Environmental impact of hydraulic fracturing in the United States
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Shale gas drilling rig near Alvarado, Texas
Environmental impact of hydraulic fracturing in the United States has been an issue of public concern, and includes the potential contamination of ground and surface water, methane emissions, air pollution, migration of gases and hydraulic fracturing chemicals and radionuclides to the surface, the potential mishandling of solid waste, drill cuttings, increased seismicity and associated effects on human and ecosystem health. A number of instances with groundwater contamination have been documented, however opponents of water safety regulation claim hydraulic fracturing has never caused any drinking water contamination.
As early as 1987, researchers at the United States Environmental Protection Agency (EPA) concluded that hydraulic fracturing can contaminate and has contaminated groundwater. According to former EPA employees, evidence of the negative environmental impact of fracking was systematically removed from congressional reports to support the energy industry under the direction of the Office of Legal Counsel during the Reagan administration. With the growth of hydraulic fracturing in the United States, "public exposure to the many chemicals involved in energy development is expected to increase over the next few years, with uncertain consequences" per science writer Valerie Brown in 2007.
- 1 Air quality and methane emissions
- 2 Water issues
- 3 Seismicity
- 4 Abandoned wells
- 5 Health effects
- 6 See also
- 7 References
- 8 Further reading
- 9 External links
Air quality and methane emissions
Methane emissions from wells raise global warming concerns. There is a 2,500 square-mile methane plume hovering over the western US and is worsening because of hydraulic fracture drilling. NASA was so alarmed by the size of the methane plume that, NASA researcher Christian Frankenberg reported to the press that, "We couldn’t be sure that the signal was real."
Other concerns are related to emissions from the hydraulic fracturing chemicals and equipment such as volatile organic compound (VOC) and ozone. In 2008, ozone concentrations in ambient air near drilling sites in Sublette County, Wyoming were frequently above the National Ambient Air Quality Standards (NAAQS) of 75 ppb and have been recorded as high as 125 ppb. In DISH, Texas, elevated levels of disulfides, benzene, xylenes and naphthalene have been detected in the air, emitted from compressor stations. In Garfield County, Colorado, an area with a high concentration of drilling rigs, VOC emissions increased 30% between 2004 and 2006.
Researchers from the University of Michigan analyzed the emissions produced from the hydraulic fracturing equipment at the Marcellus Shale and Eagle Ford Shale plays, and concluded that hydraulic pumps accounted for about 83% of the total emissions in the hydraulic fracturing fleet. NOx emission ranged between 3,600–5,600 lb/job, HC 232–289 lb/job, CO 859–1416 lb/job, and PM 184–310 lb/job. If the fuel efficiencies of the hydraulic fracturing pumps are improved, the emissions can be reduced.
On April 17, 2012, the EPA issued cost-effective regulations, required by the Clean Air Act, which include the first federal air standards for natural gas wells that are hydraulically fractured. The final rules are expected to yield a nearly 95% reduction in VOC emissions from more than 11,000 new hydraulically fractured gas wells each year. This reduction would be accomplished primarily through capturing natural gas that escapes into the air, and making it available for sale. The rules also will reduce air toxics, which are known or suspected of causing cancer and other serious health effects, and emissions of methane, a potent greenhouse gas.
Stanford University in the American Journal of Science, looked at 200 studies and claimed the United States Environmental Protection Agency has been underestimating US methane emissions. A survey of hydraulic fracturing sites in Pennsylvania revealed drilling operations releasing plumes of methane 100 to 1,000 times the rate the EPA expects from that stage of drilling.
Hydraulic fracturing uses between 1.2 and 3.5 million US gallons (4,500 and 13,200 m3) of water per well, with large projects using up to 5 million US gallons (19,000 m3). Additional water is used when wells are refractured. An average well requires 3 to 8 million US gallons (11,000 to 30,000 m3) of water over its lifetime. Back in 2008 and 2009 at the beginning of the shale boom in Pennsylvania, hydraulic fracturing accounted for 650 million US gallons per year (2,500,000 m3/a) (less than 0.8%) of annual water use in the area overlying the Marcellus Shale. The annual number of well permits, however, increased by a factor of five and the number of well starts increased by a factor of over 17 from 2008 to 2011.
