College of Law Center for Energy and Sustainable Development

Energy Forward Blog

Articles tagged with: marcellus_shale

16 Sep

James Van Nostrand
September 16, 2014

Charleston Gazette
September 2, 2014

$5B, 550-Mile Natural Gas Pipeline to Start in Harrison County
Caitlin Cook

Several major pipeline projects have been announced in recent months, geared toward moving the natural gas produced in the Marcellus Shale region to markets to the East and South. According to Bloomberg New Energy Finance, as many as ten pipeline projects are in the works that would deliver two billion cubic feet of gas from the Marcellus Shale to the Northeast and Mid-Atlantic. The major announced projects include the following:

  • Atlantic Coast Pipeline: This is a $5 billion, 550-mile project beginning in Harrison County in West Virginia, and continuing to North Carolina and Virginia. It will transport 1.5 billion cubic feet of natural gas per day. Four companies are sponsoring the project: Dominion, Duke Energy, Piedmont Natural Gas and AGL Resources. Dominion, which has a 45 percent stake in the pipeline, will build and operate the pipeline. Construction is expected to start in summer of 2016, with completion expected by late 2018. The pipeline will have a 42-inch diameter in West Virginia and Virginia, and a 36-inch diameter in North Carolina.
  • Diamond East: Williams is proposing to expand its 10,200-mile Transco interstate pipeline to allow more Marcellus Shale gas to head to Transco’s northeast market, including Pennsylvania, New Jersey and New York local distribution companies and power generators. The Diamond East Project is being designed to provide up to one billion cubic feet of new capacity from points in Lycoming and Luzerne counties to Mercer County, N.J. The price tag of the project is estimated to be between $500 million to $800 million.
  • Algonquin Incremental Market: This pipeline upgrade will add capacity of 342 million cubic feet per day. It is being built by Algonquin Gas Transmission and Spectra Energy, and is designed to move Marcellus production to Algonquin City Gates. The shippers are 6 gas utilities in New England.
  • PennEast: This is a $1 billion pipeline project being proposed by AGL Resources, NJR Pipeline Company, South Jersey Industries, and UGI Energy Services. The 100-mile pipeline will be able to deliver up to 1 billion cubic feet per day of lower cost natural gas produced in the Marcellus Shale region to homes and businesses in Pennsylvania and New Jersey.
  • Constitution: This new pipeline, being built by Williams Pipeline, Cabot Oil & Gas, Piedmont Natural Gas, and WGL Holdings, will add capacity of 650 million cubic feet per day, and will connect Appalachian natural gas supplies in northern Pennsylvania with major northeastern markets. The approximately 124-mile pipeline will have a 30-inch diameter, and will extend from Susquehanna County, Pa., to the Iroquois Gas Transmission and Tennessee Gas Pipeline systems in Schoharie County, N.Y.
  • Atlantic Sunrise: This Williams project would include expanding the existing Transco transmission pipeline by adding new pipeline infrastructure in Pennsylvania, as well as modifying some existing Transco facilities in other states, to allow gas to flow from north to south. The project involves a total of approximately 178 miles of new greenfield pipe, two pipeline loops totaling about 12 miles, two and half miles of existing pipeline replacement, two new compressor facilities in Pennsylvania, and other facility additions or modifications in five states (Pennsylvania, Maryland, Virginia, North Carolina, South Carolina). The project will increase capacity by 1.7 billion cubic feet per day, and is proposed to go into service in the second half of 2017.
  • Leidy Southeast: This 30-mile long pipeline upgrade by Williams will add capacity of 525 million cubic feet per day, primarily to serve local gas distribution companies along the Atlantic Seaboard.
  • Niagara Expansion: Tennessee Pipeline is proposing to add capacity of 158 million cubic feet per day to interconnect the Marcellus Shale in Pennsylvania to its interconnect with TransCanada Pipeline in Niagara County, New York.
    In addition to these projects located within or near the Marcellus Shale region, there are several projects within the Northeast designed to transport the new gas supplies throughout New England once the Marcellus gas reaches the region.

