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USA fracking news. New Research – Disputes a fundamental industry claim. [Five news articles]

 Fracking news. New Fracking Research: Disputes a fundamental industry claim.   News Postings Drinking water contamination news. Save our water  Volume 3


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 Fracking news New Fracking Research Disputes a fundamental industry claim. Kansas landfills near a fracking site have declined to take in the drilling fluid waste  Drinking water contamination news

 

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Hydraulic fracking is a process in which water, sand and chemicals are injected into deep shale formations to crack the rock and free trapped gas

New Fracking Research:

Disputes a fundamental industry claim.

Michael Kelley | Jul. 10, 2012, 11:04 AM | 1,509 | 16

A primary claim of the hydraulic fracking industry is that deeply buried rock layers will always seal and contain the dangerous chemicals that are injected thousands of feet underground.

But a new study released in the Proceedings of the National Academy of Sciences concluded that fracking for natural gas under Marcellus Shale in Pennsylvania may lead to harmful gas or liquids flowing upward and contaminating drinking-water supplies.

The study found that salty, mineral-rich fluids deep beneath Pennsylvania’s natural gas fields are seeping upward thousands of feet into drinking water supplies. Although it found no evidence of fracking chemicals doing the same, the findings suggest that there are paths that would let hazardous gas or fluids flow up after drilling:

“The biggest implication is the apparent presence of connections from deep underground to the surface,” Robert Jackson, a biology professor at Duke University and one of the study’s authors, told ProPublica. “It’s a suggestion based on good evidence that there are places that may be more at risk.”

The study supplements another recent study that used computer modeling to predict how fracking fluids would move over time and found that they could migrate toward drinking water supplies far more quickly than experts have previously predicted.

Critics of the study said that it doesn’t prove that fracking fluids have traveled up to aquifers and argue that gas and water from fracking will flow into the well and not up through fissures that may exist.

Hydraulic fracking is a process in which water, sand and chemicals are injected into deep shale formations to crack the rock and free trapped gas.

The natural gas in Marcellus Shale, which stretches from New York to Tennessee and may hold enough gas to supply the U.S. for three years, has led to permits for more than 11,000 wells. The practice had been an economic boon for Pennsylvania and has helped set decade-low natural gas prices nationwide.

But there is growing evidence of the hazards of fracking. Last year some of the same Duke researchers published findings that methane contamination of drinking water accompanied fracking.

Researchers at the Colorado School of Public Health recently found that air pollution caused by hydraulic fracturing raises the risk of acute and chronic health problems for those living near natural gas drilling sites.

The oil and gas industry doesn’t have to publicly disclose most of the chemicals it pumps into the ground, but we know the list contains several carcinogens. Even landfills have begun to reject fracking fluid waste.

The powers that be may know the risk of those chemicals being known as there is a new “doctor gag rule” law in Pennsylvania that provides doctors access to trade-secret chemicals used in natural gas drilling so that they can treat people who have been made sick but prohibits doctors from sharing that information with anyone, even other doctors.

No matter what science concludes, there is no doubt that the fracking industry has a powerful lobby to protect its interests. Read more:

Natural GasConventional Drilling Areas And Shale Basins

Fracking debate at Aspen Ideas Fest:

Fracking debate at Aspen Ideas Fest: Audience decides that fracking does more harm than good.

The Colorado Independent | By Troy Hooper Posted: 07/06/2012 5:02 pm

An emerging oil boom has been sparked by modern technologies using horizontal drilling and a technique known as hydraulic fracturing, or “fracking,” to coax out oil and gas. The potential production from the Mississippian Lime formation here – and its impact on domestic energy supplies – remains uncertain. But the use of the technology to unlock energy supplies previously unavailable i

From The Colorado Independent’s Troy Hooper:

ASPEN — After an Oxford-style debate Sunday night, environmental attorneys Deborah Goldberg and Katherine Hudson convinced 15 percent of the audience here to change their minds about hydraulic fracturing. Before the debate, only 38 percent of the audience agreed that the detriments of hydraulic fracturing are greater than its benefits but afterward, 53 percent agreed fracking does more harm than good.

“There are hundreds of millions of dollars being spent to ensure that this industry can continue to operate without the science and without the protections we need — $320 million spent on lobbying the federal government in just two years,” Goldberg said. “As a result, what we are hearing now is not how we’re going to end our addiction to fossil fuels, but instead, a hundred years of gas. Now, a hundred years of gas is based on extracting every molecule of gas from all of our reserves, even those that we haven’t actually discovered yet, when it is well known that only about 10 percent of those reserves tend to be economically feasible to develop.”

On the other side of the debate were New York Times op-ed columnist Joe Nocera and former U.S. Department of Energy assistant secretary of policy Sue Tierney.

“Think about a world where you don’t have to worry about cartels, you don’t have to worry about being dependent on our enemies for oil, a world where foreign policy is not dictated by our need for oil,” Nocera said. “The ability of the United States to have its own resource once again in a way that we never thought we were going to is a tremendous gift that’s been handed to us, and fracking is the way that we’re taking advantage of it.”

The debate, hosted by Intelligence Squared at the Aspen Ideas Festival, tapped into the controversial practice of fracking, in which millions of gallons of water, along with sand and chemicals, are pumped thousands of feet into the ground, under high pressure, to break up rock to release oil and gas. One byproduct of fracking, methane gas, is often released into the air and it can even pollute drinking water. Studies show there is an increased risk of cancer and other maladies for residents in gas-land areas.

“One, there will always be accidents, spills, mechanical failures, and human error,” said Hudson. “Two, the gas industry has consistently fought enforceable rules and there is insufficient state and federal staff to ensure compliance with what rules do exist. Three, the idea that the industry as a whole will comply with voluntary best practices — as I think our opponents have acknowledged — in the face of falling gas prices, is unlikely. Given the continued risk of harm and all of fracking’s costs weighed against its limited benefits for most, it is beyond dispute that the natural gas boom is doing more harm than good.”

Tierney and Hudson called for a balanced energy outlook, one that embraces the promise of natural gas, which is abundant in the United States and burns more cleanly than traditional coal production. Natural gas is also more affordable than many fuels and viewed as “a bridge fuel” to renewables, they said.

“What I really wish is that people would stop demonizing this fuel, because it makes it impossible to find sensible solutions in the middle,” she said. “There are sensible solutions in the middle. We should be working on enabling those to develop over time. Our main argument is that the two principal sources of energy in the United States, coal and oil, are much more damaging to the environment than is natural gas, and that’s for the communities where those are used as well as to the nation as a whole.”

The debate is being broadcast this month on National Public Radio, and it will be telecast on WNET on July 18, the same day as a celebrity-driven protest is planned in Washington, D.C., called “Stop the Frack Attack.” The event will have three demands for Congress: stop dangerous fracking, close seven legal loopholes that exempt the oil and gas industry from parts of the Safe Drinking Water, Clean Air, and Clean Water Acts, and implement a pathway toward 100 percent clean renewable energy. The event will include Mark Ruffalo, Pete Seeger, Lois Gibbs, Bill McKibben, Ed Begley Jr., Ed Asner, Josh Fox, Gus Speth, Cornel West, Vandana Shiva, Holly Near, James Hansen, Dar Williams, Michael Kieschnick, Joe Uehlein, Margot Kidder and over 100 organizations and community groups.

Big and small governments across the country are grappling with ways to best regulate fracking, including North Carolina where on Monday night a state representative mistakenly cast the wrong vote. Democrat Becky Carney accidentally pushed the green button when she meant to hit the red one. It was the deciding House vote and it ultimately meant that North Carolina will have to wait until it establishes rules for hydraulic fracturing and horizontal drilling for oil and gas exploration.

“Oh my gosh. I pushed green,” she reportedly said, blaming her gaffe on fatigue.

“I feel rotten, and I feel tired,” she added.

Denver News, Video, Aspen Ideas Festival, Environmental News, Aspen Colorado, Aspen Ideas, Aspen Ideas Fest, Colorado, Denver Colorado, Fracking, Fracking Benefits, Fracking Debate, Fracking Harmful, Intelligence Squad, Denver News

Green Alerts At Energy, Video, Marcellus Shale Study, Marcellus Shale, Duke University Drilling Study, Duke University Fracking Study, Fracking, Fracking Contamination, Fracking Pollution, Pa Fracking, Pa Gas Drilling, Pennsylvania Fracking, Pennsylvania Gas Drilling, Green News

Marcellus Shale Fracking Wastewater Harmful

Marcellus Shale Fracking Wastewater Harmful

By News Staff | May 9th 2012 04:35 PM

A new paper by Natural Resources Defense Council says hydraulic fracturing (fracking) generates massive amounts of polluted wastewater in in the Marcellus Shale that threatens the health of drinking water supplies, rivers, streams, and groundwater – and that federal and state regulations have not kept pace with the dramatic growth of fracking and must be strengthened to reduce the risks of health issues throughout the Marcellus region.

hydraulic fracturing (fracking) generates massive amounts of polluted wastewater in in the Marcellus Shale that threatens the health of drinking water

Their paper contends the wastewater contains potentially harmful pollutants, including salts, organic hydrocarbons, inorganic and organic additives and naturally occurring radioactive material. These pollutants can be dangerous if they are released into the environment or if people are exposed to them. They can be toxic to humans and aquatic life and can damage ecosystem health by depleting oxygen or causing algal blooms, or they can interact with disinfectants at drinking water plants to form cancer-causing chemicals.

