Showing posts with label FLOWBACK. Show all posts
Showing posts with label FLOWBACK. Show all posts

Wednesday, April 25, 2012

New U.S. Fracking Emission Rules Unclear on Climate Impacts


Regulating emissions of methane from fracking to free natural gas will have important co-benefits in slowing climate change
U.S. EPA's pollution-cutting oil and gas rule will help cut emissions of a potent greenhouse gas without regulating it directly, say clean air advocates.
EPA released a final rule yesterday that requires new hydraulically fractured gas wells to use technology that will cut toxic substances and smog-forming pollution by 2015. As a co-benefit, the upgrades will also reduce methane -- a greenhouse gas with 30 times the global warming potential of carbon dioxide -- by up to 1.7 million tons, said EPA Assistant Administrator for the Office of Air and Radiation Gina McCarthy.
When it comes to cutting methane emissions from hydraulic fracturing, or fracking, wells, "[EPA] isn't aware of any other technologies that are effective as this rulemaking," McCarthy said.
"The standards are practical, flexible, affordable and achievable," she said.
The New Source Performance Standards will mandate that all new wells install "green" completions, technology that separates gas from liquid hydrocarbons from the flowback of wells to cut pollution. Well operators could also flare, or burn, waste gas instead of releasing it directly into the atmosphere.
But because methane is only a co-benefit, it is not an enforceable requirement, said Stuart Ross, communications director for the Clean Air Task Force.
"We know there's a lot more that can be done for methane," he said.




Thursday, September 29, 2011

Dear Citizens: We are writing to ask your permission to... Yours truly,The Gas Industry

Dear Citizens:
We are writing to ask your permission to develop shale gas in your states using high-volume, slickwater, hydraulic fracturing from long horizontal well legs (HVSHF).
Although you have allowed us to produce oil and gas for many years, we recognize that we are now asking you to allow us to do much more intense development than ever before, using a technology never before used in your area. We acknowledge our development plan for your states might eventually involve over 400,000 wells alone, with thousands more in other shale, and be valued in the trillions of dollars, over decades to come.
We have seen how such intense development with this technology has caused problems where we are using it already in gas shales. We have listened closely to your concerns about these problems, and others on the horizon, so we are writing you now to make a compact with you. We understand that you are granting us a privilege, that, collectively, all of you have to give us the right to develop your gas, because, quite honestly, our plans will significantly affect all of you, not just landowners with whom we might have a business relationship.
Therefore, if you give us the permission we seek, here are our promises to you:
1. Since we will not be developing in your area for another 2–3 years, we have time to help you prepare for our arrival:
• We will immediately fund appropriate training programs in your community colleges to produce homegrown workers for our industry. We will subsidize tuition for the students who commit to work in our industry. Those workers will get right-of-first-refusalon our job openings.
• We will immediately fund appropriate training programs for your emergency responseteams — fire, police, medical, and spill hazards — and we will equip themat our expense.
• We recognize that our heavy equipment will damage many of your roads and bridges. We will start now to pay to upgrade these so that they all remain usable not just by our equipment, but by you, too, throughout the development process. This will be a “stimulus” to help your unemployment situation now. When development is complete in an area, we will pay for final repairs necessary to leave all impacted roads and bridges in state-of-the-art condition. This will be a legacy gift to you from our industry.
• We will fund the construction or upgrading of regional industrial waste treatment and disposal facilities with adequate capacity to process safely all of the solid and liquid wastes we produce. We will not truck our wastes to other states.
2. We will be transparent about our entire plan for development:
• We will tell you as soon as practicable, but no later than 1 year before start of activity, where and when we will drill, and what pipelines and compressor stations will be needed where and by when.
• We will publish gas and waste production figures from every well, accurately, and on time.
• We will tell you where your gas is going to market, and not sell your gas to foreign markets.
• We will disclose, completely, all chemicals and other substances we use.
3. We will accept, without debate, all new regulations that might be proposed by your regulatory agencies: your existing regulations are inadequate to cover the new technologies and cumulative impact of HVSHF. We will offer your agencies suggestions for continuous evolution of the regulations as a result of lessons we are learning.
4. With respect to your natural environmentlegacy:
• For every treewe uproot, we will plant at least 1 replacement. We will reforestall access roads as quickly as we can, and minimize the width of all forest cuts.
• We will pay a fair price for the water we extract from your lakes and rivers, which will average several million gallons per gas well. Whatever we break, despoil, or pollute, we will repair, replace, or remediate, at our expense.
5. We will safely dispose of all liquid and solid wastes from our development:
• We will never store any flowback fluids or produced water in open pits. All such fluids will be recycled to the highest extent possible by existing technologies, regardless of increase in cost to us.
• All liquid and solid wastes remaining from recycling will be treated at the above-mentioned industrial waste treatment plants.
• We will provide radiation monitoring equipment on every well pad: any materials, including drill cuttings, leaving a well pad that trigger an alarm will be sent to a licensed radioactive waste disposal facility.
6. We will not cause an increase in the tax levy on your citizens.
• We will agree to a substantial increase in permit fees to reflect the expected 4-fold increase in person-time we expect you to spend on review of permits for HVSHF.
• We will agree to a state severance tax, the level of which will be floating, according to an accurate accounting of all costs to the state and municipalities.
7. We will practice what we preach about clean fuels and emissions:
• Every truck, every generator, every pump, every compressor will run on natural gas — no diesel, no gasoline engines.
• We will not allowuncaptured gaseous emissions from any of our processes: no evaporation from open pits, no pressure releases from compressor stations or condensate tanks.
8. We will be sensitive to noise and light pollution, even if a community does not have zoning restrictions in place to regulate such:
• All of our pads and compressor stations will have sound/light suppression measures in place before startup.
• Site drill pads, compressor stations, and pipelines in collaboration with the community.
9. We will not unduly stress any of your communities:
• We will never experiment with drilling many wells in a small area over a brief period of time.
• We will abide by all area and time restrictions on permitting.
• We will never contest loss of water use by any citizen. If a well is lost, we will replace it with whatever type of supply is requested by its owner at our expense.
• We will never require a citizen harmed by our development to promise silence in return for remediation.
Finally, and humbly, we note that even our best plans and efforts will come up short, sometime, someplace, somehow. Therefore, in addition to all the contributions noted above, we also pledge to establish an escrow account which will receive 1% of the value of all gas produced from shale gas wells using HVSHF each year. This account will be administered by an independent third party, advised by an independent panel you select, and will be used as an emergency fund to compensate those financially or physically harmed by our development in your state.
Yours truly,