According to Environment America, a federation of state-based, citizen-funded environmental advocacy organizations, there are concerns for farmers competing with oil and gas for water. A report by Ceres questions whether the growth of hydraulic fracturing is sustainable in Texas and Colorado as 92% of Colorado wells were in extremely high water stress regions (that means regions where more than 80% of the available water is already allocated for agricultural, industrial and municipal water use) and 51% percent of the Texas wells were in high or extremely high water stress regions. In Barnhart, Texas the aquifer supplying the local community ran dry because of intensive water utilization for hydraulic fracturing. In 2013, the Railroad Commission of Texas adopted new hydraulic fracturing water recycling rules intended to encourage Texas hydraulic fracturing operators to conserve water used in the hydraulic fracturing process.
Consequences for agriculture have already been observed in North America. In some regions of the US that are vulnerable to droughts, farmers are now competing with fracking industrials for the use of water resources. In the Barnett Shale region, in Texas and New Mexico, drinking water wells have dried up due to fracking's withdrawal of water, and water has been taken from an aquifer used for residential and agricultural use. Farmers have seen their wells go dry in Texas and New Mexico as a result of fracking’s pressure on water resources, for instance in Carlsbad, New Mexico. Agricultural communities have already seen water prices rising because of that problem. In the North Water Conservation District in Colorado was organized an auction to allocate water and the prices rose from $22/acre-foot in 2010 to $28 in the beginning of 2012.
Hydraulic fracturing fluids include proppants, radionuclide tracers, and other chemicals. While many are common and generally harmless, some additives used in the United States are known carcinogens. Out of 2,500 hydraulic fracturing products, more than 650 contained known or possible human carcinogens regulated under the Safe Drinking Water Act or listed as hazardous air pollutants". Between 2005 and 2009, 279 products had at least one component listed as "proprietary" or "trade secret" on their Occupational Safety and Health Administration (OSHA) required safety data sheet (SDS). In many instances, companies who bought products off the shelf did not know the ingredients. Without knowing the identity of the proprietary components, regulators cannot test for their presence.[clarification needed] This prevents government regulators from establishing baseline levels of the substances prior to hydraulic fracturing and documenting changes in these levels, thereby making it more difficult to prove that hydraulic fracturing is contaminating the environment with these substances.
The Ground Water Protection Council launched FracFocus.org, an online voluntary disclosure database for hydraulic fracturing fluids funded by oil and gas trade groups and the United States Department of Energy (DOE). The site has been met with some scepticism relating to proprietary information that is not included. Some states have mandated fluid disclosure and incorporated FracFocus as the tool for disclosure.
In 2009, state regulators from across the country stated that they had seen no evidence of hydraulic fracturing contaminating water in their respective jurisdictions. In May 2011 the EPA Administrator Lisa P. Jackson testified in a Senate Hearing Committee stating that the EPA had never made a definitive determination of contamination where the hydraulic fracturing process itself has contaminated water. However, by 2013, Dr. Robin Ikeda, Deputy Director of Noncommunicable Diseases, Injury and Environmental Health at the CDC testified to congress that EPA had documented contamination at several sites.
Incidents of contamination
- As early as 1987, an EPA report was published that indicated fracture fluid invasion into James Parson's water well in Jackson County, West Virginia. The well, drilled by Kaiser Exploration and Mining Company, was found to have induced fractures that created a pathway to allow fracture fluid to contaminate the groundwater from which Mr. Parson's well was producing. Directed by Congress, the EPA announced in March 2010 that it will examine claims of water pollution related to hydraulic fracturing.
- In 2006, over 7 million cubic feet (200,000 m3) of methane were released from a blown gas well in Clark, Wyoming and nearby groundwater was found to be contaminated with hydrocarbon compounds and benzene particularly.
- An investigation was initiated after a Pennsylvania water well exploded on New Year's Day in 2009. The state investigation revealed that Cabot Oil & Gas Company "had allowed combustible gas to escape into the region's groundwater supplies." Arsenic, barium, DEHP, glycol compounds, manganese, phenol, methane, and sodium were found in unacceptable levels in the wells. In April 2010, the state of Pennsylvania banned Cabot Oil & Gas Corp. from further drilling in the entire state until it plugs wells believed to be the source of contamination of the drinking water of 14 homes in Dimock Township, Pennsylvania. Cabot Oil & Gas was also required to financially compensate residents and provide alternative sources of water until mitigation systems were installed in affected wells. The company denies, however, that any "of the issues in Dimock have anything to do with hydraulic fracturing". In May 2012 the EPA reported that their most recent "set of sampling did not show levels of contaminants that would give the EPA reason to take further action." Methane was found only in one well. Cabot has held that the methane was preexisting, but state regulators have cited chemical fingerprinting as proof that it was from Cabot's hydraulic fracturing activities. The EPA plans to re-sample four wells where previous data by the company and the state showed levels of contaminants.