This substantial infrastructure investment is being driven by the “bubble” of natural gas within the Marcellus Shale region. The production of natural gas within the region exceeds (1) the demand for natural gas within the region and (2) the capability to export gas out of the region, resulting in “trapped” gas within the region. According to NGI’s Daily Gas Price Index, natural gas prices at the Marcellus hub are in the range of $1.93 per Mmbtu versus a “national” price of $3.80 per Mmbtu at Henry Hub. When regional natural gas prices are running about one half of the national price, there is considerable interest in getting the natural gas out of the region and into the more lucrative markets around the country. Hence, the numerous pipeline projects that collectively would move two billion cubic feet of natural gas out of the region. According to the U.S. Energy Information Administration, gas output from Marcellus wells exceeded 15 billion cubic feet per day in July, and accounts for almost 40 percent of U.S. shale gas production.

The geographic shift in supply and demand for natural gas is causing a “re-plumbing” of the system. According to a June 2014 report from Goldman Sachs, 85 percent of the growth in U.S. natural gas production will come from Appalachia, while 60 percent of the growth in demand will come from the Gulf Coast. As a result, Goldman Sachs is projecting $21 billion in pipeline investment to move natural gas from the Marcellus Shale. $16 billion of that investment involves reversing the flow of existing infrastructure, i.e., moving the gas to the Southeast, which formerly got most of its gas from Louisiana, Texas and Oklahoma.
One of the big markets for gas from the Marcellus Shale is New England, where the percentage of electricity generated from natural gas has increased from 30 percent in 2001 to 52 percent, without any new pipeline capacity being built during that period. As a result, the price of natural gas delivered to New York City hit $123 per Mmbtu in early January 2014 when temperatures dropped to 7 degrees.

Until these new pipelines get completed, the depressed prices within the Marcellus region are resulting in idle wells. In Pennsylvania, about 3,000 of the 8,000 wells drilled are idle. According to one source, 1,000 to 1,500 of the idle wells could be activated if the pipeline infrastructure existed to get the gas to the market.
The implications of this surge in pipeline infrastructure investment for West Virginians are many. First, it will stimulate development of the Marcellus Shale within West Virginia in the long term. As long as natural gas prices within the region remain depressed due to the inability to move the gas out, it will have a dampening effect on new drilling. The number of “idle” wells in Pennsylvania illustrates this fact. Second, the region will lose its current price advantage on natural gas supplies. Once this pipeline infrastructure is in place, prices within the region will fall roughly in line with the national price. With gas within the region currently selling at about one-half the national price, we should be moving aggressively to reap benefits from this lower cost. Examples are promoting investment in the infrastructure to support natural gas-powered vehicles (compressed natural gas (CNG) for automobiles and liquefied natural gas (LNG) for trucks). Another example is encouraging industrial electricity customers to invest in on-site generation, with combined heat and power (CHP), or cogeneration, facilities that would generate electricity (with natural gas) and thermal energy for heating or cooling. In addition, our utilities could be giving a serious thought to investing in natural gas-fired generation to achieve some fuel diversity and reduce electricity prices.

Yet West Virginia has developed no policies that would stimulate the use of natural gas within the state to take exploit the current price advantage enjoyed in the region, which will endure for at least another 3-4 years, given the expected in-service dates of many of the pipeline projects. And, of course, over the longer term, natural gas is expected to maintain a price advantage over other energy sources and, in the case of NGVs, would result in emissions benefits as well as achieve greater energy security by displacing foreign oil. In the case of CHP, industrial customers would have a hedge against ever-increasing electricity prices, as utilities operating in West Virginia continue to “double down” on coal. Rather than exploiting low natural gas prices for the benefit of ratepayers, West Virginia utilities continue to increase their reliance on coal-fired generation. Mon Power’s acquisition of the Harrison plant, Appalachian Power’s acquisition of the Amos plant, and Wheeling Power’s proposed acquisition of the Mitchell plant are recent actions taken by West Virginia utilities to invest in 40+-year old coal plants, to the exclusion of any resource diversification that would flow some of the benefits of low natural gas prices through to utility ratepayers in the state. While there are understandable political reasons supporting these coal plant acquisitions in order to support the mining industry within West Virginia, it should also be recognized that these decisions come at a cost to utility ratepayers within West Virginia, who are burdened with electricity rates that are likely higher than they would be if utilities made resource acquisition decisions based on an objective of achieving the lowest price to ratepayers over the long term.

