would cut roughly 15%, not 30%.
Satellite data makes this worse. If actual oil and gas methane emissions are 50% above the inventories used to set the 2020 baseline, the real tonnage requiring elimination is 50% larger too. A 30% pledge against a 77-million-tonne baseline means cutting 23 million tonnes. Against the satellite-corrected ~115 million tonnes, it means cutting 35 million. Countries are working from a map that understates the distance by a third.
What the Gas Is Worth
When methane leaks from a wellhead or pipeline, it is money floating into the sky. According to IEA methane abatement analysis, around 30% of all fossil fuel methane emissions could be eliminated at zero net cost based on 2024 energy prices, with the share higher for oil and gas specifically, because the captured gas sells for more than the repair equipment costs.
Run the numbers. One million tonnes of methane contains approximately 49.6 billion cubic feet of gas, yielding about 49.6 million MMBtu. At a conservative benchmark of $4/MMBtu (U.S. Henry Hub), 77 million tonnes of O&G methane equals roughly $15 billion in wasted product per year. At international prices, where European and Asian spot LNG trades at $10-14/MMBtu, the same gas is worth $38-54 billion. Either way, the satellite-adjusted figure of 115 million tonnes makes the waste 50% larger.
The IEA estimates that mobilizing all abatement measures across the global oil and gas sector would require approximately $15 billion per year. At floor-level U.S. prices, that investment roughly equals the revenue from captured gas. At international prices, it is less than half. ExxonMobil alone reported $36 billion in net income in 2023.
| Metric | Inventory-Based | Satellite-Adjusted |
|---|---|---|
| O&G methane (Mt/yr) | ~77 | ~115 |
| Value at $4/MMBtu ($/yr) | ~$15B | ~$23B |
| Value at $10/MMBtu ($/yr) | ~$38B | ~$57B |
| Zero-net-cost abatement | 30%+ of fossil fuel total (higher for O&G) | |
| Full abatement investment | ~$15B/yr | |
| 75% reduction cost | โค$10/tCO2e | |
Sources: IEA Global Methane Tracker 2025, Belfer Center synthesis
Who Is Leaking
MethaneSAT names names. Turkmenistan's Turkmengaz, Venezuela's PDVSA, and Iran's National Iranian Oil Company operate the most persistently leaking infrastructure on the planet. None face meaningful consequences. Turkmenistan and Venezuela are not Methane Pledge signatories. Iran signed but published no implementation plan.
In the U.S., the Permian Basin produces roughly 40% of domestic crude and has some of the highest methane intensities in the country. Low-producing wells, responsible for just 7% of fossil fuel output nationally, drive an estimated 40% of U.S. methane pollution (EPA Greenhouse Gas Inventory). Many are marginal wells operated by small companies with neither the capital nor the incentive to fix leaks.
From Honor System to Enforcement
Europe is already building policy around satellite capability. The EU's 2024 Methane Regulation requires oil and gas importers to report supply-chain methane intensity. By 2027, imports exceeding thresholds face restrictions. Satellite data is the enforcement mechanism: European customs can independently verify the methane intensity of a Turkmen LNG cargo.
America's approach is more fragmented. The EPA's 2023 methane rule includes a "super-emitter response program" allowing satellite operators to report large emission events, triggering mandatory investigation and repair. But small wells producing under 15 barrels of oil equivalent per day are largely exempt. Those are the wells driving 40% of U.S. emissions.
Strongest Counterargument
Industry groups argue that satellite detection thresholds bias toward large, intermittent events. GHGSat's own data shows oil and gas sites emit detectable plumes only 16% of the time, so satellites capture worst moments rather than steady-state operations. Extrapolating from peak events to annual averages, the argument goes, inflates the totals.
This critique has partial merit. MethaneSAT's minimum detection limit is approximately 500 kg/h under ideal conditions and closer to 1,300 kg/h on average. But the bias works in both directions: satellites miss chronic low-level seepage from millions of small sources. Independent measurement campaigns using aircraft and ground sensors in the Permian Basin have consistently confirmed emission rates 2 to 3 times higher than EPA inventories, aligning with satellite data, not contradicting it.
Limitations
MethaneSAT operated for only 15 months before deorbiting, and its successors are not yet operational. Its 100-by-400-meter resolution cannot distinguish adjacent facilities in dense production areas. Offshore platforms are harder to observe because water surfaces reduce spectrometer sensitivity. Countries that refuse to cooperate face no binding enforcement mechanism. This analysis also uses a conservative $4/MMBtu floor price; regional pricing varies, and in heavily subsidized markets like Turkmenistan the economic case for capture is weaker because the gas has fewer profitable outlets.
The Bottom Line
For the first time, independent instruments in orbit are measuring methane emissions from oil and gas operations worldwide. Industry inventories undercount by roughly 50%. At conservative U.S. prices, the full fix costs about as much as the captured gas is worth. At international prices, the industry would profit. Fifteen billion dollars per year, roughly 0.3% of global oil and gas revenue, would fund it all. The atmosphere does not grade on a curve. Neither do satellites.