- Complaints about water quality from residents near a gas field in Pavillion, Wyoming prompted an EPA groundwater investigation. An EPA draft report dated December 8, 2011 found that contaminants in surface water near pits indicated were a source of contamination, and by the time the report was issued the company had already started to remediate the pits. The report also suggested that the groundwater contained "compounds likely associated with gas production practices, including hydraulic fracturing... Alternative explanations were carefully considered for individual sets of data. However, when considered together with other lines of evidence, the data indicates likely impact to ground water that can be explained by hydraulic fracturing." The Agency for Toxic Substances and Disease Registry recommended that owners of tainted wells use alternate sources of water for drinking and cooking, and ventilation when showering. Encana is funding the alternate water supplies. State and industry figures rejected the EPA's findings. In 2012 the U.S. Geological Survey tested one of two EPA monitoring wells near Pavillion and found evidence of methane, ethane, diesel compounds and phenol, In June 2013, the EPA announced that it was closing its investigation at Pavilion, and would not finish or seek peer review of its preliminary 2011 study. Further investigation will be done by the state of Wyoming.
Flowback is the portion of the injected fracturing fluid that flows back to the surface, along with oil, gas, and brine, when the well is produced. An estimated 90% of flowback in the United States is disposed of into deep EPA-licensed Class II disposal wells, with the remaining less than 10% reused, evaporated, used for irrigation, or discharged to surface streams under an NPDES permit. Of nine oil and gas-producing states studied in 2012, underground injection disposal was by far the predominant method in all but Pennsylvania where were only six active waste disposal wells. In California, Virginia, and Ohio there have been instances of illegal dumping of flowback, a precursor to possible contamination of local ground and surface water reservoirs. Discharging oil and gas produced water to surface streams without an NPDES permit is a federal crime. Discharges through water treatment works must comply with the federal Clean Water Act and the terms of their NPDES permits, but the EPA noted that most water treatment works are not set up to treat flowback.
In Pennsylvania, oil and gas produced water had for many years been accepted by licensed water treatment works for treatment and discharge, but the volume expanded greatly with the proliferation of Marcellus Shale wells after 2000. In 2010 the Pennsylvania Department of Environmental Protection (DEP) limited surface water discharges from new treatment plants to 250 mg/l chloride; the chloride limitation was designed to also limit other contaminants such as radium. Existing water treatment plants were "grandfathered," and still allowed higher discharge concentrations, but oil and gas operators were prohibited to send wastewater to the grandfathered treatment plants.
One Duke University study reported that "Marcellus [Shale] wells produce significantly less wastewater per unit gas recovered (~35%) compared to conventional natural gas wells." In Colorado the volume of wastewater discharged to surface streams increased from 2008 to 2011.
Surface water contamination
Hydraulic fracturing can affect surface water quality either through accidental spills at the wellsite, or by discharge of the flowback through existing water treatment works. Directed by Congress, the EPA announced in March 2010 that it would examine claims of water pollution related to hydraulic fracturing. Christopher Portier, director of the CDC's National Center for Environmental Health and the Agency for Toxic Substances and Disease Registry, argued that, in addition to the EPA's plans to investigate the impact of hydraulic fracturing on drinking water, additional studies should be carried out to determine whether wastewater from the wells can harm people or animals and vegetables they eat. A group of US doctors called for a moratorium on hydraulic fracturing in populated areas until such studies had been done.
However, others point out exclusions and exemptions for hydraulic fracturing under United States federal law. Exemptions were made in the Clean Water Act, as part of the Energy Policy Act of 2005, also known as the "Halliburton Loophole." These exemptions included stormwater runoff from gas and oil construction activities which includes "oil and gas exploration, production, process, or treatment operations and transmission facilities" as part of the definition of construction activities. Amendments to the Safe Drinking Water Act involved the definition of underground injection. Underground injection related to hydraulic fracturing was exempted from the Clean Water Act, except if it uses diesel fuel.
