Searching for dark energy with neutrons: With neutrons, scientists can now look for dark energy in the lab

Neutrons between parallel plates can test hypothetical forces in the universe. Credit: TU Vienna

It does not always take a huge accelerator to do particle physics: First results from a low energy, table top alternative takes validity of Newtonian gravity down by five orders of magnitude and narrows the potential properties of the forces and particles that may exist beyond it by more than one hundred thousand times. Gravity resonance spectroscopy, a method developed at the Vienna University of Technology, is so sensitive that it can now be used to search for Dark Matter and Dark Energy.

All the particles we know to exist make up only about five per cent of the mass and energy of the universe. The rest -- "Dark Matter" and "Dark Energy" -- remains mysterious. A European collaboration led by researchers from the Vienna University of Technology has now carried out extremely sensitive measurements of gravitational effects at very small distances at the Institut Laue-Langevin (ILL) in Grenoble. These experiments provide limits for possible new particles or fundamental forces, which are a hundred thousand times more restrictive than previous estimations.

Undiscovered Particles?

Dark matter is invisible, but it acts on matter by its gravitational pull, influencing the rotation of galaxies. Dark energy, on the other hand, is responsible for the accelerated expansion of the universe. It can be described by introducing a new physical quantity -- Albert Einstein's Cosmological Constant. Alternatively, so-called quintessence theories have been put forward: "Perhaps empty space is not completely empty after all, but permeated by an unknown field, similar to the Higgs-field," says Professor Hartmut Abele (TU Vienna), director of the Atominstitut and group leader of the research group. These theories are named after Aristotle's "quintessence" -- a hypothetical fifth element, in addition to the four classical elements of ancient Greek philosophy.

If new kinds of particles or additional forces of nature exist, it should be possible to observe them here on earth. Tobias Jenke and Hartmut Abele from the Vienna University of Technology developed an extremely sensitive instrument, which they used together with their colleagues to study gravitational forces. Neutrons are perfectly suited for this kind of research. They do not carry electric charge and they are hardly polarizable. They are only influenced by gravity -- and possibly by additional, yet unknown forces. Theoretical calculations analysing the behaviour of the neutrons were done by Larisa Chizhova, Professor Stefan Rotter and Professor Joachim Burgdörfer (TU Vienna). U. Schmidt from Heidelberg University and T. Lauer from TU Munich contributed with an analytic tool.

Forces at Small Distances

The technique they developed takes very slow neutrons from the strongest continuous ultracold neutron source in the world, at the ILL in Grenoble and funnels them between two parallel plates. According to quantum theory, the neutrons can only occupy discrete quantum states with energies which depend on the force that gravity exerts on the particle. By mechanically oscillating the two plates, the quantum state of the neutron can be switched. That way, the difference between the energy levels can be measured.

"This work is an important step towards modelling gravitational interactions at very short distances. The ultracold neutrons produced at ILL together with the measurement devices from Vienna are the best tool in the world for studying the predicted tiny deviations from pure Newtonian gravity," says Peter Geltenbort (ILL Grenoble).

Different parameters determine the level of precision required to find such tiny deviations -- for instance the coupling strength between hypothetical new fields and the matter we know. Certain parameter ranges for the coupling strength of quintessence particles or forces have already been excluded following other high-precision measurements. But all previous experiments still left a large parameter space in which new physical non-Newtonian 

phenomena could be hidden.

A Hundred Thousand Times Better than Other Methods

The new neutron method can test theories in this parameter range: "We have not yet detected any deviations from the well-established Newtonian law of gravity," says Hartmut Abele. "Therefore, we can exclude a broad range of parameters." The measurements determine a new limit for the coupling strength, which is lower than the limits established by other methods by a factor of a hundred thousand.

Even if the existence of certain hypothetical quintessence particles is disproved by these measurements, the search will continue as it is possible that new physics can still be found below this improved level of accuracy. Therefore, Gravity Resonance Spectroscopy will need to be improved further -- and increasing the accuracy by another few orders of magnitude seems feasible to the Abele's team. However, if even that does not yield any evidence of deviations from known forces, Albert Einstein would win yet another victory: his cosmological constant would then appear more and more plausible.

Source: Vienna University of Technology

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Deepwater Horizon spill: Much of the oil at bottom of the sea

Controlled burning of surface oil slicks during the Deepwater Horizon event.
Credit: David Valentine

Due to the environmental disaster's unprecedented scope, assessing the damage caused by the 2010 Deepwater Horizon spill in the Gulf of Mexico has been a challenge. One unsolved puzzle is the location of 2 million barrels of submerged oil thought to be trapped in the deep ocean.

UC Santa Barbara's David Valentine and colleagues from the Woods Hole Oceanographic Institute (WHOI) and UC Irvine have been able to describe the path the oil followed to create a footprint on the deep ocean floor. The findings appear today in the Proceedings of the National Academy of Sciences.

For this study, the scientists used data from the Natural Resource Damage Assessment process conducted by the National Oceanic and Atmospheric Administration. The United States government estimates the Macondo well's total discharge -- from the spill in April 2010 until the well was capped that July -- to be 5 million barrels.

By analyzing data from more than 3,000 samples collected at 534 locations over 12 expeditions, they identified a 1,250-square-mile patch of the deep sea floor upon which 2 to 16 percent of the discharged oil was deposited. The fallout of oil to the sea floor created thin deposits most intensive to the southwest of the Macondo well. The oil was most concentrated within the top half inch of the sea floor and was patchy even at the scale of a few feet.

The investigation focused primarily on hopane, a nonreactive hydrocarbon that served as a proxy for the discharged oil. Researchers analyzed the spatial distribution of hopane in the northern Gulf of Mexico and found it was most concentrated in a thin layer at the sea floor within 25 miles of the ruptured well, clearly implicating Deepwater Horizon as the source.

"Based on the evidence, our findings suggest that these deposits come from Macondo oil that was first suspended in the deep ocean and then settled to the sea floor without ever reaching the ocean surface," said Valentine, a professor of earth science and biology at UCSB. "The pattern is like a shadow of the tiny oil droplets that were initially trapped at ocean depths around 3,500 feet and pushed around by the deep currents. Some combination of chemistry, biology and physics ultimately caused those droplets to rain down another 1,000 feet to rest on the sea floor."

Valentine and his colleagues were able to identify hotspots of oil fallout in close proximity to damaged deep-sea corals. According to the researchers, this data supports the previously disputed finding that these corals were damaged by the Deepwater Horizon spill.

"The evidence is becoming clear that oily particles were raining down around these deep sea corals, which provides a compelling explanation for the injury they suffered," said Valentine. "The pattern of contamination we observe is fully consistent with the Deepwater Horizon event but not with natural seeps -- the suggested alternative."

While the study examined a specified area, the scientists argue that the observed oil represents a minimum value. They purport that oil deposition likely occurred outside the study area but so far has largely evaded detection because of its patchiness.

