Keystone Secrets: Records Show Widespread Use of Secret Fracking Chemicals is a Looming Risk for Delaware River Basin, Pennsylvania Communities
A report released today by the Partnership for Policy Integrity (PFPI) found that between 2013 and 2017, drilling companies injected at least one hydraulic fracturing (“fracking”) chemical with an identity kept hidden from the public into more than 2,500 unconventional natural gas wells drilled in Pennsylvania. The report, KeyStone Secrets, found companies injected secret fracking chemicals 13,632 times into 2,515 wells in total (explore map below).
Fracking in unconventional formations has significantly increased oil and gas extraction, making Pennsylvania the nation’s second-largest natural gas producer. The process has also sparked concerns about pollution and health effects, especially related to unidentified fracking chemicals. In response, Pennsylvania and 28 other states have enacted rules that require some public disclosure of these chemicals. However, most if not all of these rules have exceptions that allow companies to withhold chemical identities as trade secrets.
This report by Massachusetts-based Partnership for Policy Integrity (PFPI), with analysis of fracking chemical disclosure data by FracTracker Alliance, illustrates that drilling companies have used these exceptions extensively.
Records obtained by PFPI from the US Environmental Protection Agency (EPA) show that non-disclosure of fracking chemical identities may leave people unknowingly exposed to harmful substances. Between 2003 and 2014, the EPA identified health concerns for 109 of 126 new chemicals proposed for use in oil and gas drilling and fracking. The manufacturers submitted information about the chemicals for review under a program that requires EPA to screen and regulate new chemicals for health and environmental impacts before they are used commercially.
Despite concerns by EPA scientists about the chemicals’ health effects, EPA approved most of the 109 chemicals for use, and 62 were later used in or likely used in oil and gas wells. Manufacturers took advantage of trade secret protections that are permitted by federal law to conceal 41 of the 62 chemicals’ identities. It is possible that some of these chemicals declared secret at the federal level are some of the same chemicals being used under trade secret protection in Pennsylvania.
Mapping of secret fracking chemical injection sites (above) show that use is heaviest in southwest Pennsylvania near Pittsburgh and in northeast Pennsylvania near the Delaware River Basin, tracking areas of intensive drilling.
The use of secret chemicals in Pennsylvania’s oil and gas wells is likely even higher than detailed in this report because of exemptions in Pennsylvania law, including:
No disclosure requirements for the chemicals used in drilling oil and gas wells – the portion of the oil and gas extraction process that precedes fracking;
No requirement that fracking chemicals for so-called “conventional” oil and gas wells be reported to an easily searchable electronic database; and
A reporting exemption for chemical manufacturers who are not required to disclose trade secret chemical identities even to emergency responders cleaning up a leak or spill.
In the coming months, the Delaware River Basin Commission is expected to consider a ban on fracking in the basin – fracking that would be most likely to occur in unconventional gas wells in Pennsylvania’s portion of the four-state area. There is currently a de facto moratorium on fracking in the basin that provides drinking water for New York City and Philadelphia – among other cities. The commission is also expected to consider whether to allow related activities inside the basin, including the treatment and discharge into waterways of fracking wastewater from outside the basin. Any fracking or discharges of wastewater would be likely to include some of the secret fracking chemicals discussed in this report.
People have a right to know the identities of chemicals used in oil and gas operations so that citizens, first responders, regulators, and scientists can determine the chemicals’ risks and act to protect health and the environment. Learn more about the proprietary fracking chemicals used in PA by reading the full report:
Report Author: Dusty Horwitt, Partnership for Policy Integrity
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2018/09/SecretChemicalsReport-Rig-Feature.jpg400900FracTracker Alliancehttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngFracTracker Alliance2018-09-11 06:00:092019-09-10 16:52:51New report finds widespread use of proprietary fracking chemicals in PA
The below industry quote divides the world into two camps when it comes to horizontal hydraulic fracturing: those who are for it and those who are against it:
Fracking has emerged as a contentious issue in many communities, and it is important to note that there are only two sides in the debate: those who want our oil and natural resources developed in a safe and responsible way; and those who don’t want our oil and natural gas resources developed at all. – Energy from Shale (an industry-supported public relations website)
The writer imagines a world in black and white – with a clear demarcation line. In reality, it is not so simple, at least not when talking to the people who actually live in the Ohio towns where fracking is happening. They want the jobs that industry promises, but they worry about the rising costs of housing, food, and fuel that accompany a boomtown economy. They want energy independence, but worry about water contamination. They welcome the opening of new businesses, but lament the constant rumble of semi-trucks down their country roads. They are eager for economic progress, but do not understand why the industry will not hire more locals to do the work.
In short, the situation is complicated and it calls for a comprehensive response from Ohio’s local and state policy makers.
Through hefty campaign contributions and donations to higher learning institutions, the oil and gas industry exerts undue influence on Ohio’s politics and academic institutions. Many media outlets covering the drilling boom also have ties to the industry. Therefore, industry has been able to control the message and the medium. Those who oppose oil and gas in any way are painted as radicals. Indeed, some of Ohio’s most dedicated anti-fracking activists are unwavering in their approach. But most of the people living atop the Utica Shale simply want to live peacefully. Many would be willing to co-exist with the industry if their needs, concerns, and voices were heard.