Condensed from their paper:

Natural gas is found in underground layers of rock and shale gas formations are generally tighter and much less permeable than other formations, causing the gas to flow less easily.

The Marcellus is the largest shale gas area in the United States by geographic area, spanning New York, Pennsylvania, Ohio, Maryland, Virginia, and West Virginia. Shale gas sources generally require more complex and expensive technologies for production and are termed ‘unconventional’ compared to more conventional drilling for oil. Other sources of unconventional gas include coal seams and impermeable sandstone formations. As of 2008, unconventional production accounted for 46 percent of total U.S. natural gas production

Hydraulic fracturing involves the injection of liquid under pressure to fracture the rock formation and prop open the fractures, allowing natural gas to flow more freely from the formation into the well for collection.

The development of hydraulic fracturing technology, along with advances that allow the horizontal drilling of wells, has facilitated the expansion of shale gas development over the past 20 years.

Prior to these innovations, shale gas development was not viewed as economically feasible, but recently such development has exploded. The first economically producing wells in the Marcellus were drilled in 2003; in 2010, 1,386 Marcellus wells were drilled in Pennsylvania alone (up from 763 drilled in 2009).

The liquids used in the hydraulic fracturing process consist primarily of water, either fresh or recycled, along with chemicals used to modify the water’s characteristics (for example, to reduce friction or corrosion) and sand or other agents, referred to as “proppants,” that hold open the fractures in the formation.

Wastewater, flowback and production phase water, contain potentially harmful constituents and the NRDC says the current regulatory approach is in adequate and their paper outlines limitations of current state and federal policies.

In Fracking’s Wake: New Rules are Needed to Protect Our Health and Environment from  Contaminated Wastewater", Rebecca Hammer and Jeanne VanBriesen, Ph.D., PE, NRDC

In Fracking’s Wake: New Rules are Needed to Protect Our Health and Environment from Contaminated Wastewater“, Rebecca Hammer and Jeanne VanBriesen, Ph.D., PE, NRDC.

Even Landfills Don't Want Fracking Fluid Waste

Rob Wile | Jun. 18, 2012, 1:00 PM |469 |Kansas landfills near a fracking site have declined to take in the drilling fluid waste, citing a blanket ban on liquids that cannot be contained.

Flickr/eggroll

o Kansas landfills near a fracking site have declined to take in the drilling fluid waste, citing a blanket ban on liquids that cannot be contained.

Gale Rose from The Pratt Tribune in Pratt, KS writes the Pratt County landfill rejected an unnamed drilling company's proposal after a nearby landfill with more advance control precautions, like a protective liner, also said no.

"If they (nearby Reno County) have concerns about it I definitely have concerns about it,” Dean Staab, director of Environmental Services for Pratt County, told Rose.

The fluid is actually a mud, Rose reports. If it were to be delivered dry, the landfills would consider storing it, she said.

Meanwhile New Jersey last week voted to ban the transport of fracking wastewater into the state.

Assemblywoman Valerie Vainieri Huttle, a Democrat who's one of the measure's sponsors, said in a statement that allowing fracking waste to come into New Jersey is too risky for public health.

"Given the relative newness of this practice, the total damage inflicted during and after drilling is still unknown," Huttle said. "But the evidence is already mounting that fracking comes with serious environmental consequences."Read more: [/toggle]

Geochemical evidence for possible natural migration

Geochemical evidence for possible natural migration of Marcellus Formation brine to shallow aquifers in Pennsylvania

  1. Nathaniel R. Warnera,
  2. Robert B. Jacksona,b,
  3. Thomas H. Darraha,
  4. Stephen G. Osbornc,
  5. Adrian Downb,
  6. Kaiguang Zhaob,
  7. Alissa Whitea, and
  8. Avner Vengosha,1

Author Affiliations

1. aDivision of Earth and Ocean Sciences, Nicholas School of the Environment, Duke University, Durham, NC 27708;
2. bCenter on Global Change, Nicholas School of the Environment, Duke University, Durham, NC 27708; and
3. cGeological Sciences Department, California State Polytechnic University, Pomona, CA 91768
  1. Edited by Karl K. Turekian, Yale University, North Haven, CT, and approved May 10, 2012 (received for review January 5, 2012)

Abstract

The debate surrounding the safety of shale gas development in the Appalachian Basin has generated increased awareness of drinking water quality in rural communities. Concerns include the potential for migration of stray gas, metal-rich formation brines, and hydraulic fracturing and/or flowback fluids to drinking water aquifers. A critical question common to these environmental risks is the hydraulic connectivity between the shale gas formations and the overlying shallow drinking water aquifers. We present geochemical evidence from northeastern Pennsylvania showing that pathways, unrelated to recent drilling activities, exist in some locations between deep underlying formations and shallow drinking water aquifers. Integration of chemical data (Br, Cl, Na, Ba, Sr, and Li) and isotopic ratios (87Sr/86Sr, 2H/H, 18O/16O, and 228Ra/226Ra) from this and previous studies in 426 shallow groundwater samples and 83 northern Appalachian brine samples suggest that mixing relationships between shallow ground water and a deep formation brine causes groundwater salinization in some locations. The strong geochemical fingerprint in the salinized (Cl > 20 mg/L) groundwater sampled from the Alluvium, Catskill, and Lock Haven aquifers suggests possible migration of Marcellus brine through naturally occurring pathways. The occurrences of saline water do not correlate with the location of shale-gas wells and are consistent with reported data before rapid shale-gas development in the region; however, the presence of these fluids suggests conductive pathways and specific geostructural and/or hydrodynamic regimes in northeastern Pennsylvania that are at increased risk for contamination of shallow drinking water resources, particularly by fugitive gases, because of natural hydraulic connections to deeper formations.

Footnotes

  • Author contributions: N.R.W., R.B.J., and A.V. designed research; N.R.W., R.B.J., S.G.O., A.D., A.W., and A.V. performed research; N.R.W., R.B.J., T.H.D., K.Z., and A.V. analyzed data; and N.R.W., R.B.J., T.H.D., and A.V. wrote the paper.
  • The authors declare no conflict of interest.

New twist in fracking debate

upi.com/Business DURHAM, N.C., July 10 (UPI) -- A U.S. study found there may be some natural processes occurring with the contamination of water supplies in a shale play in Pennsylvania.

A study conducted by researchers at Duke University and California State Polytechnic University found natural processes were leading to some levels of contamination in drinking water wells and aquifers in northeastern Pennsylvania.

Pennsylvania hosts a portion of the Marcellus shale play, one of the largest sources of natural gas in the United States.

Shale natural gas extraction is controversial. There are concerns that some of the waste associated with the extraction methods could find their way into drinking water supplies.

Scientists found that salty water laced with certain chemicals like barium or compounds like methane were from natural pathways of contamination.

Robert Jackson, an ecologist at Duke University and one of the report's authors, said the mineral-rich fluids are seeping upwards through the shale layer.

He told National Public Radio scientists were working to figure out what was coming from shale gas extraction and what was from natural processes.

"They are a possible conduit for movement of salts or fracking chemicals or even gases up to the surface," he said. "But we just don't know how likely that is."

The study was published in the journal Proceedings of the National Academy of Sciences.

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    Save the Water™ Questions and Answers: Can fracking in the USA be cleaned up? [Kevin Bullis/Technology Review]

    Savethewater Questions and Answers


    Questions and Answers
    Vol.III
    No.19

     

    Despite many successful water projects, billions of people still lack adequate water and sanitation

    savethewater”,   “save the water”, “what is contaminated water”, “dirty water”, “water research”, “water”, “clean water”, “safe water”, “drinking water”, “water treatment”, “water testing”, “water analysis”, “bacteria”, “fluoride”, “pesticides”, “herbicides”, “organic chemicals”, “arsenic”, “ inorganic chemicals”,  “tap water”

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    Question: Can fracking be cleaned up?


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    Save the water. Can fracking be stopped

    Fracking site: Trucks at a well in Pennsylvania pump high-pressure fracking fluid down the well to free natural gas from the shale formation far below the surface.Les Stone/ Corbis

    The International Energy Agency says yes, but it will take tougher regulations that force producers to apply the latest technologies.

      Tuesday, June 5, 2012/By Kevin Bullis

    Fracking, aka hydraulic fracturing, a process for freeing natural gas locked in shale deposits, has caused a boom in natural-gas production in the United States. But some experts worry that the practice results in contaminated drinking water and the release of methane, prompting some localities to limit shale-gas production.