"This analysis provides us with, for the first time, some closure on the question 'Where did the oil go and how?' " said Don Rice, program director in the National Science Foundation's Division of Ocean Sciences. "It also alerts us that this knowledge remains largely provisional until we can fully account for the remaining 70 percent."

"These findings should be useful for assessing the damage caused by the Deepwater Horizon spill as well as planning future studies to further define the extent and nature of the contamination," Valentine concluded. "Our work can also help to assess the fate of reactive hydrocarbons, test models of oil's behavior in the ocean and plan for future spills."

Co-authors are G. Burch Fisher and Sarah C. Bagby, postdoctoral researchers in the Valentine Lab at UCSB; Robert K. Nelson, Christopher M. Reddy and Sean P. Sylva of WHOI; and Mary A. Woo of UC Irvine. The research was funded by the National Science Foundation.

Source:  University of California - Santa Barbara

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The Composite plane life cycle assessment shows lighter planes are the future

Boeing Dreamliner 787. Credit: Image courtesy of University of Sheffield

A global fleet of composite planes could reduce carbon emissions by up to 15 per cent, but the lighter planes alone will not enable the aviation industry to meet its emissions targets, according to new research.

The study, by the Universities of Sheffield, Cambridge and University College London, is the first to carry out a comprehensive life cycle assessment (LCA) of a composite plane, such as the Boeing Dreamliner 787 or Airbus 350, and extrapolate the results to the global fleet.
The LCA covers manufacture, use and disposal, using publicly available information on the Boeing Dreamliner 787 fuselage and from the supply chain -- such as the energy usage of the robots that construct the planes. The study compares the results to the traditional -- and heavier -- aluminium planes.

Emissions during the manufacture of composite planes are over double those of aluminium planes. But because the lighter aircraft use significantly less fuel, these increased emissions are offset after just a few international flights. Over its lifetime, a composite plane creates up to 20 per cent fewer CO2 emissions than its aluminium equivalent.

Professor in Advanced Materials Technologies at the University of Sheffield, Alma Hodzic, said: "This study shows that the fuel consumption savings with composites far outweigh the increased environmental impact from their manufacture. Despite ongoing debates within the industry, the environmental and financial savings from composites mean that these materials offer a much better solution."

The researchers fed the data from the LCA into a wider transport model to gauge the impact on CO2 emissions as composite planes are introduced into the global fleet over the next 25 years, taking into account other factors including population, economic prosperity, oil prices and speed of adoption of the new technology.

The study -- published in the International Journal of Life Cycle Assessment -- estimated that by 2050, composite planes could reduce emissions from the global fleet by 14-15 per cent relative to a fleet that maintains its existing aluminium-based configuration.

Professor in Energy and Transport at UCL, Andreas Schäfer, explains: "The overall emissions reduction for the global fleet is lower than the reduction for an individual plane, partly, because by 2050, not all the fleet will be of composite construction. New planes entering the fleet before 2020 could still be in use by 2050, but the faster the uptake of this technology, the greater the environmental benefits will be."

Dr Lynette Dray from the University of Cambridge added: "Given that global air traffic is projected to increase four-fold between now and 2050, changing the materials used could avoid 500 million tonnes of CO2 emissions in 2050 alone, a value that roughly corresponds to current emission levels."

Professor Hodzic commented: "The industry target is to halve CO2 emissions for all aircrafts by 2020 and while composites will contribute to this, it cannot be achieved by the introduction of lighter composite planes alone. However, our findings show that composites -- alongside other technology and efficiency measures -- should be part of the picture."

Source: University of Sheffield

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Fracking and pollution: Technology-dependent emissions of gas extraction in the US

The KIT measurement instrument on board of a minivan directly measures atmospheric emissions on site with a high temporal resolution.
Credit: Photo: F. Geiger/KIT

Not all boreholes are the same. Scientists of the Karlsruhe Institute of Technology (KIT) used mobile measurement equipment to analyze gaseous compounds emitted by the extraction of oil and natural gas in the USA. For the first time, organic pollutants emitted during a fracking process were measured at a high temporal resolution using a vapor capture system. The highest values measured by this process exceeded typical mean values in urban air by a factor of about one thousand, as was reported in the ACP journal.

Emission of trace gases by oil and gas fields was studied by the KIT researchers in the USA (Utah and Colorado) together with US institutes. Background concentrations and the waste gas plumes of single extraction plants and fracking facilities were analyzed. The air quality measurements of several weeks duration took place under the "Uintah Basin Winter Ozone Study" coordinated by the National Oceanic and Atmospheric Administration (NOAA).

The KIT measurements focused on health-damaging aromatic hydrocarbons in air, such as carcinogenic benzene. Maximum concentrations were determined in the waste gas plumes of boreholes. Some extraction plants emitted up to about a hundred times more benzene than others. The highest values of some milligrams of benzene per cubic meter air were measured downstream of an open fracking facility, where returning drilling fluid is stored in open tanks and basins. Much better results were reached by oil and gas extraction plants and plants with closed production processes. In Germany, benzene concentration at the workplace is subject to strict limits: The Federal Emission Control Ordinance gives an annual benzene limit of five micrograms per cubic meter for the protection of human health, which is smaller than the values now measured at the open fracking facility in the US by a factor of about one thousand. The researchers published the results measured in the journal Atmospheric Chemistry and Physics ACP.

"Characteristic emissions of trace gases are encountered everywhere. These are symptomatic of gas and gas extraction. But the values measured for different technologies differ considerably," Felix Geiger of the Institute of Meteorology and Climate Research (IMK) of KIT explains. He is one of the first authors of the study. By means of closed collection tanks and so-called vapor capture systems, for instance, the gases released during operation can be collected and reduced significantly.

"The gas fields in the sparsely populated areas of North America are a good showcase for estimating the range of impacts of different extraction and fracking technologies," explains Professor Johannes Orphal, Head of IMK. "In the densely populated Germany, framework conditions are much stricter and much more attention is paid to reducing and monitoring emissions."

Fracking is increasingly discussed as a technology to extract fossil resources from unconventional deposits. Hydraulic breaking of suitable shale stone layers opens up the fossil fuels stored there and makes them accessible for economically efficient use. For this purpose, boreholes are drilled into these rock formations. Then, they are subjected to high pressure using large amounts of water and auxiliary materials, such as sand, cement, and chemicals. The oil or gas can flow to the surface through the opened microstructures in the rock. Typically, the return flow of the aqueous fracking liquid with the dissolved oil and gas constituents to the surface lasts several days until the production phase proper of purer oil or natural gas. This return flow is collected and then reused until it finally has to be disposed of. Air pollution mainly depends on the treatment of this return flow at the extraction plant. In this respect, currently practiced fracking technologies differ considerably. For the first time now, the resulting local atmospheric emissions were studied at a high temporary resolution. Based on the results, emissions can be assigned directly to the different plant sections of an extraction plant. For measurement, the newly developed, compact, and highly sensitive instrument, a so-called proton transfer reaction mass spectrometer (PTR-MS), of KIT was installed on board of a minivan and driven closer to the different extraction points, the distances being a few tens of meters. In this way, the waste gas plumes of individual extraction sources and fracking processes were studied in detail.