Source: Carl Arnold

Wednesday, August 24, 2011

LPG (Liquefied Petroleum Gas) Fracturing Process - Alternative to Frac-Fluid?

Source: Gasfrac Energy Services


GASFRAC Energy Services Inc’s. proprietary LPG (Liquefied Petroleum Gas) Fracturing Process utilizes gelled LPG in place of conventional fracturing fluids. The unique properties of the LPG fracturing process result in significant savings on material expenses and fracture clean up, as well as increased well productivity.



The gelled LPG used in the fracturing process has the ability to both generate the necessary fracture system, carry the proppant through the wellbore and place into the oil and gas reservoir being stimulated.

The LPG used in the process is highly soluble in formation hydrocarbons. As a result, the LPG process results in less damage to formations than conventional hydraulic fracturing. And unlike conventional treatments where as much as 50% of the carrier remains in the reservoir and hinders well performance, virtually 100% of the LPG can be recovered.

Comparison of Conventional and GASFRAC’s LPG Fracturing Process


If video does not appear click HERE to view

Conventional Fracturing Process GASFRAC's LPG Fracturing Process







 







Is this a viable solution to pollution? Or is the only viable solution to ban hrydraulic fracturing altogether?  We feel a ban is in order and considerably past due. WTFrack.org



please comment


Monday, August 22, 2011

New Recommendations Issued in Hydraulic Fracturing Review - REVISIT

Hydraulic Fracturing Review
Source: DEC

  • In Reversal of 2009 Report, High-Volume Fracturing Would be Prohibited in NYC and Syracuse Watersheds
  • Drilling Banned Within All Primary Aquifers and on State-Owned Land Including State Forest and Wildlife Management Areas
  • Drilling Permitted on Other Private Land with Rigorous and Effective Protections
  • Advisory Panel on Implementation to Be Appointed
The Department of Environmental Conservation (DEC) tomorrow will release its revised recommendations on mitigating the environmental impacts of high-volume hydraulic fracturing (high-volume fracturing). The recommendations contain these major revisions:
  • High-volume fracturing would be prohibited in the New York City and Syracuse watersheds, including a buffer zone;
  • Drilling would be prohibited within primary aquifers and within 500 feet of their boundaries;
  • Surface drilling would be prohibited on state-owned land including parks, forest areas and wildlife management areas;
  • High-volume fracturing will be permitted on privately held lands under rigorous and effective controls; and
  • DEC will issue regulations to codify these recommendations into state law.
These recommendations, if adopted in final form, would protect the state's environmentally sensitive areas while realizing the economic development and energy benefits of the state's natural gas resources. Approximately 85 percent of the Marcellus Shale would be accessible to natural gas extraction under these recommendations.