    A new analysis by the International Energy Agency says technologies exist—or are in development—that could largely address these concerns. If they’re adopted, fracking could be more widely accepted by governments around the world, leading to lower greenhouse-gas emissions and lower energy prices. It they’re not, governments could balk, and coal would maintain its dominant place in electricity generation.

    The most well-known issue associated with fracking is concern over water use and contamination. Fracking consumes large amounts of water; roughly 20 million liters under high pressure are sent down each well to create the fractures in the rock that free the natural gas. That water use is a huge concern in places such as Texas and some areas of China that have large shale-gas resources and are prone to droughts.

    Disposal of that wastewater is another concern. Fracking also has the potential to contaminate drinking water supplies and increase air pollution. And there are concerns that it could actually increase greenhouse-gas emissions due to methane leaks.

    But the IEA report concludes that fracking, like many other practices in industries that involve hazardous chemicals, can be made relatively safe with regulation. The IEA estimates that the measures needed to make fracking safer would add about 7 percent to the cost of an average well.

    Significant levels of methane, the main component of natural gas, have been found in drinking-water supplies near some fracking sites. Some environmentalists have suggested that the fracking process, which creates fractures in shale, could create a path for natural gas and other chemicals to reach aquifers and mix with drinking water.

    But according to the IEA report, that doesn’t seem to be the problem in most cases. Fracking usually takes place hundreds of meters below aquifers, and it’s easy to stop the propagation of fractures. Cracking the rock requires high pressures. Stop applying the pressure, and the rock fracturing stops. However, some fracking sites are relatively near to the level of drinking water, and the IEA suggests it might make sense to ban the procedure at such locations.

    The IEA says the contaminated water is most likely the result of producers building substandard natural-gas wells, which are lined with metal casings and cement to keep the natural gas from contaminating aquifers. But in some cases, producers have done a poor job of cementing, allowing channels for natural gas to form. “Whenever there was a gas leakage, it came out because the cement was not well done,” says Franz-Josef Ulm, a civil and environmental engineering professor at MIT. That problem could be solved by cementing properly and then carefully monitoring the well’s integrity. “When it comes to cementing, the solutions are out there. The question is whether they are being applied,” Ulm says.

    New technology could greatly reduce the amount of pressure needed for fracking, making it far easier to build safe wells, Ulm says. Researchers are learning that shale is particularly fracture-resistant because of the presence of a small amount of organic material that binds together inorganic particles. Targeting these materials by applying a special solvent could weaken the shale and make it far easier to free the natural gas.

    There are also opportunities to reduce water use by using fluids other than water—such as propane (which brings its own environmental challenges)—or mixing carbon dioxide or nitrogen with water to create foams. Eventually it may be possible to mix small amounts of water with solid particles designed to easily flow, Ulm says.

    Another contamination fear involves the chemicals that fracking companies add to the water. The biggest concern isn’t the chemicals once they’re mixed with the water, since they’re so dilute, but rather the handling of the chemicals in concentrated form. Spills on the surface could soak into the ground and contaminate drinking water. The solution is to line the area where chemicals are handled with plastic and monitor any leaks. Researchers are also developing less-toxic chemicals, or techniques to eliminate the need for them.

    Yet even if these chemicals can be dealt with, wastewater remains a challenge. The water that flows back to the surface is contaminated not only with the chemicals originally mixed in at the surface, but also with chemicals, heavy metals, and, in some cases, naturally occurring radioactive materials from deep underground.

    As the water returns to the surface, natural gas and other hydrocarbons that were released by the fracking come with it. In many cases, that gas is allowed to escape into the atmosphere until the water stops flowing. The main component of natural gas—methane—is a greenhouse gas many times more powerful than carbon dioxide, so this practice could offset any greenhouse-gas emissions reductions that would come from burning natural gas rather than coal. However, simple technology exists to capture the natural gas at this stage.

    Implementing these technologies will likely require regulation. “It can’t just be counting on companies to adopt best practices, because you’ll only have a certain percentage of the well operators doing it,” says Mark Boling, president of V+ Development Solutions, which is part of Southwestern Energy, a natural-gas producer. “You have to go the rest of the way and get regulations in place so that you have a level playing field and everyone is required to do the same thing.”

    If done right, those regulations could drive innovation by creating a market for new technologies. Ulm recommends caps on emissions that give companies flexibility to choose the best technology. The IEA calls for a combination of such caps, and in some cases specific technology requirements. “With such regulations, you could force innovation to be implemented at a high pace. Technology is what it will take to make shale gas a sustainable resource,” Ulm says.

    Definitions From Wikipedia

    Save the Water™ does not represent or endorse the definitions posted herein or reliability of any advice, opinion, statement, or other information furnished by the author. It is meant for further research by you the reader.

    Hydraulic fracturing

    From Wikipedia, the free encyclopedia
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    “Fracking” redirects here. For the expletive, see Frak (expletive).
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    The neutrality of this article is disputed. Please see the discussion on the talk page. Please do not remove this message until the dispute is resolved. (March 2012)
    Hydraulic fracturing
    Process type Mechanical
    Industrial sector(s) Mining
    Main technologies or sub-processes Fluid pressure
    Product(s) Natural gas
    Petroleum
    Inventor Floyd Farris; J.B. Clark (Stanolind Oil and Gas Corporation)
    Year of invention 1947

    Hydraulic fracturing is the propagation of fractures in a rock layer caused by the presence of a pressurized fluid. Some hydraulic fractures form naturally, as in the case of veins or dikes, and are a means by which gas and petroleum from source rocks may migrate to reservoir rocks. Induced hydraulic fracturing or hydrofracking, commonly known as fracking, is a technique used to release petroleum, natural gas (including shale gas, tight gas and coal seam gas), or other substances for extraction.[a][1] This type of fracturing creates fractures from a wellbore drilled into reservoir rock formations.

    The first use of hydraulic fracturing was in 1947, though the fracking technique which made the shale gas extraction economical was first used in 1997 in the Barnett Shale in Texas.[1][2][3] The energy from the injection of a highly-pressurized fracking fluid creates new channels in the rock which can increase the extraction rates and ultimate recovery of fossil fuels.

    Proponents of fracking point to the vast amounts of formerly inaccessible hydrocarbons the process can extract.[4] Detractors point to potential environmental impacts, including contamination of ground water, risks to air quality, the migration of gases and hydraulic fracturing chemicals to the surface, surface contamination from spills and flowback and the health effects of these.[5] For these reasons hydraulic fracturing has come under scrutiny internationally, with some countries suspending or even banning it.

    Geology

    Mechanics

    Fracturing in rocks at depth is suppressed by the confining pressure, due to the load caused by the overlying rock strata. This is particularly so in the case of ‘tensile’ (Mode 1) fractures, which require the walls of the fracture to move apart, working against this confining pressure. Hydraulic fracturing occurs when the effective stress is reduced sufficiently by an increase in the pressure of fluids within the rock, such that the minimum principal stress becomes tensile and exceeds the tensile strength of the material.[6][7] Fractures formed in this way will typically be oriented perpendicularly to the minimum principal stress and for this reason, induced hydraulic fractures in wellbores are sometimes used to determine stress orientations.[8] In natural examples, such as dikes or vein-filled fractures, their orientations can be used to infer past stress states.[9]

    Veins

    Most vein systems are a result of repeated hydraulic fracturing during periods of relatively high pore fluid pressure. This is particularly clear in the case of ‘crack-seal’ veins, where the vein material can be seen to have been added in a series of discrete fracturing events, with extra vein material deposited on each occasion.[10] One mechanism to explain such examples of long-lasting repeated fracturing is the effects of seismic activity, in which the stress levels rise and fall episodically and large volumes of fluid may be expelled from fluid-filled fractures during earthquakes. This process is referred to as ‘seismic pumping’.[11]

    Dikes

    High-level minor intrusions such as dikes propagate through the crust in the form of fluid-filled cracks, although in this case the fluid is magma. In sedimentary rocks with a significant water content the fluid at the propagating fracture tip will be steam.[12]

    History

    Fracturing as a method to stimulate shallow, hard rock oil wells dates back to the 1860s. It was applied by oil industries in Pennsylvania, New York, Kentucky, and West Virginia by using liquid and later also solidified nitroglycerin. Later the same method was applied to water and gas wells. The idea to use acid as a nonexplosive fluid for a well stimulation was introduced in the 1930s. Due to acid etching, created fractures would not close completely and therefore enhanced productivity. The same phenomenon was discovered with water injection and squeeze cementing operations.[13]