Source: Karlsruhe Institute of Technology

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Is natural gas a 'bridge' to a hotter future?

This image shows a natural gas plant in Moss Landing, California. Credit: Carnegie President Matthew Scott

Natural gas power plants produce substantial amounts of gases that lead to global warming. Replacing old coal-fired power plants with new natural gas plants could cause climate damage to increase over the next decades, unless their methane leakage rates are very low and the new power plants are very efficient.

These are the principal findings of new research from Carnegie's Ken Caldeira and Xiaochun Zhang, and Nathan Myhrvold of Intellectual Ventures that compares the temperature increases caused by different kinds of coal and natural gas power plants. Their work is published in Environmental Research Letters.

There is an ongoing debate among people concerned with power plants and the future of energy policy and greenhouse gas emissions. Does it makes sense to replace old coal-fired power plants with new natural gas power plants today, as a bridge to a longer-term transition toward near zero-emission energy generation technologies such as solar, wind, or nuclear power? A key issue in considering the decision has been the potential climate effects of natural gas versus coal. Studies have yielded different results by focusing on power plants with different characteristics and using different definitions of what it means to be "better" for climate.

Carnegie's Caldeira and Zhang, along with Myhrvold, aimed to identify the key factors that are responsible for most of the difference in greenhouse gas emissions between individual gas and coal plants. The key factors, they found, are power plant efficiency and, in the case of natural gas plants, methane leakage during the supply process. They used these factors to derive a simple model for resulting temperature change caused by the carbon dioxide and methane released by a particular plant.

The team chose a simple and understandable way to compare climate effects of different types of power plants. They predicted how much global warming would be produced by different kinds of power plants during and after their period of operation.

They found that because natural gas plants are overall more efficient than coal plants, producing more energy per unit of carbon, they could cause less warming in the long term. However, it all depends on the amount of methane leakage that occurs. Natural gas plants that leak a substantial amount of methane during their supply process can produce more warming than comparable coal plants.

"If there is substantial natural gas leakage, then building new natural gas plants would lead to more near term climate damage than using the old dirty coal plants," explained Caldeira. "But natural gas plants would help reduce other types of air pollution that damage our health, and would be somewhat better for climate in the long term."

If faced with the choice of shutting down either a typical coal plant or a typical gas plant and methane leakage from the natural gas plant is below about 2 percent of total fuel, there would be a short-term climate benefit to shutting down the coal plant instead of the natural gas plant, the team found. But if methane leakage would be greater than 2 percent, there would be less warming in the near term if the natural gas plant were shut down instead of the coal plant.

Regardless, the team emphasized that meeting upcoming greenhouse gas emission targets will require deeper emissions cuts than just building natural gas plants with low methane leakage. If natural gas is to be a part of a future near-zero emission energy economy, methods for capturing and storing carbon from gas-fired power plants will likely be necessary.

Source: Carnegie Institution

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Carbon dioxide converted into a valuable resource

Arshe Said, postgraduate researcher at Aalto University, operating a pilot plant that converts CO2 and slag into Precipitated Calcium Carbonate (PCC). Credit: Image courtesy of Aalto University

Researchers at Aalto University have opened a pilot plant that converts CO2 and slag, the by-product of steel manufacturing, into a valuable mineral product. The product, Precipitated Calcium Carbonate (PCC), is used in e.g. plastics, papers, rubbers and paints. The innovative plant represents the next stage prior commercialization of a new process that consumes CO2 in order to convert a low-value by-product into a highly valuable resource for industry.

The potential economic and environmental benefits of this new technology are significant. "We are turning the industrial solid by-product from steel-manufacturing into a product which is 50 times more valuable," says Arshe Said, a postgraduate researcher at Aalto University. "Also, this process actually consumes CO2 and acts as a CO2 sink which benefits the environment greatly."

Current methods of PCC production require burning large amounts of limestone. "The conventional method involves large mining activities and has high CO2 emissions," points out Sanni Eloneva, D.Sc. (Tech).

Carbon intensive manufacturing industries are coming under increasing pressure from bodies such as the EU to reduce greenhouse gas emissions. "We believe this pilot plant will help to efforts by these industries to conform with government imposed emissions and waste targets," explains Professor Mika Järvinen.

In 2010, 13% of the total steel slag produced in Europe (16 Mt) went to the landfill. "In theory, if all the calcium in this steel slag could be recovered, approximately 13 Mt PCC/year could be produced, simultaneously sequestering nearly 6 Mt CO2/year," Järvinen continues.

The highly promising new technology also has other potential advantages. "We are currently investigating the possibility of extracting other valuable materials from the slag after the extraction of calcium," says Said.

The pilot PCC plant is now running in Otaniemi campus of Aalto University. The method used in the pilot is based on the patent owned by Aalto University Foundation together with Åbo Akademi and Rautaruukki Oyj (now part of SSAB).

Source:  Aalto University

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Hydraulic fracturing linked to earthquakes in Ohio

Seismograph (stock image). Hydraulic fracturing triggered a series of small earthquakes in 2013 on a previously unmapped fault in Harrison County, Ohio, according to a study. Credit: © hakandogu / Fotolia

Hydraulic fracturing triggered a series of small earthquakes in 2013 on a previously unmapped fault in Harrison County, Ohio, according to a study published in the journal Seismological Research Letters (SRL).

Nearly 400 small earthquakes occurred between Oct. 1 and Dec. 13, 2013, including 10 "positive" magnitude earthquake, none of which were reported felt by the public. The 10 positive magnitude earthquakes, which ranged from magnitude 1.7 to 2.2, occurred between Oct. 2 and 19, coinciding with hydraulic fracturing operations at nearby wells.

This series of earthquakes is the first known instance of seismicity in the area.
Hydraulic fracturing, or fracking, is a method for extracting gas and oil from shale rock by injecting a high-pressure water mixture directed at the rock to release the gas inside. The process of hydraulic fracturing involves injecting water, sand and chemicals into the rock under high pressure to create cracks. The process of cracking rocks results in micro-earthquakes. Hydraulic fracturing usually creates only small earthquakes, ones that have magnitude in the range of negative 3 (−3) to negative 1 (-1).

"Hydraulic fracturing has the potential to trigger earthquakes, and in this case, small ones that could not be felt, however the earthquakes were three orders of magnitude larger than normally expected," said Paul Friberg, a seismologist with Instrumental Software Technologies, Inc. (ISTI) and a co-author of the study.