The growing of oil and natural gas drilling employing hydraulic fracturing technology is steady around different regions of the United States, but the maintenance of wastewater gathered after the drilling process containing hydraulic fracturing fluids is lagging behind. In Pennsylvania, the DEP reported that the resources to properly regulate wastewater-handling facilities were unavailable, inspecting facilities every 20 years rather than every 2 years as called for by regulation.
The quantity of wastewater and the unpreparedness of sewage plants to treat wastewater, is an issue in Pennsylvania. The Associated Press has reported that starting in 2011, the DEP strongly resisted providing the AP and other news organizations with information about complaints related to drilling. When waste brine is discharged to surface waters through conventional wastewater treatment plants, the bromide in the brine usually is not captured. Although not a health hazard by itself, in western Pennsylvania some downstream drinking water treatment plants using the surface water experienced increases in brominated trihalomethanes in 2009 and 2010. Trihalomethanes, undesirable byproducts of the chlorination process, form when the chlorine combines with dissolved organic matter in the source water, to form the trihalomethane chloroform. Bromine can substitute for some chlorine, forming brominated trihalomethanes. Because bromine has a higher atomic weight than chlorine, the partial conversion to brominated trihalomethanes increases the concentration by weight of total trihalomethanes.
Radioactivity associated with hydraulically fractured wells comes from two sources: naturally occurring radioactive material and radioactive tracers introduced into the wells. Flowback from oil and gas wells is usually disposed of deep underground in Class II injection wells, but in Pennsylvania, much of the wastewater from hydraulic fracturing operations is processed by public sewage treatment plants. Many sewage plants say that they are incapable of removing the radioactive components of this waste, which is often released into major rivers. Industry officials, though, claim that these levels are diluted enough that public health is not compromised.
In 2011, the level of dissolved radium in hydraulic fracturing wastewater released upstream from drinking water intakes had been measured to be up to 18,035 pCi/L (667.3 Bq/l), and the gross alpha level measured to be up to 40,880 pCi/L (1,513 Bq/l). The New York Times reported that studies by the EPA and a confidential study by the drilling industry concluded that radioactivity in drilling waste cannot be fully diluted in rivers and other waterways. A recent Duke University study sampled water downstream from a Pennsylvania wastewater treatment facility from 2010 through Fall 2012 and found the creek sediment contained levels of radium 200 times background levels. The surface water had the same chemical signature as rocks in the Marcellus Shale formation. The facility denied processing Marcellus waste since 2011. In May 2013 the facility signed another agreement to not accept or discharge wastewater Marcellus Shale formations until it has installed technology to remove the radiation compounds, metals and salts. According to the Duke researches the 'waste treatment solids/sludge' have exceeded U.S. regulations for radium disposal to soil. The study by Duke University also found that radium has been "absorbed and accumulated on the sediments locally at the discharge".
The New York Times noted that in 2011 the Pennsylvania DEP only made a "request — not a regulation" of gas companies to stop sending their flowback and waste water to public water treatment facilities. However, the DEP gave oil and gas operators 30 days to voluntarily comply, and they all did. Former Pennsylvania DEP Secretary John Hanger, who served under Gov. Ed Rendell, affirmed that municipal drinking water throughout the state is safe. "Every single drop that is coming out of the tap in Pennsylvania today meets the safe drinking water standard," Hanger said, but added that the environmentalists were accurate in stating that Pennsylvania water treatment plants were not equipped to treat hydraulic fracturing water. Current Pennsylvania DEP Secretary Michael Krancer serving under Gov. Tom Corbett has said it is "total fiction" that untreated wastewater is being discharged into the state's waterways, though it has been observed that Corbett received over a million dollars in gas industry contributions, more than all his competitors combined, during his election campaign. Unannounced inspections are not made by regulators: the companies report their own spills, and create their own remediation plans. A recent review of the state-approved plans found them to appear to be in violation of the law. Treatment plants are still not equipped to remove radioactive material and are not required to test for it. Despite this, in 2009 the Ridgway Borough's public sewage treatment plant, in Elk County, PA, facility was sent wastewater containing radium and other types of radiation at 275–780 times the drinking-water standard. The water being released from the plant was not tested for radiation levels. Part of the problem is that growth in waste produced by the industry has outpaced regulators and state resources. It should be noted that "safe drinking water standards" have not yet been set for many of the substances known to be in hydrofracturing fluids or their radioactivity levels,[not in citation given] and their levels are not included in public drinking water quality reports.
