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Tags: gas drilling, hydraulic fracturing, Marcellus, natural gas, unconventional play
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Tags: blogger, Coronado LLC, El Paso Corp, ExxonMobil, gag order, intimidation, judge, lawsuit, McGill, Rancho Los Malulos, suppression, Texas
From The Sun Gazette, 3/17:
Spill from drill site likely contains 2-butoxyethanol
WATERVILLE – A substance used in the natural gas drilling process is discoloring and distorting the texture of spring water running off a Cummings Township sidehill.
. . . . .
The mysterious substance was seen flowing down the slope, under the road and into Pine Creek, said Daniel T. Spadoni, spokesman for DEP’s northcentral region office. Officials from another state agency alerted DEP.
“We were notified (Monday) morning by the Department of Conservation and Natural Resources,” Spadoni said. “There was a white foamy material discharging from a spring down the hill.”
. . . . .
Terming it a surfactant, Spadoni said a substance known as Airfoam HD was causing the water run-off to be unnatural in appearance.
. . . . .
Surfactant used to treat Pennsylvania General Energy wells affected the water run-off, which Spadoni said had nothing to do with hydrofracturing.
Workers for the Warren-based energy company are drilling five wells in the area, high above the road, but he said they have yet to reach the point of using highly pressurized water to break the rock underneath the ground.
They were using the whitening substance as a lubricant that lowers the surface tension between air and water, according to Spadoni.
A receptionist answering a Pennsylvania General Energy phone Tuesday afternoon said company officials were not available to comment.
“They’re attempting to determine what caused this problem and what actions they can take to stop it,” Spadoni said of energy company representatives, with whom DEP members have been communicating.
The only precaution Spadoni recommended to residents is to avoid the suspicious spring water run-off in the area.
“I don’t think you would want to drink this discharge,” he said.
The substance leaking down the hill isn’t listed as dangerous on a Material Safety Data Sheet, according to Spadoni.
“I don’t believe there are concerns about drinking water in Waterville at this time,” Spadoni said, adding that area residents can continue regularly using tap water in their homes.
The investigation will continue.
“We don’t know for sure what its chemical composition is,” Spadoni said.
-end of excerpt of Sun Gazette article-
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Now, you have to wonder what Material Safety Data Sheet Spadoni is talking about. The one copied below says the component of Airfoam HD is 2-butoxyethanol, also known as 2BE, which is linked to a particular kind of adrenal tumor that’s rare… unless you happen to be Laura Amos, who was exposed to 2BE, got that adrenal tumor, and wrote the following (click above on her name for complete text):
In August 2004 I came across a memo written to the US Forest Service and BLM Regional offices in Delta County, describing the health hazard posed by a chemical used in fluids that are injected underground to enhance the release of methane. Dr. Theo Colborn of Paonia, Colorado submitted the memo in response to decisions that were being made in Delta County by the government officials to allow gas exploration and development on the Grand Mesa. Colborn is the President of the Endocrine Disruption Exchange, Inc (TEDX) and for over 10 years directed the World Wildlife Fund’s Wildlife and Contaminants Program. She has been honored worldwide for her focus on the effects of synthetic chemicals on human and wildlife health. The focus of Colborn’s memo was on a chemical called 2BE, used in fracturing fluids.
The following information was taken from Colborn’s report: “2BE is a highly soluble, colorless liquid with a very faint, ether like odor.” She wrote that at the concentration to be used in Delta county 2BE might not be detectable through odor or taste. “2-BE has a low volatility, vaporizes slowly when mixed with water and remains well dissolved throughout the water column.” “It mobilizes in soil and can easily leach into groundwater.” “It could remain entrapped underground for years.”
She noted it is readily absorbed by the skin and can easily be inhaled as it off-gasses in the home. Colborn cited the Agency for Toxic Substances and Disease Registry Profile that listed the following effects of 2-BE: kidney damage, kidney failure, toxicity to the spleen, the bones in the spinal column and bone marrow, liver cancer, anemia, female fertility reduction, embryo mortality, and the biggie that got my attention – elevated numbers of combined malignant and non-malignant tumors of the adrenal gland.
-end of excerpt-
Here’s the MSDS that Spadoni mentions, but, hmmm, maybe just hadn’t read?
"Component: 2-butoxyethanol"
A deep bow and sweeping tip of the hat to Nastassja Noel for the Material Safety Data Sheet.
For more on this story, and more photos, see
Citizens Alarmed By Foam Discharge
Tags: 2-butoxyethanol, 2BE, contamination, DEP, Laura Amos, MSDS, spill
The Independent Weekender reports:
Landowners’ pipeline group forms
Staff Report
Published: March 17, 2010A group of Susquehanna and Wyoming County landowners concerned about natural gas pipeline easements has formed, and is willing to share information with other landowners to form their own neighborhood groups or for others to join them.
The Lemon Township Pipeline Group has been meeting for months and its members are looking at a range of easement and right-of-way agreements that leaseholders need to consider as more and more drilling companies come into the area looking to get the gas from the Marcellus shale to market.
Core Lemon group members are concerned that property owners lack adequate information about what’s coming to the area as well as what their rights are when negotiating a natural gas pipeline easement or ‘right-of-way agreements.
Such issues as price, nature, location, type, pipeline depth below surface, installation, road repair, pressure, timetable, abandonment, rights, restrictions and environmental responsibilities are among the many issues that individuals need to consider.
Members of the core group want to impress a sense of strength in numbers in requiring both the drilling and pipeline industry to move forward in a way that indeed is responsible to the region’s environmental well-being, and land stewardship.
Anyone interested in joining the discussion should contact pipelinerowinfo(at)yahoo.com
Tags: eminent domain, pipelines
Quoting Chamber president Kevin Keeley, The Star Gazette reports:
“This is an information session, not an advocacy session. It’s not a hearing, not a debate,” he said. “It’s simply an opportunity for the chamber constituency, which is the business and professional community, to learn more about some fundamental facets of the gas drilling phenomena.”
The 90-minute program will include brief presentations from: Mike Atchie from Chesapeake Energy Corp.; Dale Duncan, Schlumberger operations manager, Northeast Basin; Larry L. Michael, executive director of Workforce & Economic Development, Pennsylvania College of Technology, and Richard C. Stedman, an associate professor at Cornell University in the Department of Natural Resources.
—————————
With a list of presenters frontloaded with representatives of Chesapeake and Schlumberger and a booster like Mr Michael, what else could this forum legitimately be called but an advocacy session?
If it’s really information – accurate information – that you want, why would you turn to industry representatives to get it? Do you get your car-buying advice from the salesman at the dealership?
And why can’t regular citizens attend what was apparently first advertised as a public meeting, so they can hear what you’re hearing? What are you afraid of?
Readers, please, feel free to submit your ideas… Perhaps we can help the Chemung County Chamber of Commerce find the right noun.
Tags: Chamber of Commerce, Chemung
Citizens for Healthy Communities
FOR IMMEDIATE RELEASE: March 17, 2010
March 19th Chemung Economic Forum Comes Under FireChemung County Chamber of Commerce’s March 19th Economic Forum on natural gas drilling in the Southern Tier, to be moderated by Chemung County Executive Thomas Santulli, is being criticized for prohibiting the public and including presentations dominated by the gas industry and its supporters. Although the Forum, scheduled for Friday, March 19 at 7:30 am at the Holiday Inn-Riverview in Elmira, was advertised as open to the public, many people who called for reservations to the event were turned down.“When I called on March 3, I was told that the Forum was sold out,” said David Walczak of Bath, “but others who called for tickets to the breakfast were told that the event was only open to members of the Chamber.”
The scheduled speakers at the forum are heavily biased toward the gas industry. They are natural gas industry officials from Chesapeake Energy Corp and Schlumberger, Inc., a representative of the Pennsylvania College of Technology who has spoken out extensively in support of hydraulic fracturing drilling of the Marcellus Shale and someone from Cornell University.
“If the Economic Forum was merely a private Chamber of Commerce meeting, they would certainly have every right to exclude non-members,” said Mark Schlechter, a resident of Steuben County, ”but the participation of the County Executive, and possibly other elected officials, turns the Forum into a public event. The actions of the Chamber and the County Executive in excluding concerned members of the community raise questions about what will be discussed at the Forum and, more importantly, what decisions will be made by our elected leaders about gas drilling in our region.”