The earthquakes revealed an east-west trending fault that lies in the basement formation at approximately two miles deep and directly below the three horizontal gas wells. The EarthScope Transportable Array Network Facility identified the first earthquakes on Oct. 2, 2013, locating them south of Clendening Lake near the town of Uhrichsville, Ohio. A subsequent analysis identified 190 earthquakes during a 39-hour period on Oct. 1 and 2, just hours after hydraulic fracturing began on one of the wells.

The micro-seismicity varied, corresponding with the fracturing activity at the wells. The timing of the earthquakes, along with their tight linear clustering and similar waveform signals, suggest a unique source for the cause of the earthquakes -- the hydraulic fracturing operation. The fracturing likely triggered slip on a pre-existing fault, though one that is located below the formation expected to confine the fracturing, according to the authors.

"As hydraulic fracturing operations explore new regions, more seismic monitoring will be needed since many faults remain unmapped." Friberg co-authored the paper with Ilya Dricker, also with ISTI, and Glenda Besana-Ostman originally with Ohio Department of Natural Resources, and now with the Bureau of Reclamation at the U.S. Department of Interior.

Source: Seismological Society of America

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Fracking: Gas leaks from faulty wells linked to contamination in some groundwater

As researchers study hydraulic fracturing, a team led by Thomas Darrah at The Ohio State University has identified a key source of groundwater contamination (labeled 5, center right) caused by faulty well casings.
Credit: Image courtesy of Thomas Darrah, The Ohio State University

A study has pinpointed the likely source of most natural gas contamination in drinking-water wells associated with hydraulic fracturing, and it's not the source many people may have feared.

What's more, the problem may be fixable: improved construction standards for cement well linings and casings at hydraulic fracturing sites.

A team led by a researcher at The Ohio State University and composed of researchers at Duke, Stanford, Dartmouth, and the University of Rochester devised a new method of geochemical forensics to trace how methane migrates under the earth. The study identified eight clusters of contaminated drinking-water wells in Pennsylvania and Texas.

Most important among their findings, published this week in the Proceedings of the National Academy of Sciences, is that neither horizontal drilling nor hydraulic fracturing of shale deposits seems to have caused any of the natural gas contamination.

"There is no question that in many instances elevated levels of natural gas are naturally occurring, but in a subset of cases, there is also clear evidence that there were human causes for the contamination," said study leader Thomas Darrah, assistant professor of earth sciences at Ohio State. "However our data suggests that where contamination occurs, it was caused by poor casing and cementing in the wells," Darrah said.

In hydraulic fracturing, water is pumped underground to break up shale at a depth far below the water table, he explained. The long vertical pipes that carry the resulting gas upward are encircled in cement to keep the natural gas from leaking out along the well. The study suggests that natural gas that has leaked into aquifers is the result of failures in the cement used in the well.

"Many of the leaks probably occur when natural gas travels up the outside of the borehole, potentially even thousands of feet, and is released directly into drinking-water aquifers" said Robert Poreda, professor of geochemistry at the University of Rochester.

"These results appear to rule out the migration of methane up into drinking water aquifers from depth because of horizontal drilling or hydraulic fracturing, as some people feared," said Avner Vengosh, professor of geochemistry and water quality at Duke.

"This is relatively good news because it means that most of the issues we have identified can potentially be avoided by future improvements in well integrity," Darrah said.

"In some cases homeowner's water has been harmed by drilling," said Robert B. Jackson, professor of environmental and earth sciences at Stanford and Duke. "In Texas, we even saw two homes go from clean to contaminated after our sampling began."

The method that the researchers used to track the source of methane contamination relies on the basic physics of the noble gases (which happen to leak out along with the methane). Noble gases such as helium and neon are so called because they don't react much with other chemicals, although they mix with natural gas and can be transported with it.

That means that when they are released underground, they can flow long distances without getting waylaid by microbial activity or chemical reactions along the way. The only important variable is the atomic mass, which determines how the ratios of noble gases change as they tag along with migrating natural gas. These properties allow the researchers to determine the source of fugitive methane and the mechanism by which it was transported into drinking water aquifers.

The researchers were able to distinguish between the signatures of naturally occurring methane and stray gas contamination from shale gas drill sites overlying the Marcellus shale in Pennsylvania and the Barnett shale in Texas.

The researchers sampled water from the sites in 2012 and 2013. Sampling sites included wells where contamination had been debated previously; wells known to have naturally high level of methane and salts, which tend to co-occur in areas overlying shale gas deposits; and wells located both within and beyond a one-kilometer distance from drill sites.

As hydraulic fracturing starts to develop around the globe, including countries South Africa, Argentina, China, Poland, Scotland, and Ireland, Darrah and his colleagues are continuing their work in the United States and internationally. And, since the method that the researchers employed relies on the basic physics of the noble gases, it can be employed anywhere. Their hope is that their findings can help highlight the necessity to improve well integrity.

Source: Ohio State University

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Environmental costs, health risks, and benefits of fracking examined

This is a fracking operations at a well pad near a farm over the Marcellus shale formation in Pennsylvania.
Credit: Robert Jackson, Stanford University

A strange thing happened on the way to dealing with climate change: Advances in hydraulic fracturing put trillions of dollars' worth of previously unreachable oil and natural gas within humanity's grasp.

The environmental costs -- and benefits -- from "fracking," which requires blasting huge amounts of water, sand and chemicals deep into underground rock formations, are the subject of new research that synthesizes 165 academic studies and government databases. The survey covers not only greenhouse gas impacts but also fracking's influence on local air pollution, earthquakes and, especially, supplies of clean water.

The authors are seven environmental scientists who underscore the real consequences of policy decisions on people who live near the wells, as well as some important remaining questions.
"Society is certain to extract more gas and oil due to fracking," said Stanford environmental scientist Robert Jackson, who led the new study. "The key is to reduce the environmental costs as much as possible, while making the most of the environmental benefits."

Fracking's consumption of water is rising quickly at a time when much of the United States is suffering from drought, but extracting natural gas with hydraulic fracturing and horizontal drilling compares well with conventional energy sources, the study finds. Fracking requires more water than conventional gas drilling; but when natural gas is used in place of coal or nuclear fuel to generate electricity, it saves water. From mining to generation, coal power consumes more than twice the water per megawatt-hour generated than unconventional gas does.

Unconventional drilling's water demand can be better or worse than alternative energy sources, the study finds. Photovoltaic solar and wind power use almost no water and emit no greenhouse gas, but cheap, abundant natural gas may limit their deployment as new sources of electricity. On the other hand, fracked gas requires less than a hundredth the water of corn ethanol per unit of energy.

Fracking's impact on both climate change and local air pollution is similar to its impact on water, finds the study "The Environmental Costs and Benefits of Fracking," published in the Annual Review of Environment and Resources.

Getting a fractured well going is more intense than for conventional oil and gas drilling, with potential health threats arising from increases in volatile organic compounds and air toxics.

But when natural gas replaces coal as a fuel for generating electricity, the benefits to air quality include lower carbon dioxide emissions than coal and almost none of the mercury, sulfur dioxide or ash.