Third, the pipeline construction activity in and of itself will produce economic benefits for the state, to the extent the pipelines cross the state or West Virginians can gain employment with the pipeline construction firms. $10 billion in new investment over the next several years is likely to produce economic benefits throughout the Marcellus Shale basin, and West Virginians should be able to share in that increased economic activity. Fourth, this amount of pipeline construction will potentially have significant environmental impacts. The proposed route of the Atlantic Coast Pipeline, for example, will cut through mountains at nearly 4,000 feet and the habitats of three endangered species, and will cross six rivers in West Virginia, according to a letter from the Friends of Blackwater to Senator Jay Rockefeller. The Federal Energy Regulatory Commission (FERC) has an extensive stakeholder involvement process that must be followed before interstate pipeline projects will be approved. Interested citizens in West Virginia should get informed about pipeline routes and possible environmental impacts and consider getting involved in response to FERC’s required public outreach activities.

7 Nov

James Van Nostrand
November 7, 2012

New York Times Dot Earth Blog
November 5, 2012

How Natural Gas Kept Some Spots Bright and Warm as Sandy Blasted New York City
Andrew C. Revkin

My former colleague at Pace University, Andrew Revkin of New York Times Dot Earth fame, wrote an excellent post praising the role of natural gas in keeping the lights on in some parts of New York City in the aftermath of Hurricane Sandy. The well-kept secret, and one that deserves more attention, is the use of natural gas-fired combined heat and power (CHP) facilities to generate electricity and heat. New York University, for example, was able to go into “island mode,” and thereby maintain essential services on its Washington Square campus as the electric grid around it went dark. NYU had the foresight to install a grid of its own – referred to as a “micro grid” – which allows it to rely on natural gas-fired cogeneration facilities to provide a large portion of its electricity supply. More important, the heat that is produced in generating electricity, which is simply released into the atmosphere in typical large electric generating plants, is captured and used to heat and cool NYU’s buildings. Hence, the name combined heat and power, or recycled energy.

Two other former colleagues from my days at Pace Law School, Tom Bourgeois (Deputy Director of the Pace Energy and Climate Center) and Bill Pentland (a frequent contributor to make the case for CHP in Revkin’s blog post. According to Pentland,

Today’s electric grid was not designed to survive strong winds, storm surges, falling trees and flying debris and seems ludicrously inadequate for the demands of America’s increasingly digital and connected economy. The costs of hardening the electric grid will be vast. One widely cited study by the Brattle Group estimated that the electric utility industry will need to invest a $1.5 trillion to $2.0 trillion in infrastructure upgrades by 2030.

Despite spending epic sums of money on the so-called “smart grid,” the electric power grid seems as stupid as it was before spending billions in federal stimulus dollars.

Why throw good money after bad if we have a compelling alternative? And make no mistake about it, we have a compelling alternative to the conventional electric grid. It is commonly called the North American natural gas infrastructure.

Bourgeois, for his part, is a lifelong CHP advocate, and co-directs the DOE-funded Northeast Clean Energy Application Center, which is charged with promoting CHP and district energy throughout the Northeast. Here is the vision of the future electricity system articulated by Bourgeois:

We need a new vision of the electric generation, transmission and distribution system rather than one that moves electricity generated at remote locations, arriving at the point of end use . . . with a loss of 67 percent of otherwise valuable thermal energy. We need some pilots of operating micro-grids and district systems with combined heat and power that ought to represent the energy system of the future. Go beyond thinking of individual building efficiency to zero-energy blocks or neighborhoods. A vision of optimally creating a suite of resources, efficiency, photovoltaics, clean distributed generation, demand response, storage, all managed in synch with the larger transmission and distribution system.

The 67 percent figure to which Bourgeois refers is the energy efficiency of a typical large, central electric generating station, which reflects the discharge of the “waste” heat into the atmosphere instead of capturing it and using it to heat and cool buildings, as CHP systems do, thereby allowing them to achieve efficiencies that reduce the loss to less than 30 percent.

One can hardly disagree with Revkin’s conclusion: “[G]iven the role natural gas played in keeping the lights on in otherwise darkened parts of the city after this storm, it’s clear that this resource can play an important part in building a robust, resilient and flexible electricity and energy grid for the city and region.” This solution has even greater relevance in West Virginia, where we have an interest in stimulating demand for natural gas as a means of stabilizing natural gas prices, which in turn will allow the Marcellus shale resource to be tapped for the benefit of West Virginians. Policymakers in West Virginia should be pursuing measures that encourage the development of CHP facilities in the State. Large industrial facilities, for example, are prime targets for CHP installations. In addition to consuming large quantities of natural gas – which helps the “demand” side of the natural gas market in this State – the electricity produced by CHP facilities can provide some insulation from the inevitable electricity price increases that electric ratepayers in the State will continue to pay for the foreseeable future as a consequence of previous decisions by investor-owned utilities (AEP and First Energy) to rely almost exclusively on coal for electricity generation. We need our manufacturing and heavy industry to be competitive, and natural gas-fired CHP can play a huge role in that. And this is all in addition to the undisputed reliability and efficiency benefits of CHP noted by Messrs. Revkin, Bourgeois and Pentland.