There is currently a moratorium on hydraulic fracturing, known as “fracking”, in New York State due to concerns about the environmental and economic effects of the drilling and plans to build a Schlumberger gas drilling service facility in Horseheads are on hold pending a State Supreme Court ruling on the issue. A number of organizations have formed in area counties to raise public awareness of the hazards of injecting and storing millions of gallons of toxic-laced water into the ground and of the numerous examples of water contamination, air pollution and noise and odor complaints in other states where fracking has occurred.
“If public policy is to be set through closed forums such as the one moderated by our County Executive, then the public has a right to know what is being said and which elected officials are in attendance,” said Patricia Ladley, a Chemung County resident. ”This issue is too important to the health and economic well-being of our communities for us to be excluded.”
Tags: Chamber of Commerce, Chemung, Chesapeake, Schlumberger
From the Star-Telegram, January 14, 2010:
In D-FW, ’sobering’ asthma numbers
Look at a third-grade class or a youth soccer game, and start counting.
“One, two, three, asthma; one, two, three, asthma,” said Larry Tubb, senior vice president for system planning at Cook Children’s Health Care System. “That’s sobering.”
It represents a growing health problem in North Texas, where 1 in 4 children ages 8 and 9 has the lung disease. The state average for 5- to 9-year-olds is 7.1 percent; the national average for all children is 9.4 percent.
-end of article excerpt-
Now, why would the Dallas-Fort Worth area have a childhood asthma incidence that’s more than 2.5 times the national average?
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Now, if natural gas is such a “clean” fuel, why d’ya suppose they’d do that?
From the newsletter of the American Petroleum Institute:
API backs resolution to block EPA from regulating carbon emissions
The American Petroleum Institute was among the oil and natural gas groups that signed a letter expressing support of Sen. Lisa Murkowski’s, R-Alaska, resolution against the Environmental Protection Agency’s plan to regulate greenhouse-gas emissions. Energy prices could increase and many jobs would be affected under the agency’s proposal, according to the letter. Oil & Gas Journal (3/11)Natural gas suppliers oppose EPA’s GHG regulations: The Natural Gas Supply Association announced its support of a resolution sponsored by Sen. Lisa Murkowski, R-Alaska, that would stop the Environmental Protection Agency from regulating greenhouse-gas emissions. The agency’s proposed rule would “burden many natural gas projects with a time-consuming permitting process that would interfere with bringing more natural gas to market,” said trade group CEO Skip Horvath. The Wall Street Journal/Dow Jones Newswires (3/11)
For more on Senator Lisa Murkowski, see A Lobbyist Finds His Senator
Letter to Edmonton Journal: “Letting gas companies have their way has devastating results”
Edmonton Journal
March 15, 2010
Re: “Natural gas and its ‘Drill, baby, drill’ conundrum,” The Journal, March 8.
I am a central Pennsylvania native who lives in the midst of the Marcellus shale region. I cannot begin to describe how devastating it is to witness the wholesale destruction of this once strikingly beautiful state by natural gas firms from both the United States and Canada. If you are a gas company executive living in Edmonton or Calgary for example, you do not have any ancestral bonds or other firsthand knowledge of this predominantly rural and less wealthy corner of the United States. Instead, your singular goal is to extract the natural gas and, accordingly, reap substantial profits. Meanwhile, massive and permanent environmental damage will be the only legacy of the Marcellus shale drilling left for Pennsylvanians. Although drilling only started less than two years ago, the state’s freshwater supplies (including the Susquehanna River, which flows into Chesapeake Bay) are already being depleted at an alarming rate and the forests and farmlands systematically destroyed. So, whenever energy experts like Peter Tertzakian or anyone else raises the “drill, baby, drill” credo, please remember that whatever economic gains are being derived from retrieving natural gas in the Marcellus shale region via hydraulic fracturing, they are coming at a terrible environmental cost comparable to that of the oil-sands, or perhaps even worse.
Marsha Ann Tate, Pleasant Gap, Penn.
Last month the American Petroleum Institute announced it was hiring a “grassroots” organizer (actually, it’s a stretch to call anything The Nature Conservancy does “grassroots” – but that’s a slightly different story, which we’ll come back to below).
Grass-Roots Organizer Jumps From Nature Conservancy to API
By ANNE C. MULKERN of Greenwire – February 26, 2010 nytimes.com
The oil industry’s biggest trade group has nabbed one of the environmental community’s top grass-roots organizers as it ramps up efforts to build a network of citizen lobbyists.
Deryck Spooner, who ran Nature Conservancy’s push to spur legislative action on climate change, will now head American Petroleum Institute’s grass-roots activism arm. The hiring move sends a nervous flutter through environmental groups. By recruiting Spooner, green groups said, API adds someone with both credibility and deep knowledge of grass-roots strategy. Spooner previously ran campaigns for labor group AFL-CIO and abortion rights organization NARAL.
“He’s a big dog,” said Tyson Slocum, energy program director at watchdog group Public Citizen. “It gives API somebody with enormous grass-roots experience running major campaigns. This indicates that API is taking their grass-roots strategy in a very serious direction.”
The move comes two months after the trade group cut 15 percent of its staff and President Jack Gerard said API had “not been as effective as we could be in educating public officials or the public about the critical role of oil and gas in our economy. … You will see us evolve into a more nimble, more aggressive” organization. “We’re going to be aggressive in our outreach to educate the public,” he said (E&ENews PM, Dec. 11, 2009).
Hiring Spooner is part of Gerard’s strategy to expand grass-roots activism, API spokeswoman Cathy Landry said, adding, “Jack’s vision is to mobilize the 9.2 million people whose jobs rely on the oil and gas industry. We do plan to step that up.”
API’s community activism last year sparked controversy, as environmental critics accused the trade group of steering employees to rallies aimed at killing climate legislation. API said the rallies allowed both employees and other citizens to voice concerns that climate legislation would raise energy prices and affect jobs.
Spooner, 42, doesn’t see the move from Nature Conservancy to API as that big of a jump.
“I have worked for vastly different organizations throughout my career,” Spooner said. “The bottom line is it’s all about advocacy, that’s what I’m passionate about. Mobilizing and organizing people to influence the public process and public policy is what I truly love to do.”
“At the end of the day, I don’t necessarily believe that the views of [the Nature Conservancy] and API are incompatible,” Spooner added. API members use technology “to ensure that the places that they drill are not impacted,” Spooner said, while the Nature Conservancy uses a scientific approach in deciding where to protect land and water. API members, he said, “don’t just want to drill anywhere for drilling’s sake. There’s a lot of science going into where they drill.”
. . . .
“There’s no useful contribution that the American Petroleum Institute is making to forwarding our energy economy,” said Kert Davies, research director for Greenpeace. “They’ve been at the center of campaigns to derail climate progress for 20 years.”
Ramping up grass-roots efforts with Spooner shows API believes that’s what’s necessary to achieve its goals, he said.
“They know that ultimately it’s going to come down to a grass-roots toe-to-toe battle on energy policy,” Davies said. And having Spooner at API gives the oil trade group new advantages, he said, including information about environmental group strategies.”
For complete NYTimes article, click here
And now, the other shoe – API’s version of grassroots. How’s about some petrochemical-based synthetic dyes to make that astroturf look like the real thing? – sort of. From API’s “Energy Tomorrow” website:
Tell Congress to Allow for Increased Access to Oil and Natural Gas Resources
Domestic oil and gas will provide the jobs, revenues and energy our nation needs. And Canada, our friendly neighbor to the north and top supplier of oil, will continue to play a vital role as we seek greater energy and economic security. Take action and send a letter now.
Tweet Your Support for Domestic Access
Update your Twitter status to show your support for increased access to domestic oil and natural gas, as well as Canadian oil sands. Post to Twitter now.
Post about Energy Access to Facebook
Tell your Facebook friends that you support increased energy access and encourage them to get involved. Post to Facebook now.
Sign-up for Mobile Updates
Sign up to receive updates to your mobile phone on the latest energy legislation. It’s a fast and easy way to stay connected to the issues you care about. Sign up now.