Tests conducted in Pennsylvania in 2009 found "no evidence of elevated radiation levels" in waterways. At the time radiation concerns were not seen as a pressing issue. In 2011 The New York Times reported radium in wastewater from natural gas wells is released into Pennsylvania rivers, and compiled a map of these wells and their wastewater contamination levels, and stated that some EPA reports were never made public. The Times' reporting on the issue has come under some criticism. A 2012 study examining a number of hydraulic fracturing sites in Pennsylvania and Virginia by Pennsylvania State University, found that water that flows back from gas wells after hydraulic fracturing contains high levels of radium.
Before 2011, flowback in Pennsylvania was processed by public wastewater plants, which were not equipped to remove radioactive material and were not required to test for it. Industry officials, though, claim that these levels are diluted enough that public health is not compromised. In 2010 the DEP limited surface water discharges from new treatment plants to 250 mg/l chloride. This limitation was designed to also limit other contaminants such as radium. Existing water treatment plants were allowed higher discharge concentrations. In April 2011, the DEP asked unconventional gas operators to voluntarily stop sending wastewater to the grandfathered treatment plants. The PADEP reported that the operators had complied.
A 2013 Duke University study sampled water downstream from a Pennsylvania wastewater treatment facility from 2010 through 2012 and found that creek sediment contained levels of radium 200 times background levels. The surface water had the same chemical signature as rocks in the Marcellus Shale formation along with high levels of chloride. The facility denied processing Marcellus waste after 2011. In May 2013 the facility signed another agreement to not accept or discharge Marcellus wastewater until it installed technology to remove the radioactive materials, metals and salts.
A 2012 study by researchers from the National Renewable Energy Laboratory, University of Colorado, and Colorado State University reported a reduction in the percentage of flowback treated through surface water discharge in Pennsylvania from 2008 through 2011. By late 2012, bromine concentrations had declined to previous levels in the Monongahela River, but remained high in the Allegheny.
Naturally occurring radioactive materials
The New York Times has reported radiation in hydraulic fracturing wastewater released into rivers in Pennsylvania. It collected data from more than 200 natural gas wells in Pennsylvania and has posted a map entitled Toxic Contamination from Natural Gas Wells in Pennsylvania. The Times stated "never-reported studies" by the United States Environmental Protection Agency and a "confidential study by the drilling industry" concluded that radioactivity in drilling waste cannot be fully diluted in rivers and other waterways. Despite this, as of early 2011 federal and state regulators did not require sewage treatment plants that accept drilling waste (which is mostly water) to test for radioactivity. In Pennsylvania, where the drilling boom began in 2008, most drinking-water intake plants downstream from sewage treatment plants have not tested for radioactivity since before 2006.
The New York Times reporting has been criticized and one science writer has taken issue with one instance of the newspaper's presentation and explanation of its calculations regarding dilution, charging that a lack of context made the article's analysis uninformative.
According to a Times report in February 2011, wastewater at 116 of 179 deep gas wells in Pennsylvania "contained high levels of radiation," but its effect on public drinking water supplies is unknown because water suppliers are required to conduct tests of radiation "only sporadically". The New York Post stated that the DEP reported that all samples it took from seven rivers in November and December 2010 "showed levels at or below the normal naturally occurring background levels of radioactivity", and "below the federal drinking water standard for Radium 226 and 228." However, samples taken by the state from at least one river, (the Monongahela, a source of drinking water for parts of Pittsburgh), were taken upstream from the sewage treatment plants accepting drilling waste water.
Radioactive tracer isotopes are sometimes injected with hydraulic fracturing fluid to determine the injection profile and location of created fractures. Sand containing gamma-emitting tracer isotopes is used to trace and measure fractures. A 1995 study found that radioactive tracers were used in over 15% of stimulated oil and gas wells. In the United States, injection of radionuclides are licensed and regulated by the Nuclear Regulatory Commission (NRC). According to the NRC, some of the most commonly used tracers include antimony-124, bromine-82, iodine-125, iodine-131, iridium-192, and scandium-46. A 2003 publication by the International Atomic Energy Agency confirms the frequent use of most of the tracers above, and says that manganese-56, sodium-24, technetium-99m, silver-110m, argon-41, and xenon-133 are also used extensively because they are easily identified and measured. According to a 2013 meeting of researchers who examined low (never exceeding drinking water standards) but persistent detections of iodine-131 in a stream used for Philadelphia drinking water: “Workshop participants concluded that the likely source of 131-I in Philadelphia’s source waters is residual 131-I excreted from patients following medical treatments,” but suggested that other potential sources also be studied, including hydraulic fracturing.