26 Jan

New York Times
January 23, 2011

Chesapeake to Cut Number of Gas Rigs
Clifford Krauss

Chesapeake Energy announced on January 23 that it is reducing production of natural gas in response to falling natural gas prices. As stated in this NY Times article, natural gas prices have been steadily falling over the last two years because of a glut stemming from the rapidly increasing production in shale fields like the Haynesville in Louisiana, the Barnett in Texas and the Marcellus in Pennsylvania and West Virginia. And warmer-than-normal weather this winter has also cut normal seasonal demand significantly, putting further downward pressure on natural gas prices. According to the NY Times, Chesapeake’s announcement showed that the oil industry “does not know what to do with all the gas it is able to produce in shale fields, which were considered almost useless until a decade ago when new production techniques, including horizontal drilling and hydraulic fracturing, were first employed in a major way.”

26 Jan

New York Times
January 25, 2011

President Obama’s State of the Union Address

President Obama gave a prominent mention to shale gas development in his State of the Union address. In his remarks on the role of oil and gas in the national energy policy, he stated the following:

And nowhere is the promise of innovation greater than in American-made energy. Over the last three years, we’ve opened millions of new acres for oil and gas exploration, and tonight, I’m directing my administration to open more than 75 percent of our potential offshore oil and gas resources.

Right now – right now – American oil production is the highest that it’s been in eight years. That’s right – eight years. Not only that – last year, we relied less on foreign oil than in any of the past 16 years.

But with only 2 percent of the world’s oil reserves, oil isn’t enough. This country needs an all-out, all-of-the-above strategy that develops every available source of American energy.

A strategy that’s cleaner, cheaper, and full of new jobs. We have a supply of natural gas that can last America nearly 100 years.

And my administration will take every possible action to safely develop this energy. Experts believe this will support more than 600,000 jobs by the end of the decade. And I’m requiring all companies that drill for gas on public lands to disclose the chemicals they use.

Because America will develop this resource without putting the health and safety of our citizens at risk. The development of natural gas will create jobs and power trucks and factories that are cleaner and cheaper, proving that we don’t have to choose between our environment and our economy.

And by the way, it was public research dollars, over the course of 30 years, that helped develop the technologies to extract all this natural gas out of shale rock – reminding us that government support is critical in helping businesses get new energy ideas off the ground.

. . . . . .

Our experience with shale gas, our experience with natural gas, shows us that the payoffs on these public investments don’t always come right away.

According to the President, his administration “will take every possible action to safely develop this energy,” which could “support more than 600,000 jobs by the end of the decade.” That is welcome news. But right now we have more natural gas than we need, and this glut of supply, coupled with an unusually warm winter, has resulted in natural gas prices so low that Chesapeake Energy announced earlier this week that it was cutting production of natural gas (an 8 percent cut in daily production). Chesapeake will be reallocating its investments from natural gas fields to fields that produce oil and other hydrocarbon liquids.

In addition to a policy promoting the safe development of the nation’s shale gas resources, the President needs to promote a sensible energy policy that will provide a market for this gas to be used. One solution, of course, is the NAT GAS Act, which would convert large trucks to run on compressed natural gas. The NAT GAS Act (H.R.1380 and S.1863) would accelerate the use of domestic natural gas as a transportation fuel by providing financial incentives to fleets and individuals to switch their vehicles to natural gas and to install fueling stations to service them. We should deploy our natural gas resources to reduce our dependence on foreign oil and increasing the nation’s energy security. Passage of the NAT Gas Act is one means of pursuing this objective. The President should go beyond encouraging the development of shale gas resources and actively support legislation that would stimulate the market demand to help consume these newly developed natural gas resources.