    The relationship between well performance and treatment pressures was studied by Floyd Farris of Stanolind Oil and Gas Corporation. This study became a basis of the first hydraulic fracturing experiment, which was conducted in 1947 at the Hugoton gas field in Grant County of southwestern Kansas by Stanolind.[13][1] For the well treatment 1,000 US gallons (3,800 l; 830 imp gal) of gelled gasoline and sand from the Arkansas River was injected into the gas producing limestone formation at 2,400 feet (730 m). The experiment was not very successful as deliverability of the well did not change appreciably. The process was further described by J.B. Clark of Stanolind in his paper published in 1948. A patent on this process was issued in 1949 and an exclusive license was granted to the Halliburton Oil Well Cementing Company. On March 17, 1949, Halliburton performed the first two commercial hydraulic fracturing treatments in Stephens County, Oklahoma, and Archer County, Texas.[13] Since then, hydraulic fracturing has been used to stimulate approximately a million oil and gas wells.[14]

    In the Soviet Union, the first hydraulic proppant fracturing was carried out in 1952. In Western Europe, in 1977–1985 hydraulic fracturing was conducted at Rotliegend and Carboniferous gas-bearing sandstones in Germany, Netherlands onshore and offshore gas fields, and the United Kingdoms sector of the North Sea. Other countries in Europe and Northern Africa included Norway, the Soviet Union, Poland, Czechoslovakia, Yugoslavia, Hungary, Austria, France, Italy, Bulgaria, Romania, Turkey, Tunisia, and Algeria. [15]

    Due to shale’s high porosity and low permeability, technology research, development and demonstration were necessary before hydraulic fracturing could be commercially applied to shale gas deposits. In the 1970s the federal government initiated both the Eastern Gas Shales Project, a set of dozens of public-private hydro-fracturing pilot demonstration projects, and the Gas Research Institute, a gas industry research consortium that received approval for research and funding from the Federal Energy Regulatory Commission.[16] In 1977, the Department of Energy pioneered massive hydraulic fracturing in tight sandstone formations. In 1997, based on earlier techniques used by Union Pacific Resources (now part of Anadarko Petroleum Corporation), Mitchell Energy (now part of Devon Energy) developed the hydraulic fracturing technique known as ‘slickwater fracturing’ that made the shale gas extraction economical.

    In 2011, France became the first nation to ban the hydraulic fracturing.[18][19]

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    Save the Water™ Questions and Answers: Can frack toxins migrate to aquifers?Study shows more immediate drilling danger. Predicts frack toxins can migrate to aquifers within years

    Savethewater Questions and Answers


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    Despite many successful water projects, billions of people still lack adequate water and sanitation

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    Predicts frack toxins can migrate to aquifers within years

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    Save the water fracking fluidsStudy shows more immediate drilling danger

    Published May 3, 2012 at 6:01 am (Updated May 3, 2012)

    NEW YORK — A new study has raised fresh concerns about the safety of gas drilling in the Marcellus Shale, concluding that fracking chemicals injected into the ground could migrate toward drinking water supplies far more quickly than experts have previously predicted, the investigative news site, ProPublica.com reports.

    More than 5,000 wells were drilled in the Marcellus between mid-2009 and mid-2010, according to the study, which was published in the journal Ground Water two weeks ago. Operators inject up to 4 million gallons of fluid, under more than 10,000 pounds of pressure, to drill and frack each well.

    Scientists have theorized that impermeable layers of rock would keep the fluid, which contains benzene and other dangerous chemicals, safely locked nearly a mile below water supplies. This view of the earth’s underground geology is a cornerstone of the industry’s argument that fracking poses minimal threats to the environment.

    But the study, using computer modeling, concluded that natural faults and fractures in the Marcellus, exacerbated by the effects of fracking itself, could allow chemicals to reach the surface in as little as “just a few years.”

    “Simply put, are not impermeable,” said the study’s author, Tom Myers, an independent hydrogeologist whose clients include the federal government and environmental groups.

    “The Marcellus shale is being fracked into a very high permeability,” he said. “Fluids could move from most any injection process.”

    The research for the study was paid for by Catskill Mountainkeeper and the Park Foundation, two upstate New York organizations that have opposed gas drilling and fracking in the Marcellus.

    Much of the debate about the environmental risks of gas drilling has centered on the risk that spills could pollute surface water or that structural failures would cause wells to leak.

    Though some scientists believed it was possible for fracking to contaminate underground water supplies, those risks have been considered secondary. The study in Ground Water is the first peer-reviewed research evaluating this possibility.

    The study did not use sampling or case histories to assess contamination risks. Rather, it used software and computer modeling to predict how fracking fluids would move over time. The simulations sought to account for the natural fractures and faults in the underground rock formations and the effects of fracking.

    The models predict that fracking will dramatically speed up the movement of chemicals injected into the ground. Fluids traveled distances within 100 years that would take tens of thousands of years under natural conditions. And when the models factored in the Marcellus’ natural faults and fractures, fluids could move 10 times as fast as that.

    Where man-made fractures intersect with natural faults, or break out of the Marcellus layer into the stone layer above it, the study found, “contaminants could reach the surface areas in tens of years, or less.”

    The study also concluded that the force that fracking exerts does not immediately let up when the process ends. It can take nearly a year to ease.

    As a result, chemicals left underground are still being pushed away from the drill site long after drilling is finished. It can take five or six years before the natural balance of pressure in the underground system is fully restored, the study found.

    Myers’ research focused exclusively on the Marcellus, but he said his findings may have broader relevance. Many regions where oil and gas is being drilled have more permeable underground environments than the one he analyzed, he said.

    “One would have to say that the possible travel times for a similar thing in Arkansas or Northeast Texas is probably faster than what I’ve come up with,” Myers said.

    Ground Water is the journal of the National Ground Water Association, a non-profit group that represents scientists, engineers and businesses in the groundwater industry.

    Several scientists called Myers’ approach unsophisticated and said that the assumptions he used for his models didn’t reflect what they knew about the geology of the Marcellus Shale. If fluids could flow as quickly as Myers asserts, said Terry Engelder, a professor of geosciences at Penn State University who has been a proponent of shale development, fracking wouldn’t be necessary to open up the gas deposits.

    “This would be a huge fracture porosity,” Engelder said. “So I read this and I say, ‘Golly, does this guy really understand anything about what these shales look like?’ The concern then arises from using a model rather than observations.”

    Myers likened the shale to a cracked window, saying that samples showing it didn’t contain fractures were small in size and were akin to only examining an intact section of glass, while a broader, scaled out view would capture the faults and fractures that could leak.

    Both scientists agreed that direct evidence of fluid migration is needed, but little sampling has been done to analyze where fracking fluids go after being injected underground.

    Myers says monitoring systems could be installed around gas well sites to measure for changes in water quality, a measure required for some gold mines, for example. Until that happens, Myers said, theoretical modeling has to substitute for hard data.

    “We were trying to use the basic concepts of groundwater and hydrology and geology and say can this happen?” he said. “And that had basically never been done.”

    — Abrahm Lustgarten
    Editors note: View stories in the ProPublica series at www.propublica.org/series/fracking.

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    History of the Tribal PWSS and UIC Programs

    In 1974 the United States Congress passed legislation, the Safe Drinking Water Act (SDWA), designed to maintain and improve the quality of the nation’s drinking waters. Two major regulatory programs were created in the SDWA: the Public Water System Supervision (PWSS) and the Underground Injection Control (UIC) programs.

    Congress authorized EPA to delegate responsibilities to states for implementing and enforcing national standards within their jurisdiction. States must apply to EPA if they want this “primacy” responsibility and must develop PWSS or UIC programs that meet national requirements. EPA is still responsible for developing national regulations, overseeing state primacy programs and implementing programs in states without primacy.

    Because of their unique status, Indian tribes were not eligible to assume primacy in the original Act. Instead EPA regions were responsible for primary enforcement authority of PWSS and UIC programs on Tribal lands. This changed in 1986 when the Amendments to the SDWA added provisions that allow federally recognized tribes to assume primacy for the PWSS and UIC programs. Section 1451 (“Indian Tribes”) of SDWA authorizes the EPA to treat Indian tribes in a manner similar to states and to assign primary enforcement responsibility (primacy) to qualified tribes.

    The PWSS and UIC programs are very complex and costly to operate. For many tribes (especially those that do not have a large number of public water systems or underground injection wells), the costs and resources required to achieve and maintain a regulatory program may far exceed the benefits from achieving primacy. Due to such difficulties, currently the only tribe that has sought and obtained primacy for the PWSS program is the Navajo Nation. There are a few tribes that are pursuing primacy in the PWSS and UIC programs.

    Today´s Tribal Direct Implementation Program

    States and tribes that do not obtain PWSS and UIC program delegation continue to be directly implemented by the EPA region in which the State or reservation is located. All EPA regions, excluding Region III (which has no federally recognized tribes), operate tribal PWSS and UIC programs to manage public water systems or underground injection wells on Indian lands.