Hydraulic fracturing routinely produces microseismic events much too small to be detected except by sensitive instruments. These microseismic events are often used to map the horizontal and vertical extent of the fracturing. However, a 2012 US Geological Survey study reported that a "remarkable" increase in the rate of M ≥ 3 earthquakes in the US midcontinent "is currently in progress", having started in 2001 and culminating in a 6-fold increase over 20th century levels in 2011. The overall increase was tied to earthquake increases in a few specific areas: the Raton Basin of southern Colorado (site of coalbed methane activity), and gas-producing areas in central and southern Oklahoma, and central Arkansas. While analysis suggested that the increase is "almost certainly man-made", the United States Geological Survey (USGS) noted: "USGS's studies suggest that the actual hydraulic fracturing process is only very rarely the direct cause of felt earthquakes." The increased earthquakes were said to be most likely caused by increased injection of gas-well wastewater into disposal wells. The injection of waste water from oil and gas operations, including from hydraulic fracturing, into saltwater disposal wells may cause bigger low-magnitude tremors, being registered up to 3.3 (Mw).
Induced seismicity from hydraulic fracturing
Hydraulic fracturing routinely triggers microseismic events too small to be detected except with sensitive instruments. However, according to the US Geological Survey: “Reports of hydraulic fracturing causing earthquakes large enough to be felt at the surface are extremely rare, with only three occurrences reported as of late 2012, in Great Britain, Oklahoma, and Canada.” Bill Ellsworth, a geoscientist with the U.S. Geological Survey, has said, however: "We don't see any connection between fracking and earthquakes of any concern to society." The National Research Council (part of the National Academy of Sciences) has also observed that hydraulic fracturing, when used in shale gas recovery, does not pose a serious risk of causing earthquakes that can be felt.
Of greater concern are earthquakes associated with permitted Class II deep wastewater injection wells, many of which inject frac flowback and produced water from oil and gas wells.The USGS has reported earthquakes induced by disposal of produced water and hydraulic fracturing flowback into waste disposal wells in several location
In 2013, Researchers from Columbia University and the University of Oklahoma demonstrated that in the midwestern United States, some areas with increased human-induced seismicity are susceptible to additional earthquakes triggered by the seismic waves from remote earthquakes. They recommended increased seismic monitoring near fluid injection sites to determine which areas are vulnerable to remote triggering and when injection activity should be ceased.
Geophysicist Cliff Frohlich researched seismic activity on the Barnett Shale in Texas from 2009 to 2011. Frohlich set up temporary seismographs on a 70 kilometer grid covering the Barnett Shale in Texas. The seismographs sensed and located earthquakes 1.5 magnitude and larger in the area. The seismographs revealed a spacial association between earthquakes and Class II injection wells, most of which were established to dispose of flowback and produced water from Barnett Shale wells, near Dallas-Fort Worth and Cleburne, Texas. Some of the earthquakes were greater than magnitude 3.0, and were felt by peole at the surface, and reported in the local news. Earthquakes were reported in areas where there had previously been no recorded earthquakes. The study found that the great majority of Class II injection wells are not associated with earthquakes. Injection-induced earthquakes were strongly associated with wells injecting more than 150,000 barrels of water per month, and particularly after those wells had been injecting for more than a year. The majority of induced earthquakes occurred in Johnson County, which seemed more prone to induced earthquakes than other parts of the Barnett play.
Induced seismicity from water disposal wells
Earthquakes large enough to be felt by people have also been linked to some deep disposal wells that receive hydraulic fracturing flowback and produced water from hydraulically fractured wells. Flowback and brine from oil and gas wells are injected into EPA-regulated class II disposal wells. According to the EPA, approximately 144,000 such class II disposal wells in the US receive more than 2 billion US gallons (7.6 Gl) of wastewater each day. To date, the strongest earthquakes triggered by underground waste injection were three quakes close to Richter magnitude 5 recorded in 1967 near a Colorado disposal well which received non-oilfield waste.