____________________________________
Yup, that’s the industry’s other major asset: shamelessness. Watch for ongoing efforts to rebrand thoughtless over-consumption as “Domestic Access.” Thanks to the ongoing efforts of industry leaders to exploit every possible drop of hydrocarbons during their own lifetimes, while they can hoard the profits, there may be an “Energy Tomorrow” of sorts, but an “Energy Day After That” becomes somewhat more problematic.
Thanks to The Nature Conservancy for being so without ethics that it will apparently hire any amoral crook if s/he’s clever enough. No wonder real climate-protection legislation hasn’t come to pass and isn’t on the horizon either. This is why the bottom is falling out from under the big environmental organizations – they’ve forgotten their [grass]roots.
Tags: API, astroturfing, Energy Access
*Substitute your state environmental regulating agency
Guest post by Lynn Senick:
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On Feb. 2, DEP fined Talisman Energy $3,500 for violations at its “Cease” well pad in Troy Township discovered during inspections in 2009. A February 2009 inspection revealed that the company had not publicly posted the permit number and other required information at the entrance of the well pad. During a follow-up inspection in June 2009, a DEP statement explains, “flow-back fluids — or the fluids that are used to break up underground rock and then return to the surface — were found discharging into a drainage ditch, an adjacent sediment basin, and eventually through a vegetated area into an unnamed tributary of the south branch of Sugar Creek.” The Daily Review
“A vertical drilled well in The Marcellus Shale zone costs $810,000 to drill while a horizontal drilled well will cost you roughly 3-5 million dollars.” oilshalegas.com In the Marcellus shale, Talisman drilled nine gross (nine net) wells during the quarter, for a total of 12 gross (12 net) in the first half of the year. The development plan is ahead of schedule and the company is now producing at rates in excess of 30 million cubic feet of gas per day. ugcenter.com .
COST OF DRILLING ONE HORIZONTAL WELL; $ 4 MILLION
A FINE OF $3500 is 0.0875% – the value of a a used Chevy Caravan.
VALUE OF CLEAN AIR, LAND, & WATER?
PRICELESS
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Tags: DEP, fine, spill, Talisman, violations
photo credit The Daily Star
Excerpt from The Daily Gazette, Schenectady, NY on the pipeline explosion in North Blenheim, NY, twenty years ago on March 13, 1990:
Effects of deadly blast still felt
EDWARD MUNGER JR
Earth scarred by the massive explosion that rocked this rural Schoharie County town 20 years ago has since healed and buildings reduced to smoldering rubble have long since vanished.
But people who recall the sudden death of two neighbors and the devastation caused when a pipeline burst say they don’t expect to ever forget the fateful morning of March 13, 1990.
The pipe carrying liquid propane, running north of state Route 30 near West Kill Road in North Blenheim, ruptured and sent a cloud of flammable gas drifting downhill.
The cloud exploded about 7:30 a.m. when it got to the intersection of Route 30 and West Kill Road, killing Blenheim resident and firefighter Robert Hitchcock, 53, and Central Bridge resident Richard Smith, 43. The explosion destroyed 14 homes and injured five people.
New gear added to the pipeline’s infrastructure and town buildings built after the blast — dedicated in honor of Hitchcock – stand as reminders of the devastation today.
And in the 20 years since, more stringent regulations governing pipelines and an added emphasis on safety have accompanied a 10 percent reduction in serious accidents, a government spokesman said.
North Blenheim resident Peter Giesin recalls being in the cellar of his West Kill Road farmhouse when his daughter called to him asking what was going on in the field outside their home.
“I looked out, there’s this white plume. At the time, I thought it was smoke. I thought an airliner had crashed or something,” Giesin said.
The white cloud was a plume of gasified propane that leaked out of the Texas Eastern Products Co.’s underground pipeline — a pipeline run underground in the 1960s despite resident opposition that was ultimately overpowered by eminent domain.
“I realized it was the pipeline blowing this plume of gas across the field which, naturally, was going downhill away from us. Then, within less than five minutes, a ball of fire came back over the hill from downtown where it ignited,” Giesin said.
“The village looked like a war scene. It was just destroyed,” said Blenheim resident Gail Shaffer, who was working as secretary of state in Albany and rushed to the scene.
“When we got to the village, it was all charred remains of buildings. There were 12 or 15 different fire companies with their hoses still on. It was organized chaos at that point,” Shaffer said. “I will never forget.”
photo credit The Daily Gazette
Today, offshore and onshore gas transmission lines carrying hazardous liquid such as propane stretch for more than 2.5 million miles in all 50 states, according to the federal Pipeline and Hazardous Materials Safety Administration, or PHMSA.
New York state accounts for a total of 53,275 miles of underground pipelines.
PIPELINE MAINTENANCE
Following the 1990 disaster in North Blenheim, engineers hired by the government determined that several months before the accident, workers from the pipeline company raised the pipe to insert a rubber washer between it and a casing pipe around it. The work was in response to a short circuit detected in the system that uses a small electrical charge to keep the pipe from corroding.
Engineers at the time said the crew filled the pipeline hole back in but the dirt might have been frozen. Once thawed, it allowed the pipe to settle and a weak point in the pipe — a manufacturing defect — broke in half.
A National Transportation Safety Board investigation that followed criticized the fact that the pipeline’s operators were unable to detect a drop in pressure when the pipe leaked; the nearest monitoring location was in Gilbertsville, Otsego County, about 15 miles west of Oneonta and roughly 68 miles from North Blenheim. Afterward, the pipeline company installed remote terminal units to monitor the pressure at pump stations and receiving stations.
The same 4,200-mile-long pipeline, which stretches from Texas to Selkirk, Albany County, sprang a leak in January of 2004. An explosion that followed destroyed one home in Delaware County but no injuries were suffered.
Engineers determined the 2004 pipeline leak was caused by frost heave separating a valve from the pipe. Roughly 5,000 gallons of propane in the pipe burned for three days after the blast.
In the 20 years since the blast in North Blenheim, the federal Department of Transportation has created the Pipeline and Hazardous Materials Safety Administration, expanding the department’s inspection and enforcement abilities and doubling the number of inspectors and accident investigators, said Damon Hill, a spokesman for the federal DOT.
“Since then, we’ve had a number of regulations introduced that includes regulations for [pipe] integrity management programs, operator qualifications, control room management and quite a few other things to help make pipelines a lot safer,” Hill said.
Among the new standards is a requirement that pipelines be capable of undergoing an internal inspection, he said.
The “call before you dig” number was developed after the Schoharie County explosion, Hill said, to help stem third-party damage to pipelines he said are responsible for the bulk of pipeline failures today.
The pipeline changed hands in terms of ownership, with TEPPCO merging with Enterprise Products Partners LP in October of 2009, Enterprise spokesman Rick Rainey said.
Complete story available for fee from The Daily Gazette
Tags: eminent domain, pipelines
TO:
Attn: dSGEIS Comments
Bureau of Oil & Gas Regulation
NYSDEC Division of Mineral Resources
625 Broadway, Third Floor
Albany NY 12233-6500
dmnsgeis@gw.dec.state.ny.usFROM:
Brian Brock, retired geologist
Franklin NYDATE:
30 December 2009RE: CONSIDERATIONS FOR REVISIONS TO dSGEIS
Aquifer Depths, Database of BOGR states that depths to the base of aquifer is so poorly known that they need to set a default value of 850 feet. Despite this, there in no mention of a database for the driller’s report of the depth of fresh and brine waters at each well, which could be then used to predict depths to the base of the aquifer for future well permits.
Bedding Planes and Fractures Flow of groundwater is usually controlled by these discontinuities, but there is no adequate discussion of bedding planes and fractures in Chapter 4, Geology. Large roadcuts, quarries, railroad tunnels, and aqueduct tunnels can provide data.
County Health Departments Many have neither the expertise or resources to investigate reports of water pollution, as suggested by SGEIS. This responsibility is an unfunded mandate. Health departments from counties in the fairways of the black shales should provide input.