23 Jan

Los Angeles Times
January 3, 2012

Let’s Do This Right
Hal Harvey

Hal Harvey, the founder of the ClimateWorks Foundation, wrote an excellent Op-Ed piece in the Los Angeles Times earlier this month with five recommended steps for “getting it right” in developing the nation’s shale gas resources. (The column was later reprinted in the Dominion Post.) Mr. Harvey’s five points:

  1. No leaks in the system. Given the global warming potential of natural gas versus CO2 (about 25 times greater), it is essential that gas leaks throughout the extraction, production and distribution process be minimized.
  2. Use gas to shut down old coal. The median age of a coal plant in the U.S. is 44 years, and the older plants are the dirtier ones for which it does not make economic sense to install scrubbers. Perhaps a better way to state this point, at least in West Virginia, is that we need to make sure that the increased use of natural gas to generate electricity does not displace the use of renewable generating sources, such as wind and solar. While natural gas-fired electric generation is roughly twice as clean as coal-fired, it is obviously not as clean as wind and solar (even under a life cycle analysis that takes into account CO2 emissions over the entire production cycle of a resource.)
  3. Strong standards for wells, with effective monitoring and enforcement. In West Virginia, the legislature recently passed, and the Governor signed, the Horizontal Well Act. The Act delegates to the WV Department of Environmental Protection (DEP) the task of developing well casing standards, and the Act substantially increases permitting fees to generate sufficient revenue for DEP to monitor and enforce compliance with the rules. Time will tell whether the rules will be sufficient, and whether DEP will have adequate resources to enforce them.
  4. Don’t allow toxic streams [from the disposal of fracking fluids] poison the land. Again, the Horizontal Well Act in West Virginia includes measures to address this issue, but there is some disagreement as to whether these measures are adequate.
  5. Drill only where it is sensible. In other words, allow zoning of natural gas development so that it is kept out of ecologically important areas.

As Mr. Harvey states, “gas can do a great deal for our energy future” in terms of energy independence, environmental benefits versus coal, and economic development (i.e., jobs). But it is important that this resource be developed in a reasonable manner that balances the environmental impacts of shale gas development against these indisputable benefits. Mr. Harvey’s recommendations offer some wise guidance on how to strike this balance properly.

30 Dec

Washington Post
December 16, 2011

A Boom in Shale Gas? Credit the Feds
Michael Shellenberger and Ted Nordhaus

This insightful article from the Washington Post makes the point that the breakthroughs that revolutionized the natural gas industry — massive hydraulic fracturing, new mapping tools and horizontal drilling — were made possible by strategic financial support from the U.S. Department of Energy (DOE). It should be noted that this same DOE is under serious attack for being unable to invest wisely in new technology, in the aftermath of the Solyndra bankruptcy (the solar firm that received $535 million in federal support but nonetheless slipped into bankruptcy last fall). In a nutshell, the technologies now used to extract natural gas from shale in a cost-effective manner were developed with the support of taxpayer dollars. And much of the early work in the 1970s was done right here in Morgantown, at the Energy Department’s Morgantown Energy Research Center. According to this article, the federal government generously subsidized drilling for non-conventional gas throughout the 1980s and 1990s, when oil and gas were cheap. The authors conclude that:

“[T]he lesson of the shale gas revolution is that we should not be so quick to judge government investments in energy technology. Between 1978 and 2007, the Energy Department spent $24 billion on fossil energy research. Billions more were spent through the Gas Research Institute and non-conventional gas tax credits. Those investments were widely panned as a failure during the ‘80s and early ‘90s, when gas was plentiful and cheap.”

30 Dec

December 28, 2011

Oil Giant’s Shell Game Nets Elderly Farmers
Joshua Schneyer and Brian Grow

This article from Reuters discusses that rather troubling use of shell corporations to avoid liability for voiding hundreds of land deals. It is understandable for a major gas company to use shell corporations to keep a low profile in order to avoid tipping off competitors and speculators about land leasing and drilling efforts. But the use of shell companies as a tactic to avoid liability for voiding leases, if true, is indeed troubling.

9 Dec

New York Times
December 8, 2011

E.P.A. Implicates Fracking in Pollution
Associated Press

The U.S. Environmental Protection Agency (EPA) issued a draft finding today suggesting that fracking may be to blame for causing groundwater pollution in Wyoming. The EPA found that compounds likely associated with fracking chemicals had been detected in the groundwater beneath Pavillion, Wyoming, a small community about 230 miles northeast of Salt Lake City where residents complained that their well water reeks of chemicals. EnCana Corp. owns about 150 wells in Pavillion. EnCana has been providing drinking water to about 21 families in Pavillion since August, 2010. Samples taken from two deep water-monitoring wells near a gas field in Pavillion showed synthetic chemicals such as glycols and alcohols “consistent with gas production and hydraulic-fracturing fluids,” according to the EPA statement.