    EPA’s 1997 inventory shows that there are nearly 1000 public water systems (740 community water systems, 90 nontransient noncommunity water systems and 130 transient noncommunity water systems) that the EPA regional offices manage on Indian lands serving a population of nearly 500,000. There are also over 5,300 injection wells (one Class I well, 4,300 Class II wells, 0 Class III wells and 1,042 Class V wells) on tribal lands that are managed by regional UIC staff.

    As the primary enforcement authority for tribal public water systems, EPA regions are responsible for enforcing against those systems that do not comply with federal drinking water regulations. A formal enforcement action is taken as a last measure. EPA regions dedicate a great deal of resources to provide tribes with technical assistance to help their systems or wells comply with federal standards. Regional staff visit reservations as often as possible to provide compliance assistance on site. Many Regions also fund circuit rider programs which enable other qualified persons the opportunity to provide technical assistance and training directly to tribes.

    For more information on the Tribal PWSS and UIC programs, please contact your program representative.

    Source water assessment and protection programs

    Source Water Assessment and Protection Programs

    The Safe Drinking Water Act (SDWA) Amendments of 1996 required states to develop and implement source water assessment programs (SWAPs) to analyze existing and potential threats to the quality of the public drinking water throughout the state. Using these programs, most states have completed source water assessments for every public water system — from major metropolitan areas to the smallest towns. Even schools, restaurants, and other public facilities that have wells or surface water supplies have been assessed. A source water assessment is a study and report, unique to a water system, that provides basic information about the water used to provide drinking water. States are working with local communities and public water systems to identify protection measures to address potential threats to sources of drinking water.

    EPA publications and resources

    Wellhead protection program

    Wellhead Protection Program

    The Wellhead Protection Program (WHPP) is a pollution prevention and management program used to protect underground sources of drinking water. The national WHPP was established under section 1428 of the 1986 SDWA amendments. The law specified that certain program activities, such as delineation, contaminant source inventory, contingency planning and source management, be incorporated into state WHPPs, which are approved by EPA prior to implementation. All states have EPA-approved state WHPPs. Although section 1428 applies only to states, a number of tribes are implementing the program as well.

    WHPPs provided the foundation for many of the state source water assessment programs required under the 1996 SDWA amendments. Most states also use the wellhead protection program as a foundation for assessing and protecting ground water systems. State WHPPs vary greatly. For example, some states require community water systems to develop management plans, while others rely on education and technical assistance to encourage voluntary action. Other states have mandatory requirements for wellhead protection at the local level. Guidance, publications and other resources are available on state source water web sites.

    EPA publications and resources

    Non-EPA publications and resources

    State ground water protection program

    State Ground Water Protection Programs

    Many states have also developed programs that are focused specifically on ground water protection. Several states developed formal Comprehensive State Ground Water Protection Programs (CSGWPP), which were designed as a management tool for states to use to integrate all programs that affect ground water quality, thus allowing better decisions to be made. Although most states are no longer pursuing formal approval of a CSGW pp, virtually all states are pursuing at least some of the individual elements necessary for comprehensive ground water protection. Within EPA, the source water protection program is working with the underground storage tank program to address potential threats to ground water posed by leaking tanks.

    Publications and resources

    Sole source aquifer protection program

    Sole Source Aquifer Protection Program

    A sole source aquifer supplies 50 percent or more of the drinking water for a given aquifer service area for which there are no reasonably available alternative sources, should the aquifer become contaminated. Designation as a sole source aquifer protects an area’s ground water resources by requiring EPA to review any proposed projects within the designated area that are receiving federal financial assistance.

    Watershed-based protection program

    Watershed-Based Protection Program

    The goal of source water protection is to protect the drinking water resource by protecting and preserving the environmental quality of the watershed above the intake (or the aquifer around the well). The assessment is the first step in the process to protect the resource. Once a watershed has been assessed to determine its current condition and the extent of the threats to the system, a watershed plan can be developed and implemented.

    EPA’s Office of Water has numerous programs that focus on watershed protection under the Clean Water Act (CWA). The Act includes programs such as the Nonpoint Source Program, National Estuary Program, the Total Maximum Daily Load (TMDL) Program, and the National Pollution Discharge Elimination System (NPDES) program. Each of these programs encourage states to develop programs to promote watershed-based protection, and they have elements that support watershed-based planning and implementation. The federal programs are generally implemented at the state level.

    EPA,Federal /non-governmental programs

    EPA, Federal / Non-governmental Programs

    There is no single federal program for implementing source water protection plans and activities. However, many federal, tribal, regional, and local programs have tools and resources that can be used to focus on protecting drinking water. Source water protection can benefit, and benefit from, other EPA programs, other federal programs and non-governmental programs:

    • Other programs can use source water assessments and identified protection areas to set priorities for ongoing prevention efforts.
    • Identifying source water protection areas increases federal, state and local managers’ awareness of other programs where participation might increase the protection of human health.
    • Protecting sources of drinking water can help various federal programs, states, organizations and communities meet other environmental and social goals, such as green space conservation, stormwater planning, management of nonpoint source pollution and brownfields redevelopment.
    • The benefits that EPA and other federal programs can provide to state and local source water assessment and protection efforts are potentially very large. These include information, technical and financial resources, and communication networks and enforcement authorities.

    EPA program links

    Other Federal Programs and Non-Governmental Organizations

    Tribal programs

    Tribal Programs

    EPA is firmly committed to helping tribes to assess the rivers, lakes, springs and aquifers that serve as tribal public water supplies and to implement measures to protect against contamination of these water resources.

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    Fracking water contamination : Natural gas fracking fizzles in Michigan – EPA Fracking Directory – [Detroit News - Jim Lynch]

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    Fracking water contamination:  Natural gas fracking fizzles in Michigan - EPA Fracking Directory - [Detroit News - Jim Lynch]

    Natural gas fracking fizzles in Michigan

    Pollution concerns, falling prices slow drilling

    May 25, 2012 at 12:37 pm / By Jim Lynch / The Detroit News
    Fracking, the practice of pumping chemical-laced water underground to fracture the rock, has been practiced in Michigan for decades. (Photo by Heather Rousseau)

    Just two years ago Michigan was well on its way to becoming Pennsylvania West — following in that state’s footsteps as the next hotbed of natural gas exploration and production.

    Since that time, the plummeting price of natural gas and concerns over the technology used to extract it — hydraulic fracturing — have brought the expected boom to a standstill.

    “There is so much gas that we already (know) can be produced cheaply that exploring new areas and trying to commercialize them has ground to a halt everywhere,” industry analyst Amber McCullagh said.

    Despite that lull in production, the debate over natural gas has never been more intense — a high-stakes battle that could dictate the future terms of gas production when prices rebound.

    That fight is playing out in Michigan’s Legislature as well as the courts. Lawmakers have a spate of bills to consider that put restrictions on hydraulic fracturing, or “fracking.” One citizens’ group based in Charlevoix is trying to give voters the option of banning the practice outright. A new lawsuit filed in Ingham County seeks to force Michigan’s Department of Environmental Quality to apply regulations on the books for injection wells to hydraulic fracturing.

    And the debate over how best to deal with fracking has caused a divide in the environmental community as well. Efforts to enact a ban on the process are considered unrealistic by some, while anything short of a ban is considered a sellout by others.

    Fracking has been practiced in Michigan for decades. By pumping chemical-laced water underground to fracture the rock, energy companies can pump out the natural gas no longer trapped. More recent twists on the technology — such as drilling horizontally after reaching the shale depth and using millions of gallons of water — have increased productivity and opened up new areas in Michigan to development.

    “Michigan has a strong stake in continued responsible development and greater use of this homegrown energy source,” said Robert Sumner, director of communications for America’s Natural Gas Alliance, in a written response to questions. “For both power generation and transportation, natural gas is a far cleaner alternative than the dominant forms of energy we use today.That means cleaner air in Michigan communities.”

    Environmental issues in Pennsylvania

    But the expanded use of horizontal fracking also has heightened the level of concern over natural gas production. Environmental issues in Pennsylvania and earthquake concerns from as close by as Ohio have painted a target on the extraction process.

    And the battle has already claimed one — sort of. Steven Losher, a 47-year-old Barry County resident, traveled to Lansing on May 8 to watch as the Michigan Department of Natural Resources auctioned off oil and mineral rights to state lands — some of which were near his home.

    Losher, who was there because of concerns over fracking in his southwest county, wound up being arrested when he was thought to be part of the Occupy movement that was demonstrating outside.

    “When you look at what’s happened in other states … it seems after even cursory research that everywhere horizontal fracking has been occurring, there have been problems,” said Losher, who will be arraigned June 5. “And some of those problems have been hellish.”

    A single test well, brought online by Calgary, Alberta-based Encana Corp. in early 2010, was the first domino here, putting the fracking debate in the spotlight. The initial production from that well in Missaukee County — in the natural gas deposit called the Collingwood Shale — brought energy companies to the state, scrambling to secure oil and mineral rights on as much land as possible. The county is east of Cadillac.

    But a second test well produced less robust results and the dropping market price for natural gas brought exploratory efforts to a standstill.