Cumulative Impact Draft SGEIS has only a few scattered and brief discussions of this. If a boom in extraction of gas from black shales develops in NYS (as it has elsewhere), then cumulative impacts will be substantial. Final SGEIS should have comprehensive Cumulative Impact Assessment to include: water withdrawal, waste disposal, traffic, road damage, air pollution, manpower, and community. Current SEQRA handbook covers cumulative impact.
Disclosure of Frac Chemicals to Public While BOGR requires that companies report all chemicals used to them, there is no provision for releasing this information to the public. These chemicals will be injected below the public’s property and might contaminate the public’s drinking water. Without such information, the public can not monitor the purity of its drinking water.
Fairway, Extent of Alpha Environmental consultants defines “fairway” by rock properties (pages 4-14 and 4-18) without considering the setting of the rock units. As a result, Fig. 4.7 and 4.12 show fairways of Utica and Marcellus shales extending north and east to outcroppings. Production of economic quantities of gas require the hydrostatic/lithostatic pressure differential produced by thousands of feet of overlying rock. As drawn, these figures give the mistaken impression that areas that are immediately south and west of shale outcroppings will have gas extraction and should be revised.
Faulting
Figure 4.13 gives the mistaken impression that the fairways for Utica and Marcellus shales are mostly free of faults — faults that could provide pathway for waters from black shales to aquifers. True the figure is labeled “Mapped Faults …”, but the distinction between mapped faults and total faults is not discussed. The bedrock is monotonous and poorly exposed, so probably many faults have gone unmapped. This figure is based on a compilation over 30 years old, and could be updated with data from natural seismicity, seismic imaging, and mapping from NYC reservoir and tunnel construction.Figure 5-1 This schematic of a well pad is confusing at best, and much of it is wrong. If it is of a multi-well pad in development, then it should be so labeled. This figure should be completely redrafted. There is too much wrong to detail here, but contact me if you want suggestions.
Flowback Disposal
Destination Within months of the approval of the final SGEIS, wells will each begin producing hundreds of thousand or millions of gallons of flowback. A safe way to dispose of this is required, but there appears to be none in NYS. Draft SGEIS does not estimate the volume of flowback expected nor discuss which sites could accept this volume.
Reporting In Appendix 6, the proposed Environmental Assessment Form does not require reporting of frac fluids that leave New York State. Given the lack of a significant disposal option in state, most of this water may be sent out of state.Formation Waters, Composition of Draft SGEIS provides a summary of flowback analyses but not analyses of formation waters, despite BOGR regulating gas drilling for over a century. Without such, several key points of the SGEIS can not be finalized, including:
* How can formation waters be distinguished from flowback?
* Can formation waters be processed through POTW?
* Can formation water be safely spread on roads?Frac Trespass
CI Hearings Currently a hearing for compulsory integration can be held after well work is completed as long as land has been leased where drilling takes place. Presumably a frac job is designed to fracture throughout entire drilling unit. May they frac before the whole unit is leased or integrated?
Taking Fracing is a new technology with imperfect control of the extent of resulting fractures. How can neighbors to the drilling unit be assured that fracing will not extend under their properties, neither trespassing nor taking “their” gas?Funding and Staffing Although this is outside the scope of SGEIS, until BOGR obtains adequate resources for enforcement, the public can have no confidence that GEIS and SGEIS are anything more than ink on paper.
ICF International Analysis. Appendix 11
Pore Flow The mathematical analysis of fluid flow through intact rock via pore space (pp. 24 – 31) is a pointless. There is no doubt that 1000 feet of unfractured rock would provide a barrier to frac fluids over short times, but how often is this the case?
Fracture Flow Despite wasting pages on calculating pore-flow rates, ICF dismisses chances of an open flow path from fractures, faults, or well bores as “theoretically possible but extremely unlikely” (pg. 31) without attempting to quantify this risk. The experience of NYC in drilling their aqueduct tunnels suggest that the risk could be substantial.
Reporting Fluid Flow Even if the odds of an open flow pathway “is very small” (pg. 32), given the large number of wells expected, then occurrence of open pathways is almost certain. Therefore one of the required non-routine incidents that drillers should report (Appendix 10, Supplementary Permit Conditions, #46) should be failure to hold pressure or anomalous fluid loss during fracing.
Injection Wells ICF consultants may be correct that high-pressure fracturing for a short time (“typically less than a day per stage”, pg. 34) make it unlikely that frac fluids could immediately reach aquifers. On the other hand, injection wells do pump waste water at high pressures for longer times. The consultants neglect to consider long-time flow of fluids from injection wells. Injection wells remain one of the few ways to dispose of waste water from drilling, flowback, or plugging.
Lack of Evidence The final conclusion (pg. 34): “There are no known incidents of ground water contamination due to hydraulic fracturing.” is deceptive. Because there has been no testing of groundwater before and after fracing by either drillers or BOGR, it is more correct to say that no proof exists that groundwater remains uncontaminated due to hydraulic fracturing. “Absence of evidence is not evidence of absence.”Incident Response With a large enough number of wells, everything that could go wrong will go wrong: surface spills, well seeps, aquifer pollution, fires, explosions, etc. While SGEIS requires the reporting of any non-routine incidents by drillers, there is no mention of the response required by BOGR.
Inspections
Frequency For most wells, no inspections are required during the entire life cycle of a site: site preparations, drilling, fracturing, completing, and production. (A single inspection during surface casing is required only for the minority of wells in primary and principal aquifers.) Considering that much of the BOGR oversight is limited to the review of paperwork self-reported by drillers, a minimum number of random and unannounced inspections is necessary to encourage honest reporting and should be required.
Surface Casing and Initial Fracing Site visits should be required for these two steps. These two visits by Mineral Resource Specialists would also allow inspection of the general operation. If this is beyond the current staff, it only argues for an increase in staffing.
Transparency There is no written procedure for monitoring and inspecting a well over its life cycle from site preparation to production. Without this, the public has no way to determine if BOGR is fulfilling its responsibility to protect the environment.
Workload BOGR has stated that it has and will continue to provide sufficient oversight of each gas well. Should there be a rush of permit request, the number of permits issued would be limited by the workload of mineral resource specialists. Neither final GEIS nor draft SGEIS lists what the workload is for permitting and oversight of a single well. Nor is there a limit to the number of active wells in a mineral resources specialist’s caseload. Without such information, the public can not be assured that BOGR is providing sufficient oversight. Without sufficient oversight, GEIS and SGEIS are only ink on paper.Loss of Springs and Wells During the drilling of the first several hundred feet through aquifers, there is a risk of loss or fouling of neighboring water sources until the surface casing is cemented. Special attention in inspection or reporting should be required during this period.
LPG Fracing If this water-free fracing may someday be proposed for use in NYS, will a second SGEIS be required? Wouldn’t it make sense to include this technology in the current SGEIS? Obtaining and disposing of millions of gallons of water for each well constrains future fracing.
Metering Currently BOGR does not require periodic recertification of gas meters at well heads, spot check reading of meters that is done by companies, or audit company records – procedures that are routine in other states. (These deficiencies were cited in NYS Comptroller audit 2005-S-54.) Such procedures are required to assure that landowners and state receive what are legally due them. The much greater volumes of gas produced by horizontal wells make a true accounting all the more important.
Methane in Groundwater Draft SGEIS mentions that methane naturally occurs in groundwater. It does not discuss that this proves that there are pathways between black shales and aquifers — although not necessarily the targeted shales. Gas is much more buoyant and less viscous than frac fluid, and therefore it is not clear how much of these fluids would follow the same pathways and over what time. Nevertheless the nature and implication of these pathways should be discussed.
Multiple Plays There is substantial overlap of the fairways for Marcellus and Utica shales. A smaller area additionally includes the fairway for Herkimer tight sandstones. (Indeed Nornew brags that it has this “triple play” in Madison and Chenango Counties.) There is also a chance of the spotty occurrence of Trenton/BlackRiver plays Multiple plays multiply the effects at each well pad, but the draft SGEIS ignores the effects of multiple plays of gas, particularly on cumulative impacts.
Pollution
Bonding Drillers should be bonded for the clean-up of any pollution caused by their activities. (Currently they are bonded only for plugging well and restoring the site.) Commonly companies will set-up a shell company for drilling each well with assets just sufficient to cover expenses. Without bonding, should there be major pollution, the company has no reserves that could recovered for the clean-up.