DEC Commissioner Joseph Martens said, "This report strikes the right balance between protecting our environment, watersheds, and drinking water and promoting economic development."
The ban on high-volume fracturing in the New York City and Syracuse watersheds represents a reversal of the Department's 2009 draft report, which would have permitted drilling in those watersheds. The New York and Syracuse watersheds are unique in that they are the only unfiltered supplies of municipal water in the state and deserve special protection. The prior report also would have allowed high-volume fracturing surface drilling in primary aquifers and on public forests, wildlife areas and parkland; the 2011 report reverses all of these recommendations.

There will be more opportunity for review and comment on the Department's recommendations. DEC plans for a 60-day public comment period commencing in August. There is no administrative or discretionary moratorium on high-volume fracturing. By law, no permits may be issued until the public comments are reviewed and considered and the final Supplement Generic Environmental Impact Statement is released.

DEC enforcement and oversight of high-volume fracturing will be rigorous and effective. No permits will be issued until DEC has the proper enforcement capacity in place to monitor all fracturing activities.

In preparing the new recommendations, DEC engaged independent consultants to perform research, sought further information from the gas drilling industry, considered more than 13,000 public comments and studied other states' regulations and experience, including site visits by Commissioner Martens and DEC officials to Pennsylvania incident sites. Since September 2009, DEC staff has spent approximately 10,250 hours updating the document. The 2011 version contains more than 900 pages, including more than 150 additional pages of data and analysis compared to the 2009 version.

The Department's extensive review has resulted in recommendations for rigorous and effective controls on high-volume fracturing on private lands. These state-of-the-art controls include such permitting rules as:

Protecting Drinking Water

  • Well water protection and other water protection: No permits would be issued for sites within 500 feet of a private water well or domestic use spring. No permits may be issued for a proposed site within 2,000 feet of a public drinking water supply well or reservoir at least until three years of experience elsewhere have been evaluated. No permits will be issued for well pads sited within a 100-year floodplain.
  • Additional Well Casing to Prevent Gas Migration: In most cases, an additional third, cemented well casing is required around each well to prevent the migration of gas. The three required casings are the surface casing, the new intermediate casing and the production casing. The depths of both surface and intermediate casings will be determined by site-specific conditions.
  • Spill control: All new guidelines will require that flowback water on site must use watertight tanks within a secondary containment. No open containment may be used. A secondary containment will also be required for all fracturing additive containers, additive staging areas and flowback tanks to ensure any spills of wastewater or chemicals at the well pad do not migrate into water supplies.
  • Stormwater Control: New permit process requiring strict stormwater control measures to prevent stormwater from contaminating water resources.
  • Regulating Water Withdrawals:
    • New Legislation: Pursuant to the Governor's signing of DEC's Water Withdrawal legislation, which the State Legislature recently passed, a special permit will be required to withdraw large volumes of water for industrial and commercial purposes to ensure there are not adverse impacts.
    • Permit Condition: All withdrawals from surface water bodies will be subject to limits to prevent impacts upon ecosystems and other water quantity requirements. Identification of the water source an applicant intends to use will be required and an annual report must be issued on the aggregate amount of water it has withdrawn or purchased.

Properly Handling Flowback Water:

Since the 2009 SGEIS, many drilling companies have started to recycle much of the flowback water, greatly reducing the need for disposal.
  • Flowback Water Disposal: Applicants must have DEC-approved plans for disposing of flowback water and production brine.
  • Drilling & Production Waste Tracking: DEC would institute a process to monitor disposal of flowback water, production brine, drill cuttings and other drilling waste streams that is similar to the handling of medical waste.
  • Water Treatment Facilities: Requires full analysis and approvals under existing state and federal water laws and regulations, which must be completed before a water treatment facility could accept flowback water. This would include a treatment capacity analysis for any publicly operated treatment works facility (POTW) and a contingency plan if the primary disposal for wastewater is a POTW.

