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The Eagle Ford Shale in southern Texas is home to a booming unconventional\udoil and gas industry, the climate and air quality impacts of which remain\udpoorly quantified due to uncertain emission estimates. We used the\udatmospheric enhancement of alkanes from Texas Commission on Environmental\udQuality volatile organic compound monitors across the shale, in combination\udwith back trajectory and dispersion modeling, to quantify C2–C4 alkane\udemissions for a region in southern Texas, including the core of the Eagle\udFord, for a set of 68 days from July 2013 to December 2015. Emissions were\udpartitioned into raw natural gas and liquid storage tank sources using gas\udand headspace composition data, respectively, and observed enhancement\udratios. We also estimate methane emissions based on typical ethane-to-methane\udratios in gaseous emissions. The median emission rate from raw natural gas\udsources in the shale, calculated as a percentage of the total produced\udnatural gas in the upwind region, was 0.7 % with an interquartile range\ud(IQR) of 0.5–1.3 %, below the US Environmental Protection Agency's (EPA)\udcurrent estimates. However, storage tanks contributed 17 % of methane\udemissions, 55 % of ethane, 82 % percent of propane, 90 % of\udn-butane, and 83 % of isobutane emissions. The inclusion of\udliquid storage tank emissions results in a median emission rate of 1.0 %\ud(IQR of 0.7–1.6 %) relative to produced natural gas, overlapping the\udcurrent EPA estimate of roughly 1.6 %. We conclude that emissions from\udliquid storage tanks are likely a major source for the observed non-methane\udhydrocarbon enhancements in the Northern Hemisphere

Quantifying alkane emissions in the Eagle Ford Shale using boundary layer enhancement