Database BOGR can state that it knows of no incident of pollution from fracing in NYS. This claim can not be confirmed because BOGR does not maintain a database of reports of pollution. Such a database should be built.
Liability In neighboring Pennsylvania, any pollution within 1000 feet of well head is presumed to be the responsibility of the driller who must provide sufficient water and remediate the pollution to the satisfaction of DEP. (Purity of the provided water must be independently certified.) There is no such provision in the final GEIS or draft SGEIS. Without it, a individual land owner could have the expense and aggravation of dragging a polluting company through the courts for years to get satisfaction, whereas the owner needs are immediate.
Risk Despite BOGR statement that there are no case of pollution of aquifers from fracing, there are numerous documented cases of pollution of aquifers from gas drilling. To the land owner who has lost their drinking water and a much of the value of their property, the distinction between drilling and fracing is academic. The SGEIS should more fully discuss causes of pollution during the entire drilling process and how to eliminate any causes not covered in GEIS.Publicly-Owned Treatment Works, Appendix 21 Despite this list of 135 POTWs, there is no guarantee that a single one of these works is capable of treating of produced waters, from drilling, flow back, or plugging. POTW do not remove the chemicals from these waters but only dilute the toxins to below legal limits. All the toxins are dumped into the river. Without representative analyses of produced waters, it is not possible to even know if it is safe to pass these waters through these works or what dilution is required. Indeed the vast majority of operators are not even considering applying for permission from DEC to accept this waste. Including this long list in the SGEIS deceptively give the impression that there are many possible sites to receive the waste waters produced.
Refrac Permits Black shales in NYS may be refraced as soon as one year after the initial frac – although five years is more typical elsewhere. Draft SGEIS requires a permit for refracing (8.3.2), but does not specify what information will be necessary to obtain this permit.
Road Spreading of Produced Fluids Permitting for a Beneficial Use Determination for road spreading does not specify what are the acceptable concentration of pollutants.
Set Backs, Residential GEIS requires set backs of 100 feet from drill pads to residences for a single well and this is not increased in the draft SGEIS. This is the smallest setback of any state, with most having setbacks of 200 to 600 feet. Even if this is adequate for single vertical wells, this is inadequate for single horizontal wells, let alone pads of multiple wells, multiple plays, and refacturings. One site could be actively drilled and fractured for three years for a single play.
Seismic Monitoring Fracing is a developing technology with an imperfect control of the extent of resulting fractures. Without seismic monitoring during fracing, the owners of neighboring can not be assured that gas will not be withdrawn from beneath them. At least for a trial period, this should be required for a few wells and the results reported.
Toxicity of Chemicals Draft SGEIS does not compare the toxicity of chemicals used in drilling and fracing, claiming that there is no way to measure this: “there does not seem to be a US-based metric” pg. 9-10. However the Federal Mineral Management Service does such rating of such chemicals in its capacity of regulator of off shore drilling. Their methodology should be applied to the land-based use of such chemicals.
Trial Period Once the final SGEIS is adopted, BOGR should begin with a limited number of permits for the new horizontal drilling and high-volume hydraulic fracturing of low permeability gas shales — maybe one multi-well pad in each county. After a formal review, the annual number of such permits could be gradually increased.
Unconventional Gas Reservoirs While they are mentioned, it would help if there was a brief discussion of the differences among coal beds, tight sandstones, and black shales and of the differences in extracting gas from them.
Water Testing
Composition While water testing is required around the drill site, what is required to be tested does not include chemicals in frac fluids. Without these, results will be less useful for showing contamination. What is more, this testing is not required to be done such that the results would be admissible in a court of law, thereby giving a false sense of security to the property owner.
Location For vertical wells, testing within a circle1000 feet in diameter may be sufficient, but for horizontal wells, a corridor at least 330 feet on either side of the horizontal well bore should be included. Without this, BOGR is assuming that fracing could never pollute aquifers and avoiding any evidence that could contradict.The Bureau of Oil and Gas Regulation is to be commended for compiling so much information for the SGEIS, but much work remains to be done. Indeed, so much needs to be revised in and added to the draft SGEIS that a second round of comments will be necessary before the final SGEIS is adopted. However from my experience with the public hearings this fall at Chenango Valley High School, comments should be limited to written submissions.
Dr. Ronald E. Bishop
Cooperstown, NYDecember 30, 2009
Attention: dSGEIS Comments
Bureau of Oil and Gas Regulation
NYSDEC Division of Mineral Resources
625 Broadway, Third Floor
Albany, NY 12233-6500To Whom It May Concern,
Please accept my comments regarding the Draft Supplemental Generic Environmental Impact Statement for the Oil, Gas and Solution Mining Regulatory Program: Well Permit Issuance for Horizontal Drilling and High-Volume Hydraulic Fracturing to Develop the Marcellus Shale and Other Low-Permeability Reservoirs.
Section 2.2 Public Need and Benefit
I note that economic benefits data are limited to a 5-year time frame and are nearly entirely speculative. A more appropriate time frame would be 50 or more years, including the period after which natural gas reserves (and related revenues) have been exhausted. Refusal to estimate (or even acknowledge) the “bust” phase that follows any projected industrial “boom” constitutes a failure to thoroughly assess the overall economic impact of this industry statewide.
In this context, it is noteworthy that gas wells in the Barnett Shales, projected to produce for 30 to 50 years, have exhibited catastrophic production decline (in spite of repeated hydraulic fracturing) after 4 to 5 years of operation (1), with overall productive life spans of only 7 to 10 years. This suggests that technologies for recovery of gas from shales are immature; therefore, widespread application of the current state of the art runs counter to NYSDEC’s mandate to efficiently exploit the state’s natural gas reserves. A thorough assessment of public benefit (also reflected in Section 4.4.3 Potential for Gas Production and Section 5.16.3 Production Rate) must address this issue.Section 2.4.6 History of Drilling and Hydraulic Fracturing in Water Supply Areas
The statement, “No documented instances of groundwater contamination are recorded in the NYSDEC files from previous horizontal drilling or hydraulic fracturing projects in New York.” is scandalous. These kinds of projects represent a tiny minority of gas wells developed in New York, and so in no way reflect NYSDEC’s history of regulating this industry. Numerous instances of soil and groundwater contamination caused by the gas industry were recently documented by Toxics Targeting, Inc., primarily using sources available to (or maintained by) NYSDEC (2). Equally spurious was the statement, “The reported Chautauqua County incidents, the majority of which occurred in the 1980’s…, could not be substantiated…” Many of these incidents occurred in the period from 2000 to the present, and were substantiated not only by the Chautauqua County Department of Health, but also by the US Geological Survey. My own poll of New York county health officials pointed to other incidents where gas drilling appeared to impact water supplies in Allegany, Chemung, Genesee and Steuben Counties (3). In light of such evidence, this section of the SGEIS should be stricken and replaced with a realistic assessment of gas industry culpability for collateral damage.
Section 3.2.1.1 SGEIS Applicability – Definition of High-Volume Hydraulic Fracturing
This section minimizes the pervasive issue of scale which, more than any other factor, underlies the need for updated regulations. Compared to the GEIS’ “typical” volume of 80,000 gallons of fluids used per well, the average horizontally-drilled hydraulic fracturing project will involve over 4,000,000 gallons, 50-fold greater volume than was considered in the GEIS. I submit that this difference is not merely “significant”; it is enormous. For example, in spite of technological advances that permit effective additive concentrations one-tenth of those employed 10 years ago, the net result is still more than a five-fold increase in tonnage per gas well. The accompanying increased risk in transfer-related mishaps (arguably one of the greatest potential hazards of the industry) is, in my view, severely underestimated throughout the dSGEIS. This is particularly acute where multi-well projects are under development.
Section 5.4.3 Composition of Fracturing Fluids
This section contains gravely serious deficiencies. First, it is inappropriate for NYSDEC to accept any less than full disclosure from energy companies regarding the chemicals they intend to use in natural gas extraction projects. Products that are not completely described should not be permitted to be used in New York.
The catalog of health concerns noted by NYSDOH for each chemical category leaves much to be desired. Ecological impacts of the various chemicals are entirely omitted, and some important human health effects are missed as well.