Globally, though, relief to climate change is uncertain, the study finds. "While the increased gas supply reduces air pollution in U.S. cities downwind from coal-fired power plants, we still don't know whether methane losses from well pads and pipelines outweigh the lower carbon dioxide emissions," said Jackson.

In the eastern United States, fears of contaminated drinking water have raised more concerns than fracking's water consumption. Gas and chemicals from humanmade fractures thousands of meters underground very rarely seep upward to drinking-water aquifers, the study says. The real threats are failures in the steel and cement casings of wells nearer to the surface and the disposal of wastewater, the study finds. Numerous previous studies have shown that casings fail between 1 percent and 10 percent of the time, depending on geology and well construction.

Cases of groundwater contamination have been hotly debated, but the new study finds that the overwhelming evidence suggests it has happened, albeit not commonly. Is the methane contamination observed in drinking water a precursor to other toxins -- arsenic, various salts, radioactive radium and other metals -- making their way up slowly? The researchers do not yet know. A few recent studies suggest the answer could be "yes" in rare cases.

How oil and gas companies handle wastewater -- fluid used to fracture the shale that flows back up the well and water unleashed with the oil and gas -- shows the importance of state policies. "Wastewater disposal is one of the biggest issues associated with fracking," said co-author Avner Vengosh, a professor of geochemistry at Duke University.

Most fracking wastewater in the United States is injected deep underground, and an increasing amount is recycled for subsequent drilling or sent to advanced water treatment facilities. However, a handful of states still allow the wastewater to be used for watering cattle, sprayed onto roads for dust control or sent to municipal water-treatment plants not equipped to handle the chemicals involved.

All bad ideas, according to the authors of the new survey, who work at Duke University, MIT, Ohio State University, Newcastle University, Los Alamos National Laboratory, the National Oceanic and Atmospheric Administration and Stanford. One study they cite found that the agricultural use of fracking wastewater killed more than half of nearby trees within two years.

Injection of wastewater deep underground presents its own problems, the study finds. The practice occasionally has caused earthquakes strong enough to be felt by human beings, while the fracturing of shale miles below the surface rarely has done so. The dangers of seismicity can be reduced, however, if energy companies follow basic guidelines and undertake careful monitoring.

The study highlights several policies and practices that could optimize fracking's environmental cost-benefit balance, and it highlights the need for further research. For example, the direct impact on the health of nearby residents is virtually unknown. "Almost no comprehensive research has been done on health effects," said Jackson, "but decisions about drilling -- both approvals and bans on fracking -are made all the time based on assumptions about health risks."

Source: Stanford University

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Residual hydraulic fracturing water not a risk to groundwater

Sixty-one minutes of imbibition and evaporation of a 154 microliter bead of tap water on a 2.3 gram chip of the Union Springs Member of the Marcellus Formation. The drop disappeared in approximately 100 minutes. The photograph labeled 0 min was taken about 10 seconds after the bead was dropped on the Marcellus chip. Counter-current imbibition is indicated by methane bubbles floating up into the water bead from the Marcellus chip, starting on the left side of the bead at time = 0 min. This experiment was started 5 days after receiving fresh cuttings of the Union Springs from a horizontal well in PA.
Credit: Engelder, Penn State

Hydraulic fracturing -- fracking or hydrofracturing -- raises many concerns about potential environmental impacts, especially water contamination. Currently, data show that the majority of water injected into wells stays underground, triggering fears that it might find its way into groundwater. New research by a team of scientists should help allay those fears.

In a paper published in the current issue of the Journal of Unconventional Oil and Gas Resources, Terry Engelder, professor of geosciences, Penn State; Lawrence Cathles, professor of earth and atmospheric sciences, Cornell University; and Taras Bryndzia, geologist, Shell International Exploration and Production Inc., report that injected water that remains underground is sequestered in the rock formation and therefore does not pose a serious risk to water supplies.

Hydraulic fracturing is a drilling technique commonly used to extract gas from previously inaccessible "tight" gas reserves, including gas trapped in shale formations such as the Marcellus. During this technique between 1.2 and 5 million gallons of water mixed with sand and chemical additives are injected at high pressure into each well to fracture the rock and release the gas.

Typically less than half of the injected water returns to the surface as "flowback" or, later, production brine, and in many cases recovery is less than 30 percent. In addition to the chemical additives, flowback water contains natural components of the gas shale including salt, some metals, and radionuclides and could impair water quality if released without proper treatment. While flowback water can be managed and treated at the surface, the fate of the water left in place, called residual treatment water or RTW, was previously uncertain.

Some have suggested that RTW may be able to flow upward along natural pathways, mainly fractures and faults, and contaminate overlying groundwater. Others have proposed that natural leakage of the Marcellus is occurring without human assistance through high-permeability fractures connecting the Marcellus directly to the water table and that hydraulic fracturing could worsen this situation.

The researchers report that ground water contamination is not likely because contaminant delivery rate would be too small even if leakage were possible, but more importantly, upward migration of RTW is not plausible due to capillary and osmotic forces that propel RTW into, not out of, the shale. Their study indicates that RTW will be stably retained within the shale formation due to multiphase capillary phenomena.

"Capillary forces and coupled diffusion-osmosis processes are the reasons the brines and the RTW are not free to escape from gas shale," said Engelder. "The most direct evidence of these forces is the observation that more than half the treatment waters are not recovered. Introducing treatment water causes gas shale to act like a sponge based on the principles of imbibition.

"Imbibition into gas shale is made possible by the high capillary suction that a fine-grained, water-wet shale matrix can exert on water. As water is wicked into gas shale, the natural gas in the shale is pushed out. The capillary forces that suck the RTW into the gas shale keep it there."

Estimating imbibition is complicated, but simple experiments conducted by the researchers show that water can be readily imbibed into gas shale in quantities fully capable of sequestering RTW. The researchers demonstrated this process in a series of experiments on cuttings recovered from the Union Springs Member of the Marcellus gas shale in Pennsylvania and on core plugs of Haynesville gas shale from NW Louisiana.

"The hydraulic fracturing fluid consists mostly of very low-salinity surface water, while the shale contains high concentrations of water soluble inorganic cations and anions," said Engelder. "During hydraulic fracturing water is lost to the formation while inorganic cations and anions are transferred from the formation to the hydraulic fracture. Diffusion osmosis assists the rapid imbibition of water by the shale and diffusion of ions into the treatment water causing the high salinities observed in flowback fluids. The point to be emphasized here is that this osmotic pressure pushes the hydraulic fracture fluids into the shale matrix, expelling gas and cations to make high-salinity flowback in the process."

The researchers believe that in addition to there not being enough water in the shale to contaminate groundwater, the most important point of their work is that multiphase capillary phenomena must be considered in cases where a non-aqueous fluid is present in the subsurface pore space. The vadose zone -- the area from the surface to the groundwater -- and oil and gas migration cannot be understood using single-phase, porous-media flow methods, and any policy insights or prescriptions based on single-phase considerations will be fatally flawed, they argue.