    “Essentially, producers were victims of their own success,” said McCullagh, a senior analyst of North American gas research at Houston-based Wood Mackenzie.

    “Costs for producing natural gas declined significantly and overall production increased rapidly. … As a result, the price for natural gas declined from $12 to $13 per million British thermal unit in 2005 to an average of $4 in 2011.”

    Last month, U.S. natural gas prices traded at less than $2 per million British thermal units for the first time since 2002.

    The Collingwood Shale roughly spans the northern portion of the Lower Peninsula and reaches in to the easternmost portions of the Upper Peninsula. The gas deposits sit as deep as 10,000 feet below the surface.

    Encana’s first well was the initial hydraulic fracturing project to be used in the shale. So far, three wells in Michigan have utilized the horizontal drilling technique.

    Seventeen years ago, Joanne Cromley and her husband relocated from the Chicago area to Michigan with a specific goal in mind. They purchased 240 acres of land near Afton, in Cheboygan County, with the intention of letting it “go wild.”

    In August 2010, a letter arrived alerting the couple that the state had included their property’s oil and mineral rights in an auction. While the couple owned the land, the state had the right to offer up its drilling rights, creating the possibility a company could come in and mine on their land in pursuit of natural gas.

    Today, Cromley serves as the co-chairman of Don’t Frack Michigan — a citizens’ group attempting to ban fracking in the state. The task at-hand, he said, is education and pushing for a no-compromise solution. “I think that a lot of people have been put to sleep in the sense that there are some environmental organizations that say we can do this through regulation,” she said. “I don’t think we can.”

    For groups like Don’t Frack Michigan, or the similarly titled Ban Michigan Fracking, the bills currently in the Legislature are eyed with suspicion, if not derision.

    LuAnne Kozma is among the Ban Michigan Fracking members collecting petition signatures to place the fracking question before voters. They have until July 9 to collect 322,000 of them in order to have a ban option on the November ballot.

    Her grassroots group puts quotes around the word “reform” when discussing the package of proposed laws targeting natural gas extraction. They leave the door to energy companies open for fracking in the future and that, she said, is a risk she isn’t willing to take.

    Other groups, including the Michigan Environmental Council, see a future that includes fracking in a tightly regulated environment.

    “We all use natural gas,” he said. “This is a product that is part of our everyday lives. To the extent that if falls into that category, we should figure out the best way to deal with it.”

    jlynch@detnews.com

    (313) 222-2034

    From The Detroit News:

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    Water contamination news: Fracking – Using diesel fuel in oil and gas hydraulic fracturing.

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    Water contamination news – Fracking

    Using diesel fuel in oil and gas hydraulic fracturing.

    Kansas City infoZine / Saturday, May 05, 2012 ::

    EPA Releases Draft clarifying means of compliance to 2005 Amendments of Safe Drinking Water Act

    Washington, D.C. – infoZine – The U.S. Environmental Protection Agency (EPA) has released draft underground injection control (UIC) program permitting guidance for class II wells that use diesel fuels during hydraulic fracturing activities. EPA developed the draft guidance to clarify how companies can comply with a law passed by Congress in 2005, which exempted hydraulic fracturing operations from the requirement to obtain a UIC permit, except in cases where diesel fuel is used as a fracturing fluid.

    The draft guidance outlines for EPA permit writers, where EPA is the permitting authority, requirements for diesel fuels used for hydraulic fracturing wells, technical recommendations for permitting those wells, and a description of diesel fuels for EPA underground injection control permitting. The draft guidance describes diesel fuels for these purposes by reference to six chemical abstract services registry numbers. The agency is requesting input on this description.

    While this guidance undergoes public notice and comment, decisions about permitting hydraulic fracturing operations that use diesel fuels will be made on a case-by-case basis, considering the facts and circumstances of the specific injection activity and applicable statutes, regulations and case law, and will not cite this draft guidance as a basis for decision.

    EPA will take public comment on the draft guidance for 60 days upon publication in the Federal Register to allow for stakeholder input before it is finalized.

    More information: The EPA Offers the following information

    Hydraulic Fracturing Under the Safe Drinking Water Act


    Natural gas plays a key role in our nation’s clean energy future and the process known as hydraulic fracturing is one way of accessing that vital resource. Hydraulic fracturing is used by gas producers to stimulate wells and recover natural gas from sources such as coalbeds and shale gas formations. Hydraulic fracturing is also used for other applications including oil recovery. Over the past few years, several key technical, economic, and energy policy developments have spurred increased use of hydraulic fracturing for gas extraction over a wider diversity of geographic regions and geologic formations. Along with the expansion of hydraulic fracturing, there have been increasing concerns about its potential impacts on drinking water resources, public health, and environmental impacts in the vicinity of these facilities.

    Draft Guidance: Permitting Guidance for Oil and Gas Hydraulic Fracturing Activities Using Diesel Fuels

    EPA has developed draft Underground Injection Control (UIC) Class II permitting guidance for oil and gas hydraulic fracturing activities using diesel fuels. This document describes information useful in permitting the underground injection of oil- and gas-related hydraulic fracturing using diesel fuels where EPA is the permitting authority. EPA’s goal is to improve compliance with the Safe Drinking Water Act (SDWA) requirements and strengthen environmental protections consistent with existing law.

      For help with accessibility, please contact Sherri Comerford

    comerford.sherri@epa.gov

      , (202) 564-4369
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    • The draft guidance is open for comment for 60 days after publication in the Federal Register. To comment, use one of the following methods, and specify Docket ID No. EPA-HQ-OW-2011-1013:
    • Online: Go to www.regulations.gov, and follow the on-line instructions for submitting comments.
    • Email: OW-Docket@epa.gov@epa.gov.
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    Water contamination news: Fracking chemicals – chemicals used in fracking – Part I.

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    Water contamination news

    Chemicals Used In Fracking. Part I

    Save the Water™ does not represent or endorse the postings herein or reliability of any advice, opinion, statement, or other information furnished by the author.


    Source: FracFocus, the national hydraulic fracturing chemical registry.

    Chemicals serve many functions in hydraulic fracturing. From limiting the growth of bacteria to preventing corrosion of the well casing, chemicals are needed to insure that the fracturing job is effective and efficient.

    The number of chemical additives used in a typical fracture treatment depends on the conditions of the specific well being fractured. A typical fracture treatment will use very low concentrations of between 3 and 12 additive chemicals, depending on the characteristics of the water and the shale formation being fractured. Each component serves a specific, engineered purpose. For example, the predominant fluids currently being used for fracture treatments in the gas shale plays are water‐based fracturing fluids mixed with friction‐reducing additives (called slickwater). The addition of friction reducers allows fracturing fluids and sand, or other solid materials called proppants, to be pumped to the target zone at a higher rate and reduced pressure than if water alone were used. In addition to friction reducers, other additives include: biocides to prevent microorganism growth and to reduce biofouling of the fractures; oxygen scavengers and other stabilizers to prevent corrosion of metal pipes; and acids that are used to remove drilling mud damage within the near‐wellbore area.

    Fluids are used to create the fractures in the formation and to carry a propping agent (typically silica sand) which is deposited in the induced fractures to keep them from closing up. The chart below taken from Modern Shale Gas Development in the United States: A Primer demonstrates the volumetric percentages of additives that were used for a nine‐stage hydraulic fracturing treatment of a Fayetteville Shale horizontal well.

    fracking graph

    The make‐up of fracturing fluid varies from one geologic basin or formation to another.

    Evaluating the relative volumes of the components of a fracturing fluid reveals the relatively small volume of additives that are present. The additives depicted on the right side of the pie chart represent less than 0.5% of the total fluid volume. Overall the concentration of additives in most slickwater fracturing fluids is a relatively consistent 0.5% to 2% with water making up 98% to 99.5%.

    Because the make‐up of each fracturing fluid varies to meet the specific needs of each area, there is no one‐size‐fits‐all formula for the volumes for each additive. In classifying fracturing fluids and their additives it is important to realize that service companies that provide these additives have developed a number of compounds with similar functional properties to be used for the same purpose in different well environments. The difference between additive formulations may be as small as a change in concentration of a specific compound.

    Although the hydraulic fracturing industry may have a number of compounds that can be used in a hydraulic fracturing fluid, any single fracturing job would only use a few of the available additives. For example, the chart shown above, represents 12 additives used, covering the range of possible functions that could be built into a fracturing fluid.

    To learn more:
    FracFocus: Chemical Disclosure Registry

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    Water contamination news: Fracking – Study has raised concerns about the safety of gas drilling in the Marcellus Shale.

    Water contamination news: fracking - Study has raised concerns about the safety of gas drilling in the Marcellus Shale

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    Water contamination news: fracking - Study has raised concerns about the safety of gas drilling in the Marcellus Shale

     

    Despite many successful water projects, billions of people still lack adequate water and sanitation

     
    Save the Water™ does not represent or endorse the postings herein or reliability of any advice, opinion, statement, or other information furnished by the author.

