Updated below with Skype chat with the study lead author, 10:07 p.m. |
Most efforts to slow the natural gas drilling boom in the United States have focused on questions about the environmental impacts of the process called hydraulic fracturing, or fracking, which occurs deep underground after a well is drilled.
That's why a great deal of attention was paid last week to the results of a two-day aerial survey over gas fields in southwestern Pennsylvania that calculated emission rates of methane (the main component of natural gas) from two well pads still in the drilling phase. The emissions rates were between 100 and 1,000 times higher than what would be consistent with Environmental Protection Agency leakage estimates.
The study, "Toward a better understanding and quantification of methane emissions from shale gas development," was published in the Proceedings of the National Academy of Sciences and undertaken by Dana R. Caulton and Paul B. Shepson of Purdue and a host of co-authors, including Anthony Ingraffea and Robert Howarth, Cornell scientists who are prominent foes of fracking, along with Renee Santoro of Physicians Scientists & Engineers for Healthy Energy, a nonprofit group that has been critical of fracking* (Ingraffea is affiliated with the group, as well).
Much of the news coverage and commentary was greatly oversimplified, implying that airplane measurements taken on two days in 2012 and showing high methane levels over a handful of wells (and nothing unusual over almost all the other wells in the region) pointed to an extraordinary new pollution and climate change risk. A case in point was this Climate Central post: "Huge Methane Leaks Add Doubt on Gas as 'Bridge' Fuel."
In fact, the study is consistent with other recent work covered here that shows there are specific and tractable issues that can be addressed, making gas production far less leaky and thus a legitimate successor to coal mining.
This section from the paper says as much (I added the paper links to the citation numbers):
[T]hese regional scale findings and a recent national study (23) indicate that overall sites leak rates can be higher than current inventory estimates. Additionally, a recent comprehensive study of measured natural gas emission rates versus "official" inventory estimates found that the inventories consistently underestimated measured emissions and hypothesized that one explanation for this discrepancy could be a small number of high-emitting wells or components (33) . These high leak rates illustrate the urgent need to identify and mitigate these leaks as shale gas production continues to increase nationally (10).
There is one aspect of the new study that's worth a deeper dive. The authors noted the presence of sources of coalbed methane — a common peril in coal mines throughout the history of coal mining — near the methane hot spots they found (the supplementary information is here).
It took a bit of time for me to seek some knowledgable input on this. (Increasingly I'm in "slow blogging" mode these days, partly because I'm chronically swamped but mostly because I try to maintain a foothold in reality.)
I sent the paper to Louis Derry, a Cornell University geologist who's been a constructive presence in the Dot Earth comment stream for a long time and, although he worked several decades ago for mining and oil companies, has provided science-based guidance on research related to shale gas. Read on for Derry's analysis, which I'm sharing with the authors [see the update below].
In the end, the best way to resolve such questions is in the peer-reviewed literature, but it's valuable to have some discourse here given the way simplified interpretations of single papers ("single study syndrome") often swamp policy debates even as the process of science grinds forward.
Here's Derry's critique, which includes a very important conclusion I'm sure these authors would agree on — that regulators should require monitoring of local air chemistry before, during and after drilling of gas wells:
The new study on methane fluxes by Caulton et al. raises some interesting questions. The authors report very high fluxes associated with a small set of wells in southwest Pennsylvania, while finding "little or no emission" from other wells in a larger area. The local area they identify as anomalous has a number of coal mining operations, also a potentially large source of methane. The reported gas chemistry in the Caulton study has low ratios of propane to methane (known as C3/C1, from the carbon numbers). Such low C3/C1 is characteristic of coal bed gas, but not of Marcellus gas (higher C3/C1). As the authors note, the data suggest pretty strongly that the vented gas is from coal, not from the Marcellus target horizon. Coal bed methane is produced from many wells specifically drilled for that purpose in the area, with about 12 billion cubic feet produced in 2012 in Greene and Washington counties. An important question is how that coal bed gas is reaching the atmosphere. Is it, as the authors propose, leaking from new shale gas wells that happen to penetrate the coal-bearing horizon on the way down to their deeper intended target (the Marcellus shale)? Or, in this area with a long history of coal mining, are structures associated with past or present mining activity the main pathway? Underground coal mines (active and abandoned) are routinely vented to prevent mine explosions. There are other routes for coal gas to escape, including fractures or undocumented structures from legacy mines and abandoned wells.
Measuring gas fluxes and identifying sources associated with drilling, mining, landfills, or agriculture is not as easy as it may sound. One approach is to go out and measure gas levels "on the ground." A widely reported Environmental Defense Fund study released last year (Allen et al, 2013 PNAS) did that for about 190 gas wells. With site-specific data, they found relatively low overall leak rates but were able to identify gas-operated valves as an important leakage point. As with any "bottom up" study, extrapolating the results to large areas is difficult. Another approach is to take aircraft, tower, and other measurements, and try and infer the strength and identity of sources from anomalies in gas concentrations sampled from wide area. This requires some important assumptions and computation, including the issue of "back tracking" air masses, both horizontally and vertically. A recent example of a large-scale "top down" study using aircraft and tower data is that of Miller et al (2013, PNAS). They identified anomalous methane fluxes from the south central United States that they tentatively ascribed to fossil fuel production there. But studies like this, by their very design, cannot identify individual sources.