For example, one of the bromine-based biocides, 22-dibromo-3-nitrilopropionamide (DBNPA) has been shown to be extremely toxic to aquatic organisms. In fact, DBNPA is damaging or lethal to trout, bay oysters, Mysid shrimp and Daphnia magna (so-called “water fleas”) at concentrations below its chemical detection limit (4). The dSGEIS segment on health effects from microbicides was summarized thus: “Toxicity information is limited for several of the microbicidal chemicals.” This level of scientific scrutiny is dangerously inadequate for an agency charged with promoting public and environmental safety.
Worse yet, some information provided in this section is misleading. For example, acetylenic alcohols, including propargyl alcohol, are inappropriately grouped with simple alcohols and glycols. This group is summarized in the dSGEIS thus: “Exposure to high levels of some alcohols (e.g. ethanol, methanol) affect (sic) the central nervous system.” Consider the toxicity of propargyl alcohol (5): this chemical (inhaled or absorbed through the skin) induces a range of ailments that include multi-organ failure. A sensitizer, it elicits increasing responses to decreasing exposures, and symptoms can recur months or years after all exposure has ceased. Propargyl alcohol is widely used as a corrosion inhibitor; therefore, no discussion of health effects is adequate that fails to warn potential exposure victims about this additive.
A major question is completely omitted in this section. No one understands, and no one at NYSDEC proposes to investigate pre-existing organisms in deep rock structures, including target formations. What archaea, bacteria and algae currently live in these strata? What is their value to society via biological, pharmaceutical or medical research? How are they affected by the drastic changes imposed on their ecosystems by horizontal drilling and hydraulic fracturing? NYSDEC should inventory, protect and develop these natural resources.
Finally, after describing (albeit incompletely) probable health effects from carcinogens, endocrine disruptors, reproductive toxins, and potentially lethal compounds planned for use at rates of hundreds or thousands of pounds per project, this section ends with the statement, “As mentioned earlier, the 1992 GEIS addressed hydraulic fracturing in Chapter 9, and NYSDOH’s review did not identify any potential exposure situations associated with horizontal drilling and high-volume hydraulic fracturing that are qualitatively different from those addressed in the GEIS.” I submit that size matters here; a massive difference in scale requires an adjustment in regulatory approach in the same sense as different care is needed for a tiger than for a house cat.
Based on the deficiencies of this section alone, I would recommend withdrawal of this draft supplement to the GEIS for oil, gas and solution mining.Section 5.11.1.1 Subsurface Mobility of Fracturing Fluids
This section and the associated Appendix 11 register a glaringly flawed assumption: that fracturing fluids are being pumped into dry rock formations. Analysis of flowback fluids clearly indicate (dSGEIS Table 5-8 and Section 5.11.3.1) that rock strata including target formations are filled with salts-saturated water, i.e. brine. The ability of deep rock formations to accommodate additional non-compressible fluids may well depend on their ability to direct them into faults, abandoned wells or other, more porous strata. This consideration, along with accounting for repeat hydraulic fracturing, should guide a fresh attempt to model the subterranean flow of fluids introduced at high pressures for natural gas extraction processes.
Section 5.12 Flowback Water Treatment, Recycling and Reuse
This section contains some of the most optimistic operational projections in the entire dSGEIS. Several of the modular technologies mentioned in this section are annotated, “Modular … units have been used in the Barnett Shale.” This might be better phrased, “… have been tested in the Barnett Shale”, because none of them are in widespread use anywhere in the US. I suggest a more realistic set of assumptions that anticipate that 10% of flowback fluids will be reused / recycled, and the rest will require transport to distant disposal sites.
Section 5.13 Waste Disposal; 5.16.6 Brine Disposal; 5.16.7 Naturally Occurring Radioactive Materials in Marcellus Production Brine
Gas well flowback fluid is currently classified as “industrial waste” under state code (Article 27, Title 9, Paragraph 371.1. (e) (2) (v)). However, 18 of the 69 compounds (dSGEIS Tables 5-8, 5-9, 6-1 and 6-2), as well as radionuclides (dSGEIS Appendix 13) reported in flowback fluids are listed in New York as hazardous substances. Therefore, the NYSDEC commissioner should, by his authority under Article 27, Title 9, Paragraph 371.2 (b) (2), reclassify gas well flowback fluids as hazardous waste.
Permits for high-volume gas well development projects should not be issued unless and until intrastate infrastructure designed specifically for treating their hazardous wastes is built and functioning.Chapter 6 Potential Environmental Impacts
Conspicuously absent from mention here are the potential impacts of residual infrastructure that remains in the ground when gas extraction activities are completed. No complete inventory, let alone hazard assessment of abandoned oil and gas wells in New York has been assembled to date, and no long-term follow-up assessments related to proposed development are suggested in this dSGEIS. This constitutes a major failure in operational planning.
Section 6.1.1 Water Withdrawals
Large parts of the Southern Tier of New York situated over developable shale gas deposits lie outside regions regulated by the Susquehanna River Basin Commission, the Delaware River Basin Commission or New York City’s West of Hudson Watershed. NYSDEC makes no provision for monitoring or limiting water withdrawals in these areas. This constitutes a major failure in operational planning.
Section 6.1.6 Waste Transport
Manifesting of gas drilling wastes (hazardous by nature if not by state law) should be required for transport by Part 364-permitted haulers. Description of these loads as “general industrial waste” poses unacceptable risks for emergency responders to roadway incidents.
Section 6.5 Air Quality
This elegantly researched section suffers from a failure to aggregate emissions from a number (several to several hundred) of vicinal gas wells. Such aggregation is currently being investigated in Dish, Texas (6, 7). Preliminary results suggest that hazardous levels of benzene, ozone and other pollutants that accumulate in an intensively drilled area can measurably influence the health of people who live there. NYSDEC scientists would do well to study these data and consider ways to develop commensurate analytical scope in New York.
Section 6.7 Centralized Flowback Water Surface Impoundments
Central impoundments for flowback fluids should not be permitted. Along with maintenance of pit liners and connecting conduits, maintenance of headspace should be expected to be problematic. New York has virtually no capacity for treating these fluids (dSGEIS, (Section 5.13 Waste Disposal), and facilities in Pennsylvania are maximally utilized. With nowhere to go, flowback in New York will build to critical (and greater) mass. If not contained in rigid containers, this fluid will overflow into surrounding properties. This would be particularly troublesome during periods of heavy rain or snow.
Section 6.8 Naturally Occurring Radioactive Materials in the Marcellus Shale
This section appropriately mentions the frequent occurrence of radiondclides in flowback fluids, but omits any mention of state and federal regulatory incongruities that usually complicate disposal of mixed hazard (chemical and radiological) waste. This is particularly salient in evaluating future applications by energy companies for beneficial use determinations to permit spreading of flowback fluids on roads (Appendix 12). I recommend consideration of these complications before any such applications are accepted.
Section 6.9 Visual Impacts
Others may consider the photos of actual wellsites in New York reassuring; I do not. Even before scale-up to an unprecedented level of intensity, this kind of development in my region of the state should be expected to exert a significant negative impact on hunting, fishing, local recreation and tourism. Regarding mitigation measures, I submit that “hope and wait until the worst is over” is not a viable strategy.
Chapter 7 Mitigation Measures
Throughout this section, suggestions that NYSDEC personnel should have the opportunity to supervise various critical steps in the development process (eg. surface casing cementing) should be replaced with mandates that agency personnel shall be present for any such operations. Similarly, language proposing that mitigation steps “may” or “should” be taken should be replaced with “shall be taken”.
Section 7.1.4.2 Sufficiency of As-Built Wellbore Construction; Appendices 8, 9 & 10
Existing regulations regarding the mixing and placement of concrete are incoherent. Particularly egregious is the requirement that poured and pumped concrete should be left undisturbed in a casing until a compressive strength of 500 pounds per square inch is achieved. The chemistry of concrete curing is minimally defined as the hydration of calcium silicate. The rate at which this process occurs depends heavily on several factors that include temperature, water concentration, and the presence of modifying chemicals. All these factors are in flux with any gas well project: (1) Temperature varies from as low as 23 deg. F at the surface to as high as 150 deg. F in the target formation – and neither extreme is ideal for curing. (2) Water and brines are ubiquitous in New York subterranean rock strata, and can either add to or subtract from water available for curing depending on the layer depth. (3) Commonly added fluidizers and plasticizers all tend to impede curing, but their responses to varying temperatures and water concentrations are not well characterized.