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    Water contamination news

    New study predicts fracking fluids will seep into aquifers within years.

    This story was originally published by ProPublica.

    As part of its continuing advocacy to protect NYC’s water supply from contamination, the WCC submitted comments to  Hon. Joe Martens, Commissioner of the New York State Department of Environmental Conservation on the issue of hydrofracking in New York State

    A new study has raised fresh concerns about the safety of gas drilling in the Marcellus Shale, concluding that fracking chemicals injected into the ground could migrate toward drinking water supplies far more quickly than experts have previously predicted.

    More than 5,000 wells were drilled in the Marcellus between mid-2009 and mid-2010, according to the study, which was published in the journal Ground Water two weeks ago. Operators inject up to 4 million gallons of fluid, under more than 10,000 pounds of pressure, to drill and frack each well.

    Scientists have theorized that impermeable layers of rock would keep the fluid, which contains benzene and other dangerous chemicals, safely locked nearly a mile below water supplies. This view of the earth’s underground geology is a cornerstone of the industry’s argument that fracking poses minimal threats to the environment.

    But the study, using computer modeling, concluded that natural faults and fractures in the Marcellus, exacerbated by the effects of fracking itself, could allow chemicals to reach the surface in as little as “just a few years.”

    “Simply put, [the rock layers] are not impermeable,” said the study’s author, Tom Myers, an independent hydrogeologist whose clients include the federal government and environmental groups.

    “The Marcellus shale is being fracked into a very high permeability,” he said. “Fluids could move from most any injection process.”

    The research for the study was paid for by Catskill Mountainkeeper and the Park Foundation, two upstate New York organizations that have opposed gas drilling and fracking in the Marcellus.

    Much of the debate about the environmental risks of gas drilling has centered on the risk that spills could pollute surface water or that structural failures would cause wells to leak.

    Though some scientists believed it was possible for fracking to contaminate underground water supplies, those risks have been considered secondary. The study in Ground Water is the first peer-reviewed research evaluating this possibility.

    The study did not use sampling or case histories to assess contamination risks. Rather, it used software and computer modeling to predict how fracking fluids would move over time. The simulations sought to account for the natural fractures and faults in the underground rock formations and the effects of fracking.

    The models predict that fracking will dramatically speed up the movement of chemicals injected into the ground. Fluids traveled distances within 100 years that would take tens of thousands of years under natural conditions. And when the models factored in the Marcellus’ natural faults and fractures, fluids could move 10 times as fast as that.

    Where man-made fractures intersect with natural faults, or break out of the Marcellus layer into the stone layer above it, the study found, “contaminants could reach the surface areas in tens of years, or less.”

    The study also concluded that the force that fracking exerts does not immediately let up when the process ends. It can take nearly a year to ease.

    As a result, chemicals left underground are still being pushed away from the drill site long after drilling is finished. It can take five or six years before the natural balance of pressure in the underground system is fully restored, the study found.

    Myers’ research focused exclusively on the Marcellus, but he said his findings may have broader relevance. Many regions where oil and gas is being drilled have more permeable underground environments than the one he analyzed, he said.

    “One would have to say that the possible travel times for a similar thing in Arkansas or Northeast Texas is probably faster than what I’ve come up with,” Myers said.

    Ground Water is the journal of the National Ground Water Association, a non-profit group that represents scientists, engineers and businesses in the groundwater industry.

    Several scientists called Myers’ approach unsophisticated and said that the assumptions he used for his models didn’t reflect what they knew about the geology of the Marcellus Shale. If fluids could flow as quickly as Myers asserts, said Terry Engelder, a professor of geosciences at Penn State University who has been a proponent of shale development, fracking wouldn’t be necessary to open up the gas deposits.

    “This would be a huge fracture porosity,” Engelder said. “So I read this and I say, ‘Golly, does this guy really understand anything about what these shales look like?’ The concern then arises from using a model rather than observations.”

    Myers likened the shale to a cracked window, saying that samples showing it didn’t contain fractures were small in size and were akin to only examining an intact section of glass, while a broader, scaled out view would capture the faults and fractures that could leak.

    Both scientists agreed that direct evidence of fluid migration is needed, but little sampling has been done to analyze where fracking fluids go after being injected underground.

    Myers says monitoring systems could be installed around gas well sites to measure for changes in water quality, a measure required for some gold mines, for example. Until that happens, Myers said, theoretical modeling has to substitute for hard data.

    “We were trying to use the basic concepts of groundwater and hydrology and geology and say can this happen?” he said. “And that had basically never been done.”

    This story was originally published by ProPublica.http://www.propublica.org/article/new-study-predicts-frack-fluids-can-migrate-to-aquifers-within-years/single#republish#ixzz1uDGSWKIA” target=”_blank”>Read more:

    Proppants and fracking fluids

    Last updated June 5th 2012 From Wikipedia, the free encyclopedia

    A proppant is a material that will keep a induced hydraulic fracture open, during or following a fracturing treatment, while the fracking fluid itself varies in composition depending on the type of fracturing used, and can be gel, foam or slickwater-based.

    Proppants and fracking fluids: click

    Proppants and fracking fluids

    Last updated June 5th 2012 From Wikipedia, the free encyclopedia

    A proppant is a material that will keep a induced hydraulic fracture open, during or following a fracturing treatment, while the fracking fluid itself varies in composition depending on the type of fracturing used, and can be gel, foam or slickwater-based. In addition, there may be unconventional fracking fluids. Fluids make tradeoffs in such material properties as viscosity, where more viscous fluids can carry more concentrated proppant; the energy or pressure demands to maintain a certain flux pump rate (flow velocity) that will conduct the proppant appropriately; pH, various rheological factors, among others. In addition, fluids may be used in low-volume well stimulation of high-permeability sandstone wells (20k to 80k gallons per well) to the high-volume operations such as shale gas and tight gas that use millions of gallons of water per well.

    Conventional wisdom has often vascillated about the relative superiority of gel, foam and slickwater fluids with respect to each other, which is in turn related to proppant choice. For example, Zuber, Kuskraa and Sawyer (1988) found that gel-based fluids seemed to achieve the best results for coalbed methane operations, [1], but as of 2012, slickwater treatments are more popular.

    Ignoring proppant, slickwater fracturing fluids are mostly water, generally 99% or more by volume, but gel-based fluids can see polymers and surfactants comprising as much as 7 vol% of a gel-based fluid, ignoring other additives. [2] Other common additives include hydrochloric acid (low pH can etch certain rocks, dissolving limestone for instance), friction reducers, biocides, and emulsifiers.

    Radioactive tracer isotopes are sometimes included in the hydrofracturing fluid to determine the injection profile and location of fractures created by hydraulic fracturing.[3] Patents describe in detail how several tracers are typically used in the same well. Wells are hydraulically fractured in different stages.[4] Tracers with different half-lives are used for each stage.[4][5] Their half-lives range from 40.2 hours (Lanthanum-140) to 5.27 years (Cobalt-60).[6] Amounts per injection of radionuclide are listed in the The US Nuclear Regulatory Commission (NRC) guidelines.[7]The NRC guidelines also list a wide range or radioactive materials in solid, liquid and gaseous forms that are used as field flood or enhanced oil and gas recovery study applications tracers used in single and multiple wells.[7]

    Except for diesel-based additive fracturing fluids, noted by the American Environmental Protection Agency to have a higher proportion of volatile organic compounds and carcinogenic BTEX, use of fracturing fluids in hydraulic fracturing operations was explicitly excluded from regulation under the American Clean Water Act in 2005, a legislative move that has since attracted controversy for being the product of special interests lobbying.

    Proppant permeability and mesh size

    Proppants used should be permeable or permittive to gas under high pressures; the interstitial space between particles should be sufficiently large, yet have the mechanical strength to withstand closure stresses to hold fractures open after the fracturing pressure is withdrawn. Large mesh proppants have greater permeability than small mesh proppants at low closure stresses, but will mechanically fail (i.e. get crushed) and produce very fine particulates (“fines”) at high closure stresses such that smaller-mesh proppants overtake large-mesh proppants in permeability after a certain threshold stress.[8]

    Though sand is a common proppant, untreated sand is prone to significant fines generation; fines generation is often measured in wt% of initial feed. A commercial newsletter from Hexion cites untreated sand fines production to be 23.9% compared with 8.2% for lightweight ceramic and 0.5% for their product. [9] One way to maintain an ideal mesh size (i.e. permeability) while having sufficient strength is to choose proppants of sufficient strength; sand might be coated with resin, or a different proppant material might be chosen altogether– popular alternatives include ceramic, glass, and sintered bauxite.