"The practical implication is that hydrofracture fluids will be locked into the same 'permeability jail' that sequestered overpressured gas for over 200 million years," said Engelder. "If one wants to dispose of fracking waters, one could probably not choose a safer way to do so than to inject them into a gas shale."

Source: Penn State

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Nanoparticle research could enhance oil recovery, tracing of fracking fluid

William Sanford and Vivian Li.
Credit: Image courtesy of Colorado State University

Two Colorado State University researchers are examining how nanoparticles move underground, knowledge that could eventually help improve recovery in oil fields and discover where hydraulic fracking chemicals travel.

Vivian Li, assistant professor in the Department of Design and Merchandising, and William Sanford, associate professor in the Department of Geosciences, are trying to find patterns in how certain nanoparticles move underground. If successful, they could train the nanoparticles to indicate when specific chemicals are present in the subsurface, including those found in underground water deposits. These modified "smart" nanoparticles, known as tracers, could sense high pH levels or the presence of hydraulic fracking chemicals.

In the initial phase of their research, funded through a grant from the CSU Water Center, Li and Sanford are testing their specially engineered carbon nanoparticle to see how it moves through the ground. Once they understand how the particle travels through a number of subsurface environments, it could eventually be used to search for chemicals in some of Earth's most hostile underground environments.

"We also want to see how nanoparticles affect the composition of the natural environment and how certain elements found in the ground alter the composition of the nanoparticle," explained Li.
Temperature, water saturation, and the physical and chemical composition of the soil are the primary factors that can alter the movement of nanoparticles.

Hydraulic fracturing of wells has caused a political firestorm in recent years, as Colorado residents have questioned the health and safety risks of injecting chemicals into the ground to free oil and natural gas. There is still debate about whether these chemicals are harming the environment, and some question where the chemicals go after injection, fearing they may be contaminating groundwater supplies.

Using tracers, Li and Sanford theorize they could inject the particles into the earth near fracking sites and allow them to follow subsurface water flow paths to a distance away from the injection site. If the recovered tracers are fluorescent, they are reacting to the fracking chemical they were engineered to detect, demonstrating the path those chemicals traveled.

In continuation of Li's post-doctorate work, these tracers could also be used to improve the recovery of oil from reserves deep within the earth, which would allow scientists to increase the amount of oil that can be pumped, saving time and money on drilling new wells.

"Only about 50 percent of the Earth's oil reservoirs are being tapped," Li said. "With the potential to quickly drain the current oil reserves, the need to improve oil recovery and find the other hidden 50 percent becomes extremely important."

However, these reservoirs are often very deep in the ground and can be home to extreme conditions that make it difficult for nanoparticles to survive. Many nanoparticles that have been developed cannot withstand the high salinity of the oil reserve and deteriorate in the process of finding the oil. However, Li and Sanford believe they have engineered a nanoparticle that can both survive in the harsh environment and keep its smart abilities for a long period of time.

"The uses of these nanoparticles are potentially quite extensive," explained Sanford. "By creating smart particles we can see how contaminants are distributed in the subsurface, the recovery of economic minerals in water can be done, and the uses in the oil industry are many-fold."
Still in the early stages of the research, Li and Sanford are patenting their new nanoparticle and continue to test it in preparation for studies in the field.

The Department of Design and Merchandising is in CSU's College of Health and Human Sciences. The Department of Geosciences is part of the Warner College of Natural Resources.

Source: Colorado State University

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Natural gas saves water, even when factoring in water lost to hydraulic fracturing

For every gallon of water used to produce natural gas through hydraulic fracturing, Texas saved 33 gallons of water by generating electricity with that natural gas instead of coal (in 2011).

A new study finds that in Texas, the U.S. state that annually generates the most electricity, the transition from coal to natural gas for electricity generation is saving water and making the state less vulnerable to drought.

Even though exploration for natural gas through hydraulic fracturing requires significant water consumption in Texas, the new consumption is easily offset by the overall water efficiencies of shifting electricity generation from coal to natural gas. The researchers estimate that water saved by shifting a power plant from coal to natural gas is 25 to 50 times as great as the amount of water used in hydraulic fracturing to extract the natural gas. Natural gas also enhances drought resilience by providing so-called peaking plants to complement increasing wind generation, which doesn't consume water.

The results of The University of Texas at Austin study are published this week in the journal Environmental Research Letters.

The researchers estimate that in 2011 alone, Texas would have consumed an additional 32 billion gallons of water -- enough to supply 870,000 average residents -- if all its natural gas-fired power plants were instead coal-fired plants, even after factoring in the additional consumption of water for hydraulic fracturing to extract the natural gas.

Hydraulic fracturing is a process in which water, sand and chemicals are pumped at high pressure into a well to fracture surrounding rocks and allow oil or gas to more easily flow. Hydraulic fracturing and horizontal drilling are the main drivers behind the current boom in U.S. natural gas production.
Environmentalists and others have raised concerns about the amount of water that is consumed. In Texas, concerns are heightened because the use of hydraulic fracturing is expanding rapidly while water supplies are dwindling as the third year of a devastating drought grinds on. Because most electric power plants rely on water for cooling, the electric power supply might be particularly vulnerable to drought.

"The bottom line is that hydraulic fracturing, by boosting natural gas production and moving the state from water-intensive coal technologies, makes our electric power system more drought resilient," says Bridget Scanlon, senior research scientist at the university's Bureau of Economic Geology, who led the study.

To study the drought resilience of Texas power plants, Scanlon and her colleagues collected water use data for all 423 of the state's power plants from the Energy Information Administration and from state agencies including the Texas Commission on Environmental Quality and the Texas Water Development Board, as well as other data.

Since the 1990s, the primary type of power plant built in Texas has been the natural gas combined cycle (NGCC) plant with cooling towers, which uses fuel and cooling water more efficiently than older steam turbine technologies. About a third of Texas power plants are NGCC. NGCC plants consume about a third as much water as coal steam turbine (CST) plants.

The other major type of natural gas plant in the state is a natural gas combustion turbine (NGCT) plant. NGCT plants can also help reduce the state's water consumption for electricity generation by providing "peaking power" to support expansion of wind energy. Wind turbines don't require water for cooling; yet wind doesn't always blow when you need electricity. NGCT generators can be brought online in a matter of seconds to smooth out swings in electricity demand. By combining NGCT generation with wind generation, total water use can be lowered even further compared with coal-fired power generation.

The study focused exclusively on Texas, but the authors believe the results should be applicable to other regions of the U.S., where water consumption rates for the key technologies evaluated -- hydraulic fracturing, NGCC plants with cooling towers and traditional coal steam turbine plants -- are generally the same.