Taken together, these issues make meaningful determination of the time at which concrete throughout a well casing has reached any particular compressive strength practically incalculable. Further, shock resistance (related to channel or crack formation) is better correlated with tensile than compressive strength. I submit that the relative success in sealing New York gas well projects to date has been the result of many lucky guesses. This is not a basis for sound regulation. I strongly recommend instituting a standard period of time for waiting on concrete to cure, with the specific standard to be set by rigorous investigation of the salient parameters.
A concrete bond log should be required for every surface casing. Further, specific site conditions under which intermediate casings must be installed should be formulated.Section 7.1.11 Protecting the Quality of New York City’s Drinking Water Supply
I take umbrage at the notion that my or any other New Yorker’s water supply is less worth protecting than that of New York City. Even so, the NYC Department of Environmental Protection, in its final impact assessment (8), makes clear that the best of proposed regulations are anticipated to expose New York City’s drinking water supply to substantial risk of serious damage. Since this is the case, then acceptably safe development of gas from New York’s shales is probably not possible. My recommended response to this realization is that NYSDEC abort any attempt to update gas development regulations and institute a state-wide ban on high-intensity gas development.
Section 7.1.12 Setbacks
This section is incoherent, lacking clarity about how interacting factors (e.g. occupied dwellings, public buildings, and various water supplies) should be interpreted in terms of setback requirements.
There is no mention of setbacks from abandoned oil or gas wells; this is a major omission.Section 7.5 Protecting Air Quality
Frankly, major industrialization of a region is incompatible with protecting air quality. If the goal is maintenance of air quality that is characteristic of New York’s Southern Tier today, then the mitigation measures discussed (not mandated) are doomed to failure.
Section 7.11 Mitigating Road Use Impacts
NYSDEC offers practically no assistance in this endeavor. Municipalities should receive assistance with posting and appropriate bonding of roadways, and a centralized trust fund should be established to protect private taxpayers from having to pay for roads ruined by energy corporations and their subcontractors. This section contains no discussion of privatization of gas revenues accompanied by socialization of the risks and costs of collateral damage, let alone any mitigation of this scenario.
Section 7.12 Mitigating Community Character Impacts
This section contains no description of existing community character with which future attributes might be compared. Major potential impacts omitted from this section include: influences of permanent industrialization, changes in the types and numbers of cottage industries now typical of New York’s Southern Tier, and influences of the “bust” phase of a boom / bust economic cycle. I recommend that NYSDEC conduct a rigorous examination of existing community character as prelude to an expanded discussion of impacts mitigation.
Section 7.13 Mitigating Cumulative Impacts
There is no meaningful discussion of cumulative impacts in this section, let alone any attempt to describe mitigation measures. This constitutes one of the greatest failures of operational planning in this dSGEIS.
Chapter 9 Alternative Actions
Option 9-1, Prohibition of Development, is ruled against by NYSDEC on the basis that it would violate state law, which requires development of natural resources. I submit that, in light of the overwhelming value of resources that would be damaged or destroyed by intensive gas extraction from New York’s shales, it is the sole legal and just option.
Appendix 15 Hydraulic Fracturing – 15 Statements from Regulatory Officials
Hydraulic fracturing has, in my view, metamorphosed from a technically challenging array of methods to release trapped gases from rocks into a caricature of all that is feared about the natural gas industry. Judged soberly, these methods elevate risk from gas extraction processes primarily by requiring the transport, handling and use of exotic chemicals which would otherwise not need to be moved, handled, or disposed of. In comparison to these elements of risk, the actual steps involved with “fracking” are anticlimactic – though not risk-free.
Attribution of a specific accident to any single risk factor is always fraught with difficulty, even when that factor is known by the weight of evidence to be significant. For example, the fact that one of the drivers in an auto accident was intoxicated is not de facto evidence that the drunk driver was at fault. Still, the drunk driver bears some responsibility.
As this issue has developed publicly, I have observed energy company spokespeople caricaturizing “hydrofracturing” as that demon which is feared by the uneducated public, but which investigators can never make culpable – provided it is considered in the narrowest methodological sense and as a sole causative factor. I am disappointed that NYSDEC has chosen to perpetuate this caricature.
This appendix demonstrates, more than anything, the extent to which a variety of public officials are willing to collude in half-truths. While a handful of state officials who were queried acknowledged that gas extraction produces unintentional consequences, all whose responses were included here acceded to the premise – without context, of course – that, under the narrow conditions of the question posed, hydraulic fracturing has never polluted any groundwater.
NYSDEC had the opportunity in an appendix like this to perform a valuable service of education to the public, putting issues with hydraulic fracturing into proper context. I could not be more disappointed that you chose a different path.Respectfully,
Ron Bishop
References Cited:1. Arthur Berman, “Lessons from the Barnett Shale suggest caution in other shale plays”,
ASPO International Peak Oil Conference, August 10, 2009.2. Walter Hang, “Drilling Spills Profiles”, Toxics Targeting, Inc. 2009
3. Ron Bishop, “Experiences with Natural Gas Extraction: Interviews with Health Officials
in New York’s Counties”, private communication 2009. (Attached)4. EPA, “Reregistration Eligibility Decision (RED) 2,2-dibromo-3-nitrilopropionamide
(DNPA)”, September 1994.5. BPPB Consortium, “Propargyl Alcohol U.S. EPA HPV Challenge Program Revised
Submission”, July 2003.6. Jack Z. Smith, “Texas expediting environmental complaints on natural gas operations in
Barnett Shale”, Fort Worth Star-Telegram, December 23, 2009.7. Wilma Subra, “Results of Health Survey of Current and Former DISH/Clark, Texas
Residents”, Earthworks Oil and Gas Accountability Project, December 2009.8. New York City Department of Environmental Protection, “Impact Assessment of Natural
Gas Production in the New York City Water Supply Watershed: Final Impact Assessment
Report”, December 22, 2009.
Citizens Group Worried About Water Pollution
“Luzerne County Citizens for Clean Water is starting out small . . . but is going to grow, said Dr. Tom Jiunta of Lehman Township… Area residents don’t realize that the number of people who will benefit from Marcellus Shale drilling in the region is small compared to those who could potentially be harmed by it, he said.”
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At ft.com John Dizard writes in part:
The true cost of shale gas production
Published: March 7 2010 09:45 | Last updated: March 7 2010 09:45
I try not to get into arguments over other people’s religious convictions. Even if you win your point, you make an enemy. That’s been a conventional understanding since the Thirty Years War. Sometimes, though, you have to clear your throat and carefully offer a heretical thought, if lives or large amounts of property are at risk.
For example, I think it might not be a bad idea to examine the faith-based assumption that the US has a virtually unlimited supply of natural gas from shale formations that can be extracted at a low price for the indefinite future. Perhaps the few people who think shale gas will be produced at a higher cost, and more slowly, than generally believed should be heard out, rather than be executed or sentenced to work in the salt mines. If you disagree, I will quickly withdraw that comment.
The shale gas religion crosses the usual political boundaries. The environmentalist wing believes that shale gas can displace dirty coal-fired generation. Liberals believe it will help power the clean energy policy. National security conservatives believe shale gas can end dependence on Middle Eastern or Venezuelan oil. Economic conservatives believe it can close the current account deficit and drive an economic recovery, at least until even more nuclear power can come on line.
There are environmentalists, rural landowners, and health advocates who worry that shale drilling could contaminate water supplies. Most of them, though, want to have more careful regulation, rather than prohibition, of shale gas exploitation.
I was prompted to comment on shale gas again after watching a well known, highly emotional American television stock market commentator suggest that shale gas will be so abundant that facilities for importing natural gas could be converted to export the stuff. This when the present low US price for natural gas is about 10 times the economic value of gas stranded in huge Middle Eastern deposits. Never mind that you can’t push a button and make those facilities run backward.
