The U.S. is rushing to exploit its newfound wealth of fossil fuels. With startling regularity, a government agency or energy company announces a new natural gas or oil field, proposes another liquefied natural gas (LNG) export terminal, or lays out plans to expand a chemical plant. The bonanza is particularly important to the chemical industry as companies eagerly take advantage of these new resources for feedstocks and fuel.

But the push for fossil-fuel development and use comes at a time when greenhouse gas emissions continue their upward climb and climate scientists sharpen their calls of alarm.

For decades, human-caused climate disruption has been on the horizon, based on scientific predictions. The damage is now starting to hit home. Two months ago, a committee of leading U.S. scientists reported measurable changes in the U.S. climate because of anthropogenic greenhouse gas emissions. They stressed that all regions of the U.S. are being affected and that, without quick action, climate-related changes will accelerate and be irreversible.

Most plans to stave off climate change have focused on limiting emissions of carbon dioxide, which make up 90% of anthropogenic releases of greenhouse gases. Yet methane—the primary compound in natural gas—is a much more potent greenhouse gas.

Methane makes up only 9% of anthropogenic greenhouse gases, but it has 86 times the global warming potential of CO2 in the first 20 years after it is emitted. Scientists believe it is crucial to reduce emissions of methane now because of its potentially critical impact on the climate in the next 10 to 20 years.

Although a few years ago chemical companies complained of the high price of natural gas, today that price has tumbled. The U.S. is awash in cheap natural gas thanks to new drilling technologies, primarily hydraulic fracturing, or fracking.

The U.S. is on track to produce more natural gas than it needs by 2020. U.S. oil and gas companies intend to sell some of their bounty to the rest of the world, hence the rush to gain federal approval for building LNG terminals for exports. The race to exploit this surplus has even driven a wedge between U.S. chemical companies and their historic ally, the oil and gas industry. Chemical executives want to keep natural gas cheap for domestic use while gas and oil industry owners want to profit through exports.

Either way, the U.S. is on the cusp of a new methane energy economy.

Despite its high global warming potential, methane has climate pluses. When burned as fuel for electricity generation, methane emits around half the CO2 of coal. This climate-related advantage has led to natural gas’s endorsement by President Barack Obama and the Department of Energy (DOE). Greater use of methane as a fuel is part of the Administration’s climate action plan to cut CO2 emissions.

Natural gas also has the potential to allow the U.S. to retain its fossil-fuel infrastructure. It offers a path to reduce CO2 emissions from the burning of coal for electricity while the nation develops carbon-free renewable energy or other electricity sources.

The gas boom is a boon, according to Energy Secretary Ernest J. Moniz. “First of all, we know that it is already partially responsible for the decrease in CO2 emissions that we have experienced over the last years,” he says. Moniz calls natural gas a “kind of bridge to a very low carbon future.” U.S. natural gas resources, he says, could afford more time for the nation to develop new alternative energy technologies, lower their costs, and achieve significant market penetration.

Not everyone agrees. Because of methane’s global warming potential, leakage of methane to the atmosphere makes this “bridge” a fallacy, several scientists say. They note that the current natural gas glut—and subsequent low prices—means there is little monetary incentive to stanch methane leaks.

They point to places such as the Bakken oil field, where output, thanks to fracking, has made North Dakota the U.S.’s second-largest oil-producing state. Natural gas and oil are usually found together, notes the Energy Information Administration (EIA), adding that more than half the 40,000 wells drilled last year in the U.S. held reserves of both. At Bakken, however, there is no infrastructure to move the gas to market. Consequently, methane is vented to the atmosphere or flared on-site as if it were waste. It is a mere by-product as energy companies rush to exploit the field’s more valuable oil resources.

About 29% of U.S. methane emissions are from leakage in the oil and gas production and distribution chain, according to the Environmental Protection Agency’s Greenhouse Gas Inventory. That makes the oil and gas industry the nation’s second-largest source of methane releases, ranking barely a percentage point below emissions from livestock.

Oil and gas drilling and field production constitute nearly half this loss, according to Paul Gunning, director of EPA’s Climate Change Division in the Office of Air & Radiation, who spoke at a recent webinar. The rest is divided among gas processing, transmission, storage, and distribution.