The Electric Reliability Council of Texas, manager of the state's electricity grid, projects that if current market conditions continue through 2029, 65 percent of new power generation in the state will come from NGCC plants and 35 percent from natural gas combustion turbine plants, which use no water for cooling, but are less energy efficient than NGCC plants.

"Statewide, we're on track to continue reducing our water intensity of electricity generation," says Scanlon.

Hydraulic fracturing accounts for less than 1 percent of the water consumed in Texas. But in some areas where its use is heavily concentrated, it strains local water supplies, as documented in a 2011 study by Jean-Philippe Nicot of the Bureau of Economic Geology. Because natural gas is often used far from where it is originally produced, water savings from shifting to natural gas for electricity generation might not benefit the areas that use more water for hydraulic fracturing.


Source: University of Texas at Austin.

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Tapping a valuable resource or invading the environment? Research examines the start of fracking in Ohio

A drilling rig in Carroll County, Ohio. Credit: Amy Townsend-Small

A new study is examining methane and other components in groundwater wells, in advance of drilling for shale gas that's expected over the next several years in an Ohio region.

Amy Townsend-Small, a University of Cincinnati assistant professor of geology, will present on the study on Sept. 27, at the 10th Applied Isotope Geochemistry Conference in Budapest, Hungary.
The team of UC researchers spent a year doing periodic testing of groundwater wells in Carroll County, Ohio, a section of Ohio that sits along the shale-rich Pennsylvania-West Virginia borders. The study analyzed 25 groundwater wells at varying distances from proposed fracking sites in the rural, Appalachian, Utica Shale region of Carroll County. Because the region is so rural, the majority of the population relies on groundwater wells for their water supply.

"This is a major area for shale gas drilling in Ohio, and one reason is because shales in the area are thought to have a good amount of liquid fuel as well as natural gas," says Townsend-Small.
The researchers are currently analyzing samples from groundwater wells over a one-year period, with water samples drawn every three-to-four months.

The samples are being analyzed for concentrations of methane as well as hydrocarbons -- a carcinogenic compound -- and salt, which is pulled up in the fracking water mixture from the shales, which are actually ancient ocean sediments.

"We're examining changes over time resulting from fracking, and since this is just beginning in Ohio, we have the opportunity to make some baseline assessments," says Townsend-Small.

Hydraulic fracturing, or fracking, involves using millions of gallons of water mixed with sand and chemicals to break up organic-rich shale to release natural gas resources. Proponents say fracking promises a future in lower energy prices, cleaner energy and additional jobs amid a frail economy. Opponents raise concerns about the practice leading to increased methane gas levels (known as the greenhouse gas) and other contamination -- resulting from spillover of fracking wastewater -- of groundwater in shale-rich regions.

Townsend-Small explains that some groundwater wells naturally hold a certain level of methane due to the decomposition of organic matter. It's not toxic in drinking water, but high levels can result in explosion. The study includes measurements of stable isotopes, which can indicate whether methane is derived from natural organic matter decomposition or from fossil fuels.

Other chemicals in fracking wastewater are toxic and dangerous for drinking water. Future UC research includes measurements of some of these compounds, as fracking progresses in the region.
The U.S. Energy Information Administration reported this summer that natural gas reserve additions in 2011 ranked as the second-largest annual increase since 1977, with hydraulic fracturing adding to increased oil and gas reserves.

The Ohio Department of Natural Resources reports that 882 sites in the state of Ohio have been awarded permits for fracking. In Carroll County, 327 sites have been awarded permits and 236 have been drilled.

Funding for the UC study was supported in coordination with UC Foundation by a $20,000 grant from the Missouri-based Deer Park Foundation, a $2,500 grant from the Cincinnati-based David and Sara Weston Foundation and an $85,714 grant from the Ohio Board of Regents.

Townsend-Small and her colleagues in the UC Department of Geology were also awarded a $400,000, 3-year grant from the National Science Foundation (EAR-1229114) for an isotope ratio mass spectrometer. The instrument measures the stable isotope composition of methane, which can indicate whether it is derived from biological activity or natural gas.

Source: University of Cincinnati

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The Hydraulic fracturing in Michigan investigated

Geology of Michigan. Credit: MDEQ

University of Michigan researchers today released seven technical reports that together form the most comprehensive Michigan-focused resource on hydraulic fracturing, the controversial natural gas and oil extraction process commonly known as fracking.

The studies, totaling nearly 200 pages, examine seven critical topics related to the use of hydraulic fracturing in Michigan, with an emphasis on high-volume methods: technology, geology and hydrogeology, environment and ecology, public health, policy and law, economics, and public perceptions.

While considerable natural gas reserves are believed to exist in the state and high-volume hydraulic fracturing has the potential to help access them, possible impacts to the environment and to public health must be addressed, the U-M researchers concluded.

Though modern high-volume hydraulic fracturing is not widely used in Michigan today, a main premise of the U-M study is that the technique could become more widespread due to a desire for job creation, economic growth, energy independence and cleaner fuels.

"There's a lot of interest in high-volume hydraulic fracturing, but there really isn't much activity at the moment in Michigan," said John Callewaert, project director and director of integrated assessment at U-M's Graham Sustainability Institute, which is overseeing the project. "That's why now is a good time to do this assessment."

These reports conclude the first phase of a two-year U-M project known formally as the Hydraulic Fracturing in Michigan Integrated Assessment. The seven documents -- which should not be characterized or cited as final products of the integrated assessment -- provide a solid informational foundation for the project's next phase, an analysis of various hydraulic fracturing policy options. That analysis is expected to be completed in mid-2014 and will be shared with government officials, industry experts, other academics, advocacy groups and the general public.

"Nothing like this has been done before in Michigan," Callewaert said. "Having this comprehensive, state-specific set of reports will be an invaluable resource that will help guide future decision-making on this issue -- and hopefully will help Michigan avoid some of the pitfalls encountered in other states."

Conclusions of the reports, which were written by faculty-led, student-staffed teams from various disciplines, include:

• Technology. In view of the current low price of natural gas, the high cost of drilling deep shale formations and the absence of new oil discoveries, it is unlikely that there will be significant growth of the oil and gas industry in Michigan in the near-term future. However, considerable reserves of natural gas are believed to exist in deep shale formations such as the Utica-Collingwood, which underlies much of Michigan and eastern Lake Huron and extends into Ontario, Canada.

• Geology/hydrogeology. A recent flurry of mineral rights acquisitions in the state associated with exploratory drilling suggests the potential for growth in natural gas production through high-volume hydraulic fracturing, though only a handful of such wells have been drilled to date. "Michigan is thus in a unique position to assess the future of high-volume hydraulic fracturing before the gas boom begins."

• Environment/ecology. Potential impacts of hydraulic fracturing on the environment are significant and include increased erosion and sedimentation, increased risk of aquatic contamination from chemical spills or equipment runoff, habitat fragmentation and resulting impacts on aquatic and terrestrial organisms, loss of stream riparian zones, and reduction of surface waters available to plants and animals due to the lowering of groundwater levels.

