How Thirsty is Shale Gas?

Water use in the production of shale gas and corn ethanol.

Editor’s note: Professionals in the oil and gas industry often receive questions about how industry operations affect public health, the environment, and the communities in which they operate. Of particular concern today is the impact of hydraulic fracturing on the environment. In this new column, JPT is inviting energy experts to put those questions and concerns about industry operations into perspective. Additional information about the oil and gas industry, how it affects society, and how to explain industry operations and practices to the general public is available on SPE’s Energy4me website at

The New York Times reported on 15 May 2014 that Butte County in California banned hydraulic fracturing because of concerns regarding freshwater consumption in a drought year. Shale oil and gas opponents have seized this issue even in parts of the country not suffering any significant drought. The perception of being deprived of drinking water has strong imagery. The facts beyond the headlines are decidedly not so dire.

A single shale oil or gas well will use between 3 and 5 million gal of water for drilling and completion operations. This sounds like a lot and, in some sense, it is a lot. But then you realize that the average golf course uses that much every 25 days, about the length of time it takes to drill a single well and start producing from it. It is also the amount of water that New York City uses every 4 minutes! Not a fair comparison, you say. Well, why don’t we compare it against other forms of energy?

Such comparisons are best made on the basis of liters of water per megawatt hour of energy. Shale gas production uses about 38 liters. In comparison, corn ethanol on average uses 32,000 to 370,000 liters (the higher end of the range is for irrigated corn), and the real shocker is soybean diesel, which comes in at 180,000 to 960,000 liters. In other words, corn ethanol uses more than 1,000 times more water per unit of energy compared with shale gas. Other sources suggest an even greater disparity in water usage (Science 2009).

Conventional fracturing fluid uses freshwater as the base fluid. Fresh is defined as 500 parts per million (ppm) or less of dissolved solids. The fluid returning to the surface after use, known as flowback water, is always saltier than what went in. Salinities of 200,000 ppm are not uncommon. As a frame of reference, seawater runs about 35,000 ppm. Recent advances in fracturing fluid chemistry allow for such flowback water to be reused without removing the salt down to fresh standards. Currently in the Marcellus shale play, some companies are reusing almost all of their flowback water with minimal treatment. This practice materially reduces freshwater requirements.

Between 16% and 35% of fracturing water returns to the surface. Consequently, even reuse entails making up that with new freshwater. Since salt concentrations are tolerable, this makeup water could also be salty. To the extent that this is done, the industry would not be competing to use freshwater resources. How viable is this option? It turns out that salty water is commonly available almost anywhere that freshwater is found. The comprehensive map of saline groundwater by the US Geological Survey is old but instructive in this regard (USGS 1965). Fresh groundwater gets saltier as you go deeper. This is because over time, minerals dissolve into the water, more so at greater depths. Very often, the fresh and saltier zones are in direct communication. This is why in times of drought, farmers face restrictions on the rate of withdrawal of freshwater in order not to draw up saltier water from below.

Shale oil or gas production does indeed use a lot of water, but not as much as other sources of energy. Recent advances in technology allow the substitution of brackish water for freshwater. This is already happening today. If the practice becomes more widespread, public acceptance of the industry, especially in drought-prone areas, will improve.


Another Biofuels Drawback: The Demand for Irrigation Science Vol. 326. 23 October 2009.

J.H. Feth et al.1965. Preliminary map of the conterminous United States showing depth to and quality of shallowest groundwater containing more than 1,000 parts per million dissolved solids. 

Vikram Rao, SPE, is executive director of the Research Triangle Energy Consortium (, a nonprofit group in energy founded by Duke University, North Carolina State University, RTI International, and the University of North Carolina at Chapel Hill. Its mission is to illuminate national energy priorities and, by extension, those of the world, and to catalyze research to address these priorities. Rao advises Energy Ventures AS, BioLargo, Global Energy Talent, Integro Earth Fuels, and a multinational oil company. He retired as senior vice president and chief technology officer of Halliburton in 2008. He also serves on the North Carolina Mining and Energy Commission and chairs the Water and Waste Management Committee. He holds a bachelor’s degree in engineering from the Indian Institute of Technology Madras in India, and a master’s degree and doctorate in engineering from Stanford University. Rao is the author of more than 50 publications and has been awarded 36 US patents and foreign analogs. His book, Shale Gas: The Promise and the Peril, released in 2012, is an informed look at the heated debate regarding hydraulic fracturing for shale gas.

How Thirsty is Shale Gas?

Vikram Rao, Executive Director, Research Triangle Energy Consortium

01 July 2014

Volume: 66 | Issue: 7