. . . . .To their credit, gas prophets such as Aubrey McClendon, chief executive of Chesapeake Energy Corp, have been saying that gas at USD 5 per thousand cubic foot is not sustainable. In their laudable enthusiasm for their business, though, they may have understated just how unsustainable the price is.
Ben Dell, of Bernstein Research in New York, who has, so to speak, done some of the deepest drilling into the shale gas industry numbers, believes that the full cost of finding, developing, and operating shale gas wells, and paying an average return on capital to investors, requires a spot gas price of USD 7.50 to USD 8 a thousand cubic foot.
As Mr Dell points out, the horizontal drilling rigs that are needed to drill shale gas wells are in relatively short supply. “We think there will be a 15% to 20% increase in costs from last year to this year. That includes the costs of drilling and fracking [hydraulic fracturing of rock layers holding gas].”
Furthermore, the producers partially insulated themselves from gas price weakness over the past year with hedges that are gradually running off. New hedges have to be put on at lower prices. So revenues will be declining while costs are increasing.
Shale gas is not magic. Production costs are high, and probably underestimated. An even more gas-dependent policy will accelerate the coming price rise. For the producers’ sake, it better.
Waaaay back, in the early days of the Marcellus gas rush, we were told over and over again that a key part of the technology was the magical horizontal well, which, though much more expensive than a verticalwell, would produce much more gas. But Arthur Berman has noted that the horizontal wells don’t necessarily produce enough gas to make their much higher cost a bargain: they start out like gushers, but then they have very steep decline curves. Further, I think that by now most of us have noticed that in shale-gas-producing regions, the gas industry ends up infilling the spacing units with a lot of additional wells. Each new well within each unit adds more cost. I don’t know for certain, but it seems to me that the cost of all of that infilling must at least be approaching the cost of simply drilling many old-fashioned vertical wells — in other words, it looks as if they are duplicating the same costly drilling situation that the magical new horizontal wells were supposedly designed to avoid. Oops.And there are a lot of other problems as well. As mentioned above, it’s going to take a LOT of money to get all of that gas out of the ground, and then there are the costs of converting infrastructure to gas, not to mention the costs involved in cleaning up the mess. All of that is money that could be spent elsewhere–like on coming up with permanent solutions to the energy problem rather than constructing a temporary “bridge” to nowhere.
Unfortunately, a lot of environmental damage has already been done by shale gas drilling, and more is likely to follow before the gas bubble bursts. And when it does burst, a lot of the gas companies will be broke, so don’t look to them for help cleaning up the mess.
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Guest post by Maura Stephens, originally published at Reader Supported News
“Update: PEMA urges residents to prepare now for possible flooding.”
“DEP directs gas drillers to replace water.”
“Man killed by fall off Towanda drilling rig.”
I read these three stories in that order. The first two were in the Pike County [Pennsylvania] Courier, the third in the Binghamton [New York] Press & Sun Bulletin. The headlines of the first (get ready for a flood) and third (a man died in a gas-drilling accident) are self-explanatory. The second, about “replacing” water, went like this:
“The Department of Environmental Protection (DEP) . . . ordered Schreiner Oil and Gas Co. to provide a permanent solution to water supply issues at two homes the company’s drilling activity impacted near Hedgehog Lane, McKean County.
“DEP previously determined that the company, based in Massillon, Ohio, was liable for affecting the water supplies of homes. . . . among the contaminants identified were total dissolved solids, chlorides, manganese, iron, dissolved methane and ethane gas.”
Does this not terrify everyone who lives in the huge gas-drilling and potential gas-drilling region? (The Marcellus Shale encompasses large swaths of New York State, almost all of Pennsylvania, Ohio, and West Virginia, and parts of Maryland, Virginia, Tennessee, and Kentucky. A total of 31 or 32 states have deposits of so-called “natural” gas, more properly termed “fossil-fuel gas.”)
Here are some facts:
1) The horizontal, slick-water hydraulic fracturing process of gas drilling (“chemo-fracking”) uses and releases numerous toxic chemicals — carcinogens, endocrine disruptors, naturally occurring radioactive materials.
2) Accidents happen.
3) People make mistakes.
4) Floods occur.Anyone who has ever experienced a flash flood knows that you’re going to run for your life and your loved ones’ lives first, and for your most expensive and/or most precious possessions next.
Even if gas companies had our best interests at heart — and you’d have to be a total naïf to think they do — there is simply no way to protect us from all these toxins that would go streaming into our water systems in the event of a flood, let alone the inevitable accidents and mistakes that will occur.
Because they will.
In the cases where the gas companies have to “replace” water, what are we talking about?
You can’t “replace” water that has been contaminated with poisons. You can bring in huge “water buffaloes” with 300 or 500 gallons of “fresh” water from elsewhere (and who is monitoring that water? Where does it come from?) to resupply a family with drinking, cooking, and bathing water, but the ground is still contaminated.
The vegetables and flowers and shrubs in the family’s garden are still reliant on that water for survival. The squirrels, bunnies, and raccoons . . . the chickadees, warblers, and woodpeckers . . . the frogs, fish, and turtles . . . the crickets, bees, and peepers . . . the family cat and dog . . . all drink the water from that contaminated ground. Toddlers in sandboxes eat the dirt. Kiddie pools and grown-ups’ pools, bird baths, ponds, streams, rivers, and lakes . . . all can be contaminated from just one spill.
You can’t “replace” bad water with good. Period.
There is not enough recompense in the world to mitigate this kind of permanent damage to a person’s home and property or to our surrounds, or to our own health and our children’s health.
It is up to communities to decide if the risks are worth the riches that will go to the gas companies and to a few members of the communities.
Let’s think about these risks for a moment: Someone in my community will die because of fracking. It’s inevitable. The man who was killed on a gas rig in Towanda, Pennsylvania, has a name: Greg Allen Henry. He was from Athens, Tennessee. He was 31 years old and was killed when he fell from a rig and suffered massive head trauma.
Are the risks worth the reward? How many lives are worth how many dollars? The job (of the many promised to Pennsylvanians and New Yorkers) came, no doubt, with pretty good pay to bring a Tennesseean so far from home. But was it enough for Greg Henry’s family? Will it help ease their grief?
Will you be getting free energy for life, if you lease your land and it’s fracked? Will you ever feel safe drinking the water? Will the royalty fees cover the loss of your home’s value? Where will you go if you are forced to leave your valueless home? What will happen to the investments of time, equity, sweat, and tears—let alone cash—you’ve poured into it? How much money is enough?
Is a Tennessee man’s life worth as much as a Towanda child’s life? If your child drinks contaminated water today and develops cancer in five years, will a gas company come forward to help you pay for your child’s chemotherapy and radiation treatments, and hold your hand while you wait for the latest medical test results that will tell you if she will live or die?
Are the risks worth the reward?
Whose risks? Whose reward?
Are the risks worth the reward?
Every community must come up with its answer.
See also Is the juice worth the squeeze?
Tags: Community Effects, deaths, water contamination, water wells, workers
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Texas Pipeline Association, backed by Chesapeake, goes after small town to exhaust its budget
Since publishing the results of an air study, performed by Wolf Eagle Environmental, that showed that compressor stations are seriously degrading air quality in Dish, the town has been subjected to threats of legal action from the Texas Pipeline Association. An e-mail reveals that Chesapeake Energy (chk.com) is behind the TPA’s efforts to exhaust Dish’s small budget:
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Sent: Friday, January 29, 2010 6:30 PM
To: Bryn Meredith
Subject: RE: Response Letter to TPACelina,
I’ll try to look this over Monday and give you a list of what might be missing. Mostly I was hoping to get any mail or email correspondence between the Mayor and Wolf Eagle…guess that hasn’t happened?
Grover
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Celina Romero is a lawyer representing the TPA; she signed the letter threatening Dish with legal action if the town does not release more documents to the TPA. According to the mayor, the only documents not released relate to private health issues of Dish residents, information to which the TPA is not entitled.OK, fast forward – Aubrey McClendon, CEO of Chesapeake, sues small town to exhaust its budget:
Tags: Aubrey, Chesapeake, harrassment, lawsuit, McClendon
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