• Public health. Possible hazards in the surrounding environment include impaired local and regional air quality, water pollution and degradation of ecosystems. Possible hazards in nearby communities include increased traffic and motor vehicle accidents, stress related to risk perception among residents, and boomtown-associated effects such as a strained health care system and road degradation.

• Policy/law. The state is the primary source of law and policy governing hydraulic fracturing in Michigan. The operator of a high-volume hydraulically fractured well must disclose the hazardous constituents of chemical additives to the state Department of Environmental Quality for each additive within 60 days of well completion. Unlike most other states, DEQ does not require operators to report toFracFocus.org, a nationwide chemical disclosure registry. • Economics. The gas extraction industry creates employment and income for Michigan, but the employment effects are modest compared with other industries and not large enough to "make or break" the state's economy. In the future, the number of technical jobs in the industry will likely increase, while less-skilled laborer positions will decline.

• Public perceptions. A slight majority of Michigan residents believe the benefits of fracking outweigh the risks, but significant concerns remain about the potential impacts to human health, the environment and groundwater quality. The public tends to view the word "fracking" as the entirety of the natural gas development process, from leasing and permitting, to drilling and well completion, to transporting and storing wastewater and chemicals. Industry and regulatory agencies hold a much narrower definition that is limited to the process of injecting hydraulic fracturing fluids into a well. These differences in perceived meaning can lead to miscommunications that ultimately increase mistrust among stakeholders.

In fracking, water, sand and chemicals (in a mix known as hydraulic fracturing fluid) are injected under high pressure deep underground to crack sedimentary rocks, such as shale, and free trapped natural gas or oil. Though the process has been used for more than half a century to improve well production, recent technical advances have helped unlock vast stores of previously inaccessible natural gas and oil, resulting in a boom in some parts of the United States.

Chief among the technical advances are directional drilling and high-volume hydraulic fracturing, which are often used together. In directional drilling, the well operator bores vertically down to the rock formation, then follows the formation horizontally. High-volume fracking -- the focus of recent attention and public concern -- is defined by the state of Michigan as a well that uses more than 100,000 gallons of hydraulic fracturing fluid. For reference, an Olympic-size swimming pool holds about 660,000 gallons of water.

Since the late 1940s, an estimated 12,000 gas and oil wells have been drilled in Michigan using hydraulic fracturing, without any reported contamination issues. Most of those wells have been relatively shallow vertical wells that each used about 50,000 gallons of water.

But recently, a small number of deep, directionally drilled, high-volume hydraulically fractured wells have been completed in the northern part of the Lower Peninsula. Those wells sometimes use several million gallons of water, and one Michigan well required more than 20 million gallons.

Since 2010, when the Petoskey Pioneer Well spurred interest in high-volume hydraulically fractured wells in Michigan, 19 such wells are known to have been completed in the state, according to Sara Gosman, a lecturer at the U-M Law School and author of the technical report on policy/law.

In the public perceptions report, authors Kim Wolske and Andrew Hoffman of the U-M Erb Institute for Global Sustainable Enterprise note that chemical additives in high-volume hydraulic fracturing fluids "remain a primary point of contention for many stakeholders in Michigan." Many nonprofits and concerned citizens stress the point that operators of high-volume wells are not required to report the composition of those fluids to the state until 60 days after the hydraulic fracturing event.

The often-repeated concern is that if a spill were to occur, responders would not be as well-prepared as they would have been if the fluid composition had been known beforehand, Wolske and Hoffman note.

Though groundwater contamination is often cited as a top concern, surface contamination from spills and improper disposal of waste fluids likely carries the greatest risk for harmful water-quality impacts, due to proximity to potable water resources, according to the geology/ hydrogeology report written by Brian Ellis, assistant professor in the Department of Civil and Environmental Engineering.

When a well is fracked, the fluid is injected into rock formations to create cracks and to prop them open. Of the total volume of hydraulic fracturing fluids injected into a well, amounts varying from 10 percent to 70 percent may return to the surface as "flowback water" after the pressure is reduced and gas or oil begin to flow toward the wellhead.

In Michigan high-volume hydraulically fractured wells, the average amount of flowback water returning to the surface is about 37 percent of injected volumes, according to the Ellis report.

The flowback water is highly saline and can contain elevated levels of heavy metals and naturally occurring radioactive elements, in addition to methane and the original chemical additives in the fracturing fluids. In Michigan, common hydraulic fracturing fluid additives include ethylene glycol, hydrochloric acid, isopropyl alcohol, methanol and ammonium persulfate, according to the Ellis report.

"However, since in Michigan all flowback is disposed of by deep-well injection and it is not allowed to sit in open pits, the risk of this type of contamination will be lower than in other states without such disposal opportunities and regulations," Ellis wrote.

On the topic of potential water contamination, the environment/ecology report notes that Michigan's dense, interconnected aquatic ecosystems (streams, rivers, lakes, inland and coastal wetlands) and the groundwater aquifers to which they are linked are of particular concern. The connectivity between surface and groundwater bodies "can lead to impacts distant from, as well as close to, drilling sites," according to the report by G. Allen Burton, professor in the School of Natural Resources and Environment and director of the U-M Water Center, and Knute Nadelhoffer, professor of ecology and evolutionary biology and director of the U-M Biological Station.

The potential migration of methane, the main component of natural gas, into groundwater reservoirs has also received a lot of attention lately.

But the probability of significant methane leakage associated with deep-shale drilling involving hydraulic fracturing in Michigan "is quite low provided that best practices are adhered to," according to the U-M report on hydraulic fracturing technologies written by John Wilson, a consultant to the U-M Energy Institute, and Johannes Schwank, professor of chemical engineering.

The greatest challenge to understanding the potential public health risks of hydraulic fracturing in Michigan is the lack of state-specific data, according to Niladri Basu, author of the public health technical report and a former faculty member at the U-M School of Public Health. While thousands of hydraulically fractured wells have been drilled in Michigan, the potential public health risks related to these facilities have been poorly documented, Basu wrote.

For example, while operators of high-volume fracking wells are required to disclose the contents of their hydraulic fracturing fluids, operators of the 12,000 or so low-volume wells in the state are not. "There needs to be much greater understanding of what chemicals are being used in every well, with information related to volumes, amounts, disposal plans, etc., made available," Basu wrote.

The U-M hydraulic fracturing study is expected to cost at least $600,000 and is being funded by U-M through its Graham Sustainability Institute, Energy Institute and Risk Science Center. State regulators, oil and gas industry representatives, staffers from environmental nonprofits, and peer reviewers provided input to the technical reports, and more than 100 public comments were considered.

In addition to the study authors mentioned above, the technical report authors include Roland Zullo, assistant research scientist, U-M Institute for Research on Labor, Employment and the Economy (economics report).

Technical reports: http://graham.umich.edu/knowledge/ia/hydraulic-fracturing/technical-reports

Source: University of Michigan

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