Taking Local Governments & Communities into Account:

  • Local Government Notification: DEC would notify local governments of each well permit application for high-volume fracturing.
  • Local Land Use & Zoning: Applicant must certify that a proposed activity is consistent with local land use and zoning laws. Failure to certify or a challenge by a locality would trigger additional DEC review before a permit could be issued.

Identifying Fracturing Fluid Chemicals:

  • Chemical Identification: The 2011 SGEIS identifies 322 chemicals proposed for use in New York and includes health hazard information for each as identified by the NYS Department of Health. Applicants must fully disclose to DEC all products utilized in the high-volume fracturing process. In addition, applicants must agree to publicly disclose the names of the additives, subject to appropriate protections for proprietary information.
  • Chemical Alternatives: Operators will be required to evaluate using alternative additives that pose less potential risk.

Protecting the Air:

  • Air Quality: Requires enhanced air pollution controls on engines used at well pads. DEC will monitor local and regional air quality at well pads and surrounding areas.
  • Greenhouse Gas Impact: Requires use of existing pipelines when available rather than flaring gas.

Conserving Habitats:

  • Private Forestland: Disturbing the surface of the land is strictly restricted in forests of 150 acres or more by requiring applicants to comply with best management practices.
  • Private Grasslands: Disturbing the surface of the land is strictly restricted in grasslands of 30 acres or more by requiring applicants to comply with best management practices.

Making Sure We Get It Right - Community Impacts Still Under Study:

The 2009 SGEIS did not adequately consider the community and socioeconomic impacts of high-volume fracturing. To address this deficiency, DEC has engaged independent consultants to thoroughly research these types of effects.
Specifically, researchers are examining both baseline data and the potential effects of development in the areas of:
  • Socioeconomic conditions including positive and negative impacts;
  • Transportation infrastructure, current road use and the impacts of increased traffic; and
  • Visual and noise impacts.
DEC expects the research to be completed by July 31, 2011. This research will be considered and reflected in the final draft of the report.

Appointment of Advisory Panel to Develop Implementation Plan:

Upon final adoption of the permitting standards, the Department will implement a system of oversight, monitoring and enforcement. The successful implementation of high-volume fracturing policy will also require close consultation with local governments and communities.
Commissioner Martens will announce the formation of the High-Volume Hydraulic Fracturing Advisory Panel, which will be composed of outside environmental and industry experts, and local government representatives. The Panel will be charged with developing recommendations for:

  • funding to ensure the proper oversight, monitoring and enforcement of mitigation measures, including both state and county agencies responsible for drilling activities and reviewing water sampling data;
  • measures to minimize socioeconomic and other impacts on local governments and communities;
  • a fee structure for drilling development; and
  • a mechanism for the funding of infrastructure improvements

please comment


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Tuesday, February 8, 2011

Gas Drilling-The Fracking Truth

Tuesday, February 08, 2011

Hydro-fracture expert, Prof. Anthony R. Ingraffea, Ph.D., P.E., Cornell University, N.Y. provides myth-breaking info on gas industry environmental impacts:
Gas Industry myths:

1. Hydro-fracturing is so deep in the ground that it does not effect the surface waters or grounds. This is the "science" that the Halliburton Loop-Hole Law, exempting the hydro-fracture technologies from regulation under the EPA's "Clean Air Act", "The Clean Water Act" and "The Public Disclosure Act", is based on.

The fracking truth is the EPA has had to remove these initial studies from its website due to "be-bunking" by numerous true non-Dick-Cheney-Pres. George Bush-Halliburton-influenced scientific studies since the law was passed. The current EPA "restudy" attempts are not needed. The evidence already exists. The EPA is carrying out an industry bribed delaying action with its current re-study of hydro-fracture technologies, so that the gas industry can freely "deflower" the Marcellus shale gas without regulation. The residents that live in Dimock,PA and other contaminated Marcellus and other shale gas drilling areas are the victims of unlimited corporate campaign contributions to our state and national lawmakers, BRIBERY!

This will not bring our contaminated ground water back!

2. Only 4.1 million gallons of water is used to frack a well.

3. Only 10% of that fracking fluid used for hydro-fracking a gas well returns to the surface as "flowback" water.

THE FRACKING TRUTH ANSWER to parts 2 to 3:

Gas Well Rig Stage 1., the drilling of the vertical and horizontal wellbore segments, uses millions of gallons of "drilling mud", containing shale formation NORM, heavy metals and gases, which are "dewatered" and stored/buried on site and/or transported for landfill disposal. It contains shale formation compounds that may include NORM, heavy metals and methane gas, which are normally considered as hazardous waste water, but in the gas industry's case is only categorized as common waste water. Legally none of these types of waste waters could be disposed at an ordinary landfill, but are anyway!