According to the USGS only a small fraction of roughly 40,000 waste fluid disposal wells for oil and gas operations in the United States have induced earthquakes that are large enough to be of concern to the public. Although the magnitudes of these quakes has been small, the USGS says that there is no guarantee that larger quakes will not occur. In addition, the frequency of the quakes has been increasing. In 2009, there were 50 earthquakes greater than magnitude 3.0 in the area spanning Alabama and Montana, and there were 87 quakes in 2010. In 2011 there were 134 earthquakes in the same area, a sixfold increase over 20th century levels. There are also concerns that quakes may damage underground gas, oil, and water lines and wells that were not designed to withstand earthquakes.
The 2011 Oklahoma earthquake, the largest earthquake in Oklahoma history (most sources describe it as magnitude 5.7, although the US Geological Survey lists it as 5.6) has been linked by some researchers to decades-long injection of brine.
Class II disposal wells receiving brine from Fayetteville Shale gas wells in Central Arkansas triggered hundreds of shallow earthquakes, the largest of which was magnitude 4.7, and caused damage. In April 2011, the Arkansas Oil and Gas Commission halted injection at two of the main disposal wells, and the earthquakes abated.
Several earthquakes in 2011, including a 4.0 magnitude tremor on New Year's Eve that hit Youngstown, Ohio, are likely linked to a disposal of hydraulic fracturing wastewater, according to seismologists at Columbia University. By order of the Ohio Department of Natural Resources, the well had stopped injecting on December 30, 2011. The following day, after the 4.0 quake, Ohio governor John Kasich ordered an indefinite halt to injection in three additional deep disposal wells in the vicinity. The Department of Natural Resources proposed a number of tightened rules to its Class II injection regulations. The Department noted that there were 177 operational Class II disposal wells in the state, and that the Youngstown well was the first to produce recorded earthquakes since Ohio's Underground Injection Control program began in 1983.
Since 2008, more than 50 earthquakes, up to a magnitude of 3.5, have occurred in the area of north Texas home to numerous Barnett Shale gas wells, an area that previously had no earthquakes. No injuries or serious damage from the earthquakes has been reported. A study of quakes near the Dallas-Fort Worth Airport 2008–2009, concluded that the quakes were triggered by disposal wells receiving brine from gas wells.
A two-year study 2009–2011 by University of Texas researchers concluded that a number of earthquakes from Richter magnitude 1.5 to 2.5 in the Barnett Shale area of north Texas were linked to oilfield waste disposal into Class II injection wells. No quakes were linked to hydraulic fracturing itself. Researchers noted that there are more than 50,000 Class II disposal wells in Texas receiving oilfield waste, yet only a few dozen are suspected of triggering earthquakes.
On May 31, 2014, an earthquake registering at a magnitude of 3.4 occurred in Greeley, Colorado. The earthquake occurred near two hydraulic fracturing wastewater injection wells that are reportedly close to capacity. One waste injection well is 8,700 feet deep and 20 years old, while the other is 10,700 feet and just two years old. A research team from the University of Colorado Boulder have placed seismographs in the area to monitor further activity.
Abandoned wells could release methane. Fracturing uses lots of wells, and cement pads erode over time. A Scientific American article revealed that there are 300,000 to 500,000 abandoned oil and gas wells in Pennsylvania, and some of them might be leaking significant quantities of the potent greenhouse gas methane. This is an old problem for traditional oil wells, and a future problem for tight oil wells. It's costs too much to fix; and costs too much not to fix.
There is worldwide concern over the possible adverse public health implications of hydraulic fracturing activity. Although as of 2013[update] there is little evidence from which to draw a conclusion, intensive research is underway to ascertain whether there are impacts on a number of health conditions.
A 2013 review focusing on Marcellus shale gas hydraulic fracturing and the New York City water supply stated, "Although potential benefits of Marcellus natural gas exploitation are large for transition to a clean energy economy, at present the regulatory framework in New York State is inadequate to prevent potentially irreversible threats to the local environment and New York City water supply. Major investments in state and federal regulatory enforcement will be required to avoid these environmental consequences, and a ban on drilling within the NYC water supply watersheds is appropriate, even if more highly regulated Marcellus gas production is eventually permitted elsewhere in New York State."
Another 2013 review found that hydraulic fracturing technologies are not free from risk of contaminating groundwater, and described the controversy over whether the methane that has been detected in private groundwater wells near hydraulic fracturing sites has been caused by drilling or by natural processes.