The actual methane leakage numbers—stated as a percentage of production—are between 1 and 2%, according to EPA’s annual inventory, based on the agency’s interpretation of industry-reported data. This number varies yearly and has shown a decline over time, according to EPA’s assessment of industry reports.

However, many atmospheric scientists question these numbers, saying they are too low, and point to a host of new studies conducted in recent years.

First to voice a strong challenge to EPA’s data was Robert W. Howarth of Cornell University. Three years ago, Howarth warned that overall methane emissions from natural gas activities could be 7.9% of production, far above EPA’s calculation. He blamed EPA’s low estimate on missed releases during fracking, when methane and other hydrocarbons flow to the surface, carried up by fracturing fluids when wells are initially drilled and fractured.

A study published in 2012 appears to support Howarth. Scientists from the National Oceanic & Atmospheric Administration (NOAA) and the Cooperative Institute for Research in Environmental Sciences (CIRES) at the University of Colorado, Boulder, accidentally discovered high methane levels being released from a Colorado oil and gas field. They were conducting tower-based air measurement experiments near a freeway.

The group continued their methane experiments and shifted to a large oil field in Utah, where they used aircraft to take air samples over natural gas and oil fields in Uintah County. There, the research team, led by Anna Karion, found methane leakage rates of 6 to 12% of production. The study was published last year.

This group of researchers also conducted a follow-up study to the earlier one in Colorado and found methane levels that were at least three times higher than EPA’s estimate. Their data were published last month in the Journal of Geophysical Research. These studies are highly structured and adjust for other sources of methane near the oil and gas fields, the researchers note.

A growing body of literature supports the view that methane emissions are higher than levels reported by industry and EPA. A study released earlier this year by a team led by Adam R. Brandt of Stanford University examined some 20 years of technical literature and 200 papers and found that federal officials have consistently underestimated actual methane emissions, which the report says are some 50% higher than EPA’s estimates.

Other peer-reviewed studies have raised similar challenges to EPA’s estimates, all pointing to levels above the agency’s estimates.

However, not all studies found problems in EPA’s data. An examination by scientists at the University of Texas, Austin, backed EPA’s numbers.

The Texas researchers found methane leakage levels from drilling and production to be near or even slightly lower than EPA’s estimates. The study, funded and organized by the Environmental Defense Fund (EDF), an environmental group, and several oil and gas companies, measured methane emissions from operations on the ground at the oil and gas fields, rather than air measurements taken during flights over the sites.

This study is the first in which oil drillers, which control the sites, granted access to nonindustry researchers. Consequently, this study provides on-the-ground measurements. But like EPA’s inventory, it carries the stigma of industry control.

Industry and researchers negotiated to select the test sites, noted David T. Allen, a UT Austin chemical engineering professor, who led the study. Speaking at the webinar, Allen acknowledged that the tests may be measuring best conditions—sites with so-called green completions that use new technologies to capture methane leakage during drilling and fracking. Still this study advances the discussion by measuring on-the-ground emissions, he said.

The difference has been characterized as “top-down versus bottom-up”—field measurements at a specific site versus measurements from above in an aircraft or tower.

Allen, Gunning, and other researchers attribute the high losses that NOAA and CIRES found to so-called superemitters—badly run, old, and leaking well sites or abandoned wells from partially depleted fields.

They stress the difficulty in measuring emission from huge fields holding tens of thousands of operating wells and an unknown number of closed sites. EIA estimates that there are some 500,000 wells operating at some level of production in the U.S.

The disparity might be resolved by upcoming research that will merge top-down and bottom-up approaches to emissions measurements. Those studies are just getting under way, notes Drew Nelson, EDF senior manager for natural gas projects. EDF and the gas and oil industry are funding 16 studies involving 90 academic and industry collaborators, and results are expected this year, Nelson says.

Several of these studies will be done by the NOAA-CIRES team of scientists, says Jeff Peischl, CIRES associate scientist. Their plan, he says, is to conduct top-down measurements of an oil and gas field by aircraft and back up this data with mobile lab measurements on the ground. NOAA-CIRES will use two aircraft and four mobile units and will look for other hydrocarbons as well as methane. The researchers will start these investigations within a month, he adds.