Stage 2. Each gas well uses 4.1 to 7.8 million gallons of water for the fracking stage, a pressurized mix of secret chemicals/silica sand/water is injected into the shale fissures to produce shale gas. "Flowback" water is the name the industry uses for surface-returned fracture water and shale formation compounds during the 2nd stage of gas well technology called the shale fracturing stage. Industry constantly states only 10% of flowback fracture water returns to the surface.

However, during the 3rd "gas well production stage", the rig operator declares the rig is producing gas. The remaining 90% of the fracture/formation water, renamed "produced" water or "formation" water does indeed return to the surface; pushed by the pressure of the fracking fluids and the newly released gases.

NOTE: The average Marcellus well site/pad contains 6 to 12 wells.

Stage 1. uses millions of gallons of drilling "mud" per well.

Stage 2. uses 4.1 to 7.8 million gallons for fracking each well.

Stage 3. has "produced" fracture water with brine containing concentrated amounts of dissolved solids of shale formation NORM (naturally occurring radioactive materials), heavy metals and/or radon gas, methane gas, and VOCs from diesel gas commonly used for fracking. . Only 85 to 93% of any of these natural gases are captured for natural gas production.

Stage 4. Gas Processing: The other remaining 7 to 15% of those natural gases are released into the air contaminating the areas around these wells, down wind and wherever this remaining gas is processed out of these fluids and solids at gas processing centers and gas pipe line re pressurizing stations all over the nation.

NOTE: Only 2 of the 78 gas companies in the U.S. are attempting to recycle these toxic fluids. Most of these fluids can not technically be recycled due to desired changes in viscosity levels of these "muds, "flowback", produced" and "formation" fluids at different stages of the drilling and/or fracking process..

full PDF document link below:

http://www.garyabraham.com/files/gas_drilling/NEWSNY_in_Chemung/Ingraffea_ltr._and_cv_5-17-10.pdf

Excerpt below:

"...Depending on the total length of the wellbore and the geology, tens of thousands of gallons of drilling mud are typically required for a Marcellus horizontal and fracked well. This mud is continuously circulated from the surface, down the well string to the drill bit, and back to the surface. When it returns to the surface, some process must be used to remove the drill cuttings, so that the remainder of the mud can be reused. This process is called "dewatering". In Pennsylvania, active dewatering processes are applied to the collected used mud, and the dewatered waste is buried on site or transported off site to a disposal facility.
During this first stage,...

...The second stage of Marcellus shale gas extraction involves Hydraulic Fracture Stimulation ("fracking"), a prcess designed to increase the effective permeability of the target formation by fracturing it and/or opening its natural joints using fluid pressure. During the fracking action, fracturing fluid, a mixture of water, proppant (typically silica sand), and proprietary chemicals are forced down the production casing under high pressure. The purpose of fracturing the shale is this way is to provide an incompressible medium to transmit pressure from the wellhead to the target formation, thereby causing fractures and/or opening

existing joints in the formation. The various additives provide fracture opening control, viscosity control, lubrication, corrision control, bacterial growth control, wellbore and perforation cleanout. Depending on total fracture interval, Chesapeake (CHK) reports an average of 5.5 million gallons of fracturing fluid are used per well in their Pennsylvania operations. During this stage and, after the fracking action, flowback fluid comes back up the casing to the surface. Fluid from flowback operation is a mixture of fracturing fluid and brine (1), and various solids released from the Marcellus formation during the perforating, fracking, and flowback operations, including NORM. The volume of flowback fluid returned to the surface varies with well and length of time before the production stage. Industry sources state that 10 to 100% of fracturing fluid is returned in the first 30 days, but some of this is formation (extant) brine and its transported materials....

...(1) Brine occurs naturally in and around the marcellus shale formations, owning to its origins in an ocean environment. Fracking the formation forces brine into the shale fractures, allowing the brine to leach naturally occurring soluble radionuclides and heavy metals out of the shale, where they become concentrated in the brine.", Anthony R. Ingraffea, Ph.D., P.E. Cornell University and Hydro-fracture expert

Link to one of Prof. Ingraffea's Marcellus gas shale three part online lectures:

http://essentialdissent.blogspot.com/2010/03/marcellus-gas-shale-play-information.html

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