A 2012 guidance for pediatric nurses, said that hydraulic fracturing had a potential negative impact on public health, and that pediatric nurses should be prepared to gather information on such topics so as to advocate for improved community health.
Early in January 2012, Christopher Portier, director of the US CDC's National Center for Environmental Health and the Agency for Toxic Substances and Disease Registry, argued that, in addition to the EPA's plans to investigate the impact of fracking on drinking water, additional studies should be carried out to determine whether wastewater from the wells can harm people or animals and vegetables they eat.
As of May 2012, the United States Institute of Medicine and United States National Research Council were preparing to review the potential human and environmental risks of hydraulic fracturing.
In 2011 in Colorado, the U.S. Agency for Toxic Substances and Disease Registry sampled 14 sites, and found high levels of carcinogens such as benzene, tetrachloroethene, and 1-4 dichlorobenzene. Also in that year, the EPA released new emissions guidelines stating that the old standards could have led to an unacceptably high risk of cancers for those living near drilling operations.
In 2013 the United States the Occupational Safety and Health Administration (OSHA) and the National Institute for Occupational Safety and Health (NIOSH) released a hazard alert based on data collected by NIOSH that "workers may be exposed to dust with high levels of respirable crystalline silica (silicon dioxide) during hydraulic fracturing." NIOSH notified company representatives of these findings and provided reports with recommendations to control exposure to crystalline silica and recommend that all hydraulic fracturing sites evaluate their operations to determine the potential for worker exposure to crystalline silica and implement controls as necessary to protect workers.
Research and lobbying
The New York Times has reported that, since the 1980s, the EPA investigations into the oil and gas industry's environmental impact—including the ongoing one into fracking's potential impact on drinking water—and associated reports had been narrowed in scope and/or had negative findings removed due to industry and government pressure.
A 2004 EPA study on hydraulic fracturing in coalbed methane wells concluded that the process was safe, and didn't warrant further study, because there was "no unequivocal evidence" of health risks to groundwater, and the fluids were neither necessarily hazardous nor able to travel far underground. The EPA report did find uncertainties in knowledge of how fracturing fluid migrates through rocks, and recommended that diesel fuel not be used as a component of fracturing fluid in coalbed methane walls due to its potential as a source of benzene contamination; in response, well service companies agreed to stop using diesel fuel in coalbed methane wells. One of the authors of the 2004 EPA report noted that it studied only hydraulic fracturing in coalbed methane wells.
The New York Times cited Weston Wilson, the agency whistle-blower, that the results of the 2004 EPA study were influenced by industry and political pressure. An early draft of the study discussed the possibility of dangerous levels of hydraulic fracturing fluid contamination and mentioned "possible evidence" of aquifer contamination. The final report concluded simply that hydraulic fracturing "poses little or no threat to drinking water". The study's scope was narrowed so that it only focused on the injection of hydraulic fracturing fluids, ignoring other aspects of the process such as disposal of fluids and environmental concerns such as water quality, fish kills, and acid burns. The study was concluded before public complaints of contamination started emerging.:780 The study's conclusion that the injection of hydraulic fracturing fluids into coalbed methane wells posed a minimal threat to underground drinking water sources may have influenced the 2005 Congressional decision that hydraulic fracturing should continue to be regulated by the states and not under the federal Safe Drinking Water Act.
A 2011 study by Congressional Democrats and reporting by the New York Times that same year found that hydraulic fracturing had resulted in significant increases of radioactive material including radium and carcinogens including benzene in major rivers and watersheds. At one site the amount of benzene discharged into the Allegheny River after treatment was 28 times accepted levels for drinking water. The congressional representatives called for better regulation and more disclosure.
|Wikinews has related news: Disposal of fracking wastewater poses potential environmental problems|
- Environmental issues in the United States
- Exemptions for hydraulic fracturing under United States federal law
- Pollution in the United States
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The most fundamental recommendation is for states to rigorously test their ground water before and after hydraulic fracturing takes place. A major difficulty in proving or disproving contamination in previous cases has been the lack of a baseline sample for the water supply in question. The group also raises a federal policy issue, namely whether fracturing fluids should continue to be exempt from Safe Drinking Water Act regulations. This exemption was an informal one until 2005, when it was codified as part of the Energy Policy Act. A consequence of this exemption is that drilling companies are not required to disclose the chemicals that make up the fracturing fluids, making testing for these chemicals in ground water more difficult.
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