This project attempts to give these Ohioans a voice and outsiders a more accurate representation about life in the Utica Shale Basin. The report does not engage in the debate about whether or not fracking should occur – but, rather, examines the situation as we currently find it.
Listening Project Summary
The Ohio Shale Country Listening Project is a collaborative effort to solicit, summarize, and share the perspectives and observations of those directly experiencing the shale gas boom in eastern Ohio. The project is led by the Ohio Organizing Collaborative (OOC)’s Communities United for Responsible Energy (CURE), with support from the Ohio Environmental Council (OEC), FracTracker Alliance, and the Laborers Local 809 of Steubenville. Policy Matters Ohio and Fair Shake Environmental Legal Services offered resources and time in drafting the final policy recommendations.
Over the course of six months, organizers from the Laborers Local 809 and OOC worked with a team of nearly 40 volunteers to survey 773 people living in the heart of Utica Shale country. Respondents are from eastern Ohio, ranging from as far north as Portage County to as far south as Monroe County. A small number of respondents hail from across the border in West Virginia and Pennsylvania, but the overwhelming majority are from Carroll (321), Columbiana (230), Jefferson (70), Harrison (30) and Belmont (28) counties.
Respondents were asked to talk about their family and personal history in the community where they live, their favorite things about their community and what changes they have noticed since the arrival of shale gas drilling using horizontal hydraulic fracturing or fracking. They were also asked to describe their feelings about oil and gas development as either positive or negative and what they believed their community would be like once the boom ends. Finally, respondents were also asked how concerned or excited they are about 11 possible outcomes or consequences of fracking.
Summary of Recommendations
Create incentives for companies to hire local workers; and increase transparency about who drilling and subcontracting companies are employing
Tax the oil and gas industry fairly with a severance tax rate of at least 5%; use this revenue to support affected communities to mitigate the effects of the boom and bust cycle
Increase the citizen participation in county decision-making on how additional sales tax or severance tax revenue is spent and how the county deals with the effects of the drilling boom
Increase transparency around production and royalties for landowners and the public
Set aside funding at the local level for air and water monitoring programs
Mitigate noise and emissions as much as possible with mandatory sound barriers and green completion on all fracking wells
Create mechanisms to protect sensitive areas from industry activity
Levy municipal impact fees to address issues associated with drilling
Better protect landowners during leasing negotiation process and from potential loss of income due to property damage
Conclusion
The more shale gas wells a community has, the less popular the oil and gas industry appears to be. Carroll County is the most heavily drilled county in Ohio, and more than half the respondents said they view the drilling boom negatively. Moreover, many residents say they are not experiencing the economic benefits promised by the oil and gas industry. They see rent, cost of gas, and groceries rising as the drilling and pipeline companies hire workers from out of state and sometimes even out of the country. Residents see more sales tax revenue coming into their counties but also see their roads destroyed by large trucks. They say they are experiencing more traffic delays and accidents than ever before. Ohioans love their community’s pastoral nature but are watching as the landscape and cropland get destroyed. As it is playing out now, the boom in shale gas drilling is not fulfilling the promises made by industry. Locals feel less secure and more financially strapped. Many feel their towns will soon be uninhabitable. It is up to state and local governments to hold industry accountable and make it pay for the impacts it creates.
The Ohio Shale Country Listening Project started in February 2014 with a conversation between Ohio Organizing Collaborative (OOC) staff and a veteran organizer who once worked on mountain top removal in a large region of West Virginia. The OOC organizer lamented the difficulty of organizing across a large geography around a specific issue – in this case, fracking. How do you find out what the people want without dictating to the community? The more experienced organizer immediately responded: What about a listening project? She connected OOC to the Shalefield Organizing Project in Pennsylvania whose organizers helped OOC think through what a listening project might look like in Ohio.
The project took on several iterations. First, OOC planned to focus the listening project solely on Columbiana County, which at the time was the third most fracked county in Ohio. Next, community leaders in Carroll County, the most heavily drilled county in the state, suggested the project also focus there. Eventually, as it became clear that the shale play was moving further south in Ohio, the project expanded into other counties such as Belmont, Harrison, and Jefferson. While attending a public hearing on pipeline construction in Portage County, OOC staff met an organizer from the Laborers Local 809 out of Steubenville. The organizer expressed interest in joining the project. Meanwhile, OOC had been in discussions with the Ohio Environmental Coalition (OEC) about the need to share the stories of people living in the middle of a fracking boom. OEC agreed to join the project. Finally, FracTracker also came into the fold, eager to assist in analyzing and mapping data gathered during the effort.
A listening project volunteer surveys a shopper at Rogers Open Air Market
OOC staff solicited the help from about 40 volunteers to form the “Listening Project Team” who surveyed their friends, family, coworkers, and neighbors. Volunteers met four times over the course of six months to discuss the project and strategize about how to reach more people with the survey. Most of the volunteer team came from Columbiana and Carroll Counties. The Laborers Local 809 also distributed the surveys to their members. Members of the team canvassed neighborhoods, attended local festivals, set up a booth at Rogers Open Air Market (photo left) and distributed an online version of the survey through Facebook and email. OOC staff spoke at college classes at Kent State-Salem and Kent State-East Liverpool, and solicited input from students in attendance.
The project’s initial goal was to hit a target of 1,000 – 1,500 survey responses. In the end the team fell short of this number, but were able to reach 773 people living in the Utica Shale area. This barrier is mostly due to the rural nature of the communities surveyed