Bottom-up measurements are difficult, Peischl says, but combining them with top-down measurements may help solve the puzzle. “You find a leaking valve in an oil field and you measure it, but you have to ask—will this be the same for thousands of other valves in a field, or is it just one valve that someone forgot to tighten?”

Cornell’s Howarth remains convinced of his early argument. In a recent paper, he says that EPA and Allen are “measuring the best possible performance by the industry” by relying on industry data and giving industry control of sampling points. He also stands by his earlier conclusion that natural gas and coal have similar greenhouse gas impacts when methane leakage is included with CO2 from burning methane. He warns that rather than a bridge fuel, natural gas is “a bridge to nowhere”.

“So much is happening right now and … the literature is growing so rapidly that we need to understand more about top-down studies before we change estimates,” he said during the webinar. “We need further evaluation. It is too early to make any conclusions in my opinion.”

But Gunning sticks by EPA’s numbers.

“The number 1.2% doesn’t seem like much. But if the U.S. lost this many LNG tankers, the industry and public wouldn’t tolerate it,” he says.

Technologies exist to capture about 40% of lost methane from the oil and gas system, according to analysis by EDF and the Natural Resources Defense Council. The technologies are in use, but it is unclear how many sites are using them.

So far, EPA has been unwilling to directly regulate methane emissions. Under court order, the agency issued regulations in 2012 intended to reduce emissions of volatile organic compounds and hazardous air pollution from gas wells. Although methane wasn’t specified in the rules, the gas will be captured in these efforts as a cobenefit. The regulations affect new wells beginning in 2015 on a phased schedule.

But existing wells are not covered. Because of this, an EDF-funded study by the engineering consulting firm ICF International estimates methane emissions from the oil and gas industry will grow by 4.5% by 2018, with that year’s releases coming primarily from existing wells.

“Existing wells are a big hole in the regulatory structure,” Nelson says.

Meanwhile, natural gas industries and their political allies are continuing to press ahead with proposals to sell U.S. LNG to the rest of the world. In June, the federal government approved the Cameron LNG project in Louisiana, the nation’s second natural gas terminal to get government go-ahead.

The American Petroleum Institute, an oil trade association, called the decision “great news for Louisiana workers and the U.S. economy” and noted that the U.S. has become the “world’s top natural gas producer.” It urged the government to speed up the export approval process.

But the Chesapeake Climate Action Network, an environmental group, is more circumspect after parsing a recent DOE report on LNG exports to Europe. It finds that if the oil and gas system methane leak rate exceeds 1.9%, U.S. natural gas loses its greenhouse gas advantage over European coal. To retain a climate benefit, natural gas leakage must be below 1.4% if shipped to Asia, the group says. The climate action network, which opposes LNG terminal expansion, is urging federal regulators to consider global climate impact when permitting new LNG terminals.

Gunning says EPA has several proposals in the works to reduce methane emissions. The agency is planning for new, tighter greenhouse gas reporting requirements, which may clear up the disagreements about leakage rates and boost confidence in EPA’s figures. The agency will also prepare a series of technical white papers this autumn examining ways to limit methane emissions. If regulations are necessary, EPA intends to propose them by 2016.

On the other hand, the Obama Administration underscores the importance of methane “as a source of clean energy that generates revenues, spurs investment and jobs, improves safety, and leads to cleaner air.”

Arguing about emissions levels is not the point, says EDF’s Nelson. An overall system leak of 1.2% of production is worth between $1.36 billion and $5.15 billion in lost revenue, he says. That amount of methane equals the annual greenhouse gas emissions of 112 million cars and 140 coal-fired power plants. It’s also equivalent to the capacity of 119 LNG tankers.

Methane’s role as either a climate saver or destroyer may be determined by these white papers. If EPA finds leakage to be small, the gas may serve as a clean energy bridge, as Energy Secretary Moniz says. Otherwise natural gas will simply speed the rate of climate change that Earth already faces.