In issuing its draft findings, the EPA also emphasized that the findings are specific to the Pavillion area. The agency said the fracking that occurred in Pavillion differed from fracking methods used elsewhere in regions with different geological characteristics. Specifically, the fracking occurred below the level of the drinking water aquifer and close to water wells. Elsewhere, drilling is more remote and fracking occurs much deeper than the level of groundwater that anybody would use.

EPA’s statement notes that “[t]o ensure a transparent and rigorous analysis,” it is releasing its findings for public comment and will submit them to an independent scientific review panel.

7 Dec

Pittsburgh Post-Gazette
December 6, 2011

EPA Criticizes State for Shale Air Pollution Rules
Don Hopey

The U.S. Environmental Protection Agency has strongly criticized Pennsylvania’s new policy guidelines for regulating air pollutants emitted by Marcellus Shale gas wells and development sites located in close proximity to one another. The EPA is taking the position that the Pennsylvania Department of Environmental Protection (DEP) October 12 draft policy differs from established federal law and PA’s own air pollution control plan by imposing new limitations on the aggregation of air emissions from multiple shale gas industry sources such as gas wells, compressor pumping stations and pipelines. That PA DEP policy uses the physical distance of one quarter mile between the shale gas facilities as a major qualifying criteria for determining if they should be considered as individual minor sources or a single, major source of air pollutants. In its November 21 agency comment letter, the EPA asserts that the federal Clean Air Act requires a broader geographic policy of aggregation, which may result in multiple gas development activities being treated as a single major source, and thereby requiring them to meet stricter emissions standards to prevent deterioration of existing air quality. The DEP’s “bright-line test” of one quarter mile as defining proximity was viewed positively by the natural gas industry as it provides some certainty and predictability for development. Environmental groups, on the other hand, opposed the rule on the grounds that regional air quality could ultimately degrade as a result of multiple gas industry sources of air pollution.

This presents an interesting issue of federal/state tension with respect to enforcement of environmental laws. Under the Clean Air Act, a policy of “cooperative federalism” is generally followed, which leaves it largely up to the states to implement measures to fulfill the ambient air quality standards prescribed by the EPA. The EPA is taking the position through comments in the DEP proceeding that the DEP policy is deficient in failing to account for the aggregate impact of multiple sources of pollutants. Ultimately, however, DEP has the primary responsibility for implementing the Clean Air Act within Pennsylvania, and it remains to be seen whether EPA will elevate the debate to raise a fundamental challenge to DEP’s delegated authority.

5 Dec

NRDC Switchboard
November 23, 2011

Dimock Thanksgiving Disgrace: DEP Gives Cabot the Ok to Stop Water Deliveries to Affected Residents
Kate Sinding

For the past two years, the residents of Dimock, PA have been receiving daily water deliveries, courtesy of Cabot Oil and Gas Corporation, which was found responsible for contaminating their well water. The original solution was to require Cabot to build an $11.8 million municipal water pipeline. Under a new agreement with the Pennsylvania Department of Environmental Protection, however, Cabot will cease to be responsible for providing fresh water to Dimock residents as soon as it established nineteen escrow funds – one for each affected home – with twice the assessed value of the home as well as offer to install a “whole house” methane treatment system for each household. So, effective on November 30, the water deliveries ceased.

In a separate but related development, the U.S. Environmental Protection Agency (EPA) sent a notice to residents of Dimock that EPA’s review has found the water in Dimock does not pose a threat to human health. EPA officials visited Dimock on November 10 and reviewed sampling data for the affected wells. According to a statement from an EPA regional office spokesman, “[b]ased on our preliminary evaluation of sampling data that was provided to us by residents and PADEP for wells in Dimock, we have not identified any ‘imminent and substantial endangerment’ which would trigger EPA to take emergency action under the Safe Drinking Water Act.” EPA further indicated that it is continuing to review the data.

The Natural Resources Defense Council (NRDC), for its part, claims that “Dimock water is still full of methane and other hazardous substances, and that even though the ‘whole house’ methane treatment system may reduce methane levels, it doesn’t work at taking the other contaminants out.”