Both kinds have their merits and limitations. There's no silver bullet. The Caulton study is, in a sense, in between these two approaches. The study used aircraft measurements where they circled upwind and downwind of potential sources, but they only sampled during two days. Because the radius of an individual circuit was small (less than 1 kilometer), they can better identify the location of methane sources that contribute to atmospheric anomalies. For example, one well pad appears to be the source of a methane plume, since only background methane was observed upwind but anomalous levels were found just downwind. A nearby circuit showed higher methane upwind of a pad than downwind, indicating a source outside the target area, possibly from nearby mine vents. On another of their flights, a very strong gas anomaly showed up near a well pad that was also near a coal mine. The mine signal is so strong that it's not possible to resolve any contribution from the well pad. These results give an indication of the complexity of gas sources in the area. The authors state that six other well pads gave results indicating significant leakage but the underlying data are not included in the paper, so it's hard to evaluate. Given the history of coal mining in the area, each location needs to be treated with care so as not to convolve gas fluxes that come directly from past or present mining activities with those that are following new drill holes as the release pathway.
Unfortunately, we have no equivalent data on gas concentrations in this area (or just about any other place) from prior to the start of drilling with which to compare. This would have been particularly valuable in an area with so much coal, where we might expect high fluxes prior to any shale gas drilling. Because of the pace of shale gas development, scientists are basically playing catch up.
It would be very smart if local scale monitoring of air chemistry were an intrinsic part of gas development. The monitoring should include pre-drilling data so that we can usefully compare fluxes before, during and after. Real-time data would be available to monitor gas fluxes and especially to identify anomalies that could then be fixed. Data in real time can support an active QA/QC [quality assurance and quality control] program. If the methane signal jumps, something is wrong, and should be (and in most case can be) fixed quickly. At about $50,000 apiece, modern portable atmospheric gas analyzers are small change relative to the cost of drilling, and in my opinion should be part of any the well field development plan.
Related devices are already employed by some gas developers, and methane monitoring will increasingly be required as Federal and state governments roll out new regulations. Methane leakage during drilling and production can be controlled, but without data nobody can know what most needs doing. For example the E.D.F. study showed that gas-operated pneumatic valves [relevant video] were a big source. That's easy to fix, once you know you have a problem. Before that study, nobody seems to have thought about it much. The E.P.A. recently issued regulations limiting leak rates from such valves.
The hypothesis of the Caulton paper, that the new shale gas wells are enabling the escape of coal bed methane, is certainly plausible but they only clearly document one example. The drilling phase is transient, and even if there are high leak rates as the drill penetrates coal-bearing strata they are likely to persist for a matter of days, or at most until the well is cased, usually a couple of weeks. One way to assess their magnitude is to use the instantaneous flux, which implies a large effect from the newly identified sources. But if these sources are only active for a week or two, their integrated impact drops substantially. The headlines to the effect that "gas leaking at 1,000 times E.P.A. estimates" [example] might be true in a very narrow sense but do not reflect the transient nature the process. And it may turn out that at least some of this flux is not the result of shale gas drilling at all.
The rates proposed by Caulton are about a million cubic feet a day, not something the industry wants to lose, and industry people are quite skeptical that drilling operations leak anything like that amount. It may be that drilling in a coal-rich area will require special precautions to prevent transient leaks. If, as Caulton et al. conclude, a small number of wells contribute heavily to the leakage flux, this actually makes fixing the problem more straightforward.
The same has been observed with automobile emissions. A few clunkers emit more than many properly maintained vehicles, so it makes sense to try and get the clunkers off the road.
Or the real message of this study may be that gas fluxes from coal operations have been underestimated, and that they are mostly responsible for the hotspots. Either way the study helps identify an anomalous local source, but more data is needed to decide which it is, and how important it is. Once identified, gas leaks in production and transportation systems can be reduced, and there is an economic as well as environmental incentive to do so. Further, vented mine gases in the same area are now being captured as an economic resource, and there may be additional opportunities for such conversion of a waste product to a resource. Methane is an attractive target from the standpoint of stemming climate change, as it has the potential for short-term climate impacts and its anthropogenic sources are easier to control than CO2. But in the long run, it is CO2 emissions that will determine the fate of our climate.
Problem number one in greenhouse gas emissions remains coal consumption, not to mention its onerous impact on air quality and public health.
Insert, 10:08 p.m. | Paul Shepson, the study's lead author and an atmospheric chemist at Purdue, said Derry's concern that the team was measuring coalbed methane coming from somewhere other than the gas wells was unfounded.
But in a Skype chat he agreed with Derry's conclusions that real-time monitoring is vital, and that, in the end, carbon dioxide is the greenhouse gas of greatest concern.
Postscript, 8:30 p.m. | * In an e-mail message, Seth Shonkoff, the executive director of Physicians, Scientists & Engineers for Healthy Energy, said the group preferred to be described as critical of fracking rather than "anti-fracking" (see the line marked with an asterisk). In the interest of nuance and engagement, I'm happy to make this change. He gave me permission to post the message in the comment string.