As hydraulic fracturing is increasingly used for oil and gas extraction across much of the United States and Western Canada, a new Ceres report issued today shows that much of this activity is happening in arid, water stressed regions, creating significan
The report provides first-ever data on oil & gas companies’ water use and exposure to the most water stressed regions, including those in Texas, Colorado and California. It includes recommendations for companies to improve their water management and reduce their overall exposure to water sourcing risks.
“Hydraulic fracturing is increasing competitive pressures for water in some of the country’s most water-stressed and drought-ridden regions,” said Ceres President Mindy Lubber, in announcing Hydraulic Fracturing and Water Stress: Water Demand by the Numbers. “Barring stiffer water-use regulations and improved on-the-ground practices, the industry’s water needs in many regions are on a collision course with other water users, especially agriculture and municipal water use. Investors and banks providing capital for hydraulic fracturing should be recognizing these water sourcing risks and pressing oil and gas companies on their strategies for dealing with them.”
The report is based on water use data from 39,294 oil and gas wells reported to FracFocus.org from January 2011 through May 2013 and water stress indicator maps developed by the World Resources Institute (WRI). It shows that nearly half of the wells were in regions with high or extremely high water stress. (Extreme high water stress regions, as defined by WRI, are areas where 80 percent of available surface and groundwater are already allocated to municipal, industrial and agricultural users.)
The report spotlights eight specific regions with the most intense shale development and water stress challenges in the U.S. and Canada. It showed that over 55 percent of the wells hydraulically fractured were in areas experiencing drought and 36 percent overlay regions with significant groundwater depletion – key among those, California which is in the midst of a historic drought and Texas, which has the highest concentration of shale energy development and hydraulic fracturing activity in the U.S.
"Groundwater is simply not as plentiful as it used to be. We now recognize many competing uses – domestic, agricultural, for energy production and for the environment,” said Jay Famiglietti, professor and director Earth System Science, Civil and Environmental Engineering, University of California, Irvine. “Ceres’ report helps us confront difficult decisions about how we might allocate future waters, in particular in regions of considerable water stress."
In Texas, which includes the rapidly developing Eagle Ford and Permian Basin shale plays, more than half (52 percent) of the wells were in high or extreme high water stress areas. In Colorado and California, 97 and 96 percent of the wells, respectively, were in regions with high or extremely high water stress. Nearly comparable trends were also shown in New Mexico, Utah and Wyoming.
Among hundreds of hydraulic fracturing companies whose water use was evaluated, those with the highest exposure to water sourcing risk are Anadarako (APC), Encana (ECA), Pioneer (PXD) and Apache (APA). Most of the wells being developed by each of these companies are in regions of high or extreme water stress. The top three service providers, Halliburton, (HAL) Schlumberger (SLB) and Baker Hughes (BHI), handled about half of the water used for hydraulic fracturing nationally and also face water sourcing risks.
Although water use for hydraulic fracturing is often less than two percent of state water demands, the impacts can be large at the local level, sometimes exceeding the water used by all of the residents in a county. In many shale plays, hydraulic fracturing activity was found to be highly localized in a just few counties. Twenty-eight percent of water used in the regions studied was used in just two percent (or 10) of the counties where hydraulic fracturing took place. Dimmit County, Texas in the Eagle Ford basin had the largest volume of water use for hydraulic fracturing nationally – about four billion gallons. Garfield and Weld counties in Colorado and Karnes County in Texas were the highest water use counties in regions with extreme water stress.
Among the report’s other key findings:
Texas: Texas is ground zero for water availability risks. Hydraulic fracturing-related water use is projected to double there over the next decade even as much of the state continues to face severe drought conditions, key groundwater aquifers are under stress and population growth is surging.
The Eagle Ford faces some of the biggest water challenges nationally. The amount of water used for hydraulic fracturing in this shale play is greater than in any other shale play or basin in the country (19.2 billion gallons from January 2011 to May 2013). Water use per well is also relatively high, averaging over 4.5 million gallons. Shale energy production is placing increased pressure on the counties of Dimmit, Zavala, and La Salle, which have seen groundwater levels decline as much as 100 to 300 feet the last several decades.
The Permian Basin also faces high water competition, groundwater depletion and drought concerns. More than 85 percent of the Permian’s wells are in extreme water stress areas. Although average water use per well is much lower than in the Eagle Ford, the sheer number of wells in development is substantially larger, with over 9,300 wells reported developed since the beginning of 2011.
Colorado: The Denver-Julesburg Basin, part of the Niobrara shale formation, is another region with intense shale activity, much of it centered in Weld County, with nearly 2,900 wells developed since 2011 and an area marked by extreme water stress. Water demand for hydraulic fracturing in the state is forecast to double, to six billion gallons by 2015, more than twice what the city of Boulder uses in an entire year.
In California, nearly all of hydraulic fracturing water use is taking place in regions of extreme high water stress, although water use per well remains low. Most of the activity to date in California has been in Kern County, which is exposed to extreme high water stress due to factors such as large agriculture water demand and a growing population.
Many of the smaller shale plays (between 100 to 2,000 wells) are also in high and extreme high water stress regions, including the Piceance, Uinta, Green River, San Juan, Cleveland/Tonkawa and Anadarko Woodford basins.
“While the economic benefits of hydraulic fracturing are compelling, we must address all competing interests, particularly in relation to water use. For that we need factual data we can rely on to make informed decisions to ensure future water availability,” said Amanda Brock, CEO at Water Standard, a Houston-based global water treatment specialist firm.
The report also includes key recommendations for investors and shale energy companies for mitigating their water sourcing risks. Shale energy operators should:
Disclose to regulators, investors and other stakeholders: total water volumes and sources used in each shale play, future sourcing needs, and plans for reducing water use; breakdown of present and future use from freshwater and non-freshwater sources; volume of water returning to the surface, revenues and future growth in water stressed regions.
Implement Operational Practices to minimize water use; collaborate with industry peers and other industries on local water sourcing challenges; develop local source water protection plans; minimize the use of aquifer exemptions and deep well injection disposal sites whenever feasible.
Engage with Stakeholders, including with: local communities on water needs and challenges before starting operations and after they begin; local and regional regulators on water challenges; employees and suppliers to provide incentives for reducing water use.
Embed water risk and opportunity across all business units, from the boardroom to the drill site.
"Water sourcing and management is becoming a key competitive advantage – and a critical risk – for oil and gas companies using hydraulic fracturing to unlock new reserves. Investors need the data to understand how companies are meeting these challenges on a regional or play-by-play basis in order to appropriately value companies and also engage with them to improve their practices, “ said Steven Heim, Managing Director and Director of ESG Research and Shareholder Engagement at Boston Common Asset Management.
The report includes 3 interactive maps showing locations of hydraulically fractured wells against water stress, drought and groundwater depletion. See www.ceres.org/shalemaps
About Ceres Ceres is a nonprofit organization mobilizing business and investor leadership on climate change, water scarcity and other sustainability challenges. Ceres directs the Investor Network on Climate Risk (INCR), a network of over 100 institutional investors with collective assets totaling more than $12 trillion. Ceres also directs Business for Innovative Climate & Energy Policy (BICEP), an advocacy coalition of nearly 30 businesses committed to working with policy makers to pass meaningful energy and climate legislation. For more information, visit http://www.ceres.org or follow on Twitter .