    Proppant weight and strength

    Increased strength often comes at a cost of increased density, which in turn demands higher flow rates, viscosities or pressures during fracturing, which translates to increased fracturing costs, both environmentally and economically. [10] Lightweight proppants conversely are designed to be lighter than sand (~2.5 g/cc) and thus allow pumping at lower pressures or fluid velocities. Light proppants are less likely to settle. Porous materials can break the strength-density trend, or even afford greater gas permeability. Proppant geometry is also important; certain shapes or forms amplify stress on proppant particles making them especially vulnerable to crushing (a sharp discontinuity can classically allow infinite stresses in linear elastic materials). [11]

    Proppant deposition and post-treatment behaviours

    Proppant mesh size also impacts fracture length: proppants can be “bridged out” if the fracture width decreases to less than twice the size of the diameter of the proppant. [21] As proppants are deposited in a fracture, proppants can resist further fluid flow or the flow of other proppants, inhibiting further growth of the fracture. In addition, closure stresses (once external fluid pressure is released) may cause proppants to reorganise or “squeeze out” proppants, even if no fines are generated, resulting in smaller effective width of the fracture and decreased permeability. Some companies try to cause weak bonding at rest between proppant particles in order to prevent such reorganisation. [9] The modelling of fluid dynamics and rheology of fracturing fluid and its carried proppants is a subject of active research by the industry.

    Proppant costs

    Though good proppant choice positively impacts output rate and overall ultimate recovery of a well; commercial proppants are also constrained by cost. Transport costs from supplier to site form a significant component of the cost of proppants.

    References

    1. ^ Mader, Detlef (1989). Hydraulic proppant fracturing and gravel packing. Amsterdam: Elsevier. ISBN 0-444-87352-X. http://books.google.com/books?id=FyGcOI42oBMC&pg=PA473&lpg=PA473.
    2. ^ Hodge, Richard. “Crosslinked and Linear Gel Comparison”. EPA HF Study Technical Workshop. Environmental Protection Agency. http://www.epa.gov/hfstudy/cross-linkandlineargelcomposition.pdf. Retrieved 8 February 2012.
    3. ^ Reis, John C. (1976). Environmental Control in Petroleum Engineering. Gulf Professional Publishers.
    4. ^ a b [1] Scott III, George L. (03-June-1997) US Patent No. 5635712: Method for monitoring the hydraulic fracturing of a subterranean formation. US Patent Publications.
    5. ^ [2] Scott III, George L. (15-Aug-1995) US Patent No. US5441110: System and method for monitoring fracture growth during hydraulic fracture treatment. US Patent Publications.
    6. ^ [3] Gadeken, Larry L., Halliburton Company (08-Nov-1989). Radioactive well logging method.
    7. ^ a b Jack E. Whitten, Steven R. Courtemanche, Andrea R. Jones, Richard E. Penrod, and David B. Fogl (Division of Industrial and Medical Nuclear Safety, Office of Nuclear Material Safety and Safeguards (June 2000). “Consolidated Guidance About Materials Licenses: Program-Specific Guidance About Well Logging, Tracer, and Field Flood Study Licenses (NUREG-1556, Volume 14)”. US Nuclear Regulatory Commission. http://www.nrc.gov/reading-rm/doc-collections/nuregs/staff/sr1556/v14/#_1_26. Retrieved 19 April 2012. “labeled Frac Sand…Sc-46, Br-82, Ag-110m, Sb-124, Ir-192″
    8. ^ “Physical Properties of Proppants”. CarboCeramics Topical Reference. CarboCeramics. http://archive.carboceramics.com/English/tools/topical_ref/tr_physical.html. Retrieved 24 January 2012.
    9. ^ a b “Critical Proppant Selection Factors”. Fracline. Hexion. http://www.momentivefracline.com/critical-proppant-selection-factors.
    10. ^ Rickards, Allan; et al (May 2006). “High Strength, Ultralightweight Proppant Lends New Dimensions to Hydraulic Fracturing Applications”. SPE Production & Operations 21 (2): 212–221. http://www.spe.org/ejournals/jsp/journalapp.jsp?pageType=Preview&jid=EPF&mid=SPE-84308-PA.
    11. ^ Guimaraes, M. S.; et al. (2007). “Aggregate production: Fines generation during rock crushing”. Journal of Mineral Processing. http://pmrl.ce.gatech.edu/papers/Guimaraes_2007a.pdf.

     

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    Water contamination news: – Archives EPA study says hydraulic fracturing likely contaminated drinking water In Wyoming town.

     Environmental Protection Agency announced Thursday that it suspects hydraulic fracturing in a shallow natural gas well in Wyoming contaminated a town’s drinking water, Drinking water contamination news. Save the water  Volume 3

     Environmental Protection Agency announced Thursday that it suspects hydraulic fracturing in a shallow natural gas well in Wyoming contaminated a town’s drinking water,Save the water,current post

    Update
    Vol.III
    Archives
    Originally Posted
    NewsOK.com
    CHRIS CASTEEL
    December 9, 2011
    July 14
    2012

     Environmental Protection Agency announced Thursday that it suspects hydraulic fracturing in a shallow natural gas well in Wyoming contaminated a town’s drinking water


    The material posted is
    courtesy of
    NewsOK.com
    CHRIS CASTEEL
    Save the Water™
    Water Research
    Education Dept.
    and is shared as
    educational material only

     

     Environmental Protection Agency announced Thursday that it suspects hydraulic fracturing in a shallow natural gas well in Wyoming contaminated a town’s drinking water,Drinking water contamination news



    ,Contaminated drinking Water

     


     
     
     

    Rating for savethewater.org

    EPA study says hydraulic fracturing likely contaminated drinking water in Wyoming town

    WASHINGTON — The Environmental Protection Agency announced Thursday that it suspects hydraulic fracturing in a shallow natural gas well in Wyoming contaminated a town’s drinking water. After three years of study, the agency concluded that chemicals found in the aquifer and in individual wells were consistent with those used in hydraulic fracturing.

    The agency issued a report that will be open for public comment and scientific review. If it is finalized with the same conclusions, it could provide the first documented case in which “fracking” contaminated groundwater.

    “Alternative explanations were carefully considered to explain individual sets of data,” the draft report says. “However, when considered together with other lines of evidence, the data indicates likely impact to ground water that can be explained by hydraulic fracturing.”

    Inhofe comments

    Sen. Jim Inhofe, R-Tulsa, said the agency’s findings were premature and political, while an environmental group called the study “a huge blow to the oil and gas industry.”

    Hydraulic fracturing, which has been used for more than 50 years on oil and gas wells, involves pumping water, sand and a small amount of chemicals into a well to create cracks in shale formations.

    The process, in tandem with horizontal drilling, has been used increasingly by the industry to produce oil and gas that was previously considered too difficult to recover. It has come under increasing scrutiny and criticism as its use has expanded, and some have charged that it poses a threat to groundwater.

    Though there have been incidents in which “flowback” water used in a well was improperly handled, the industry has countered criticisms of hydraulic fracturing by saying there had not been a documented case in which the process itself caused contamination.

    The EPA study in Pavillion, Wyo., began in 2008 after residents complained that their water smelled and tasted bad. The residents lived near a gas field controlled by Encana, a Canadian energy company.

    According to the EPA, the agency constructed two monitoring wells to sample water in the aquifer.

    “EPA’s analysis of samples taken from the agency’s deep monitoring wells in the aquifer indicates detection of synthetic chemicals, like glycols and alcohols consistent with gas production and hydraulic fracturing fluids, benzene concentrations well above Safe Drinking Water Act standards and high methane levels,” the agency said in a statement.

    Contaminants migrate

    “Given the area’s complex geology and the proximity of drinking water wells to ground water contamination, EPA is concerned about the movement of contaminants within the aquifer and the safety of drinking water wells over time.”

    Water in private wells tested by the EPA contained compounds “consistent with migration from areas of gas production,” the agency said.

    The Environmental Protection Agency noted, however, that the fracturing in Pavillion is taking place “in and below the drinking water aquifer and in close proximity to drinking water wells — production conditions different from those in many other areas of the country.”

    Industry experts have often said that most fracturing occurs a mile or more below the surface, while groundwater is close to the surface, and that there is no way that fracking water or gas could migrate to drinking water from those depths.

    Inhofe has been of the most vocal defenders in Congress of hydraulic fracturing and has been following the EPA’s work in Pavillion and its national study of fracking. Thursday he said the EPA draft report was part of President Barack Obama’s “war on fossil fuels.”

    “EPA’s conclusions are not based on sound science but rather on political science,” Inhofe said.

    “Its findings are premature, given that the agency has not gone through the necessary peer-review process, and there are still serious outstanding questions regarding EPA’s data and methodology.”

    Wenonah Hauter, executive director of Food and Water Watch, said the draft report “illustrates the dangers of moving forward with a technology before we know the facts. It is also a huge blow to the oil and gas industry, who has continued to insist that fracking is safe.”

    A 30-day peer-review process led by a panel of independent scientists also will be conducted.

    via EPA study says hydraulic fracturing likely contaminated drinking water in Wyoming town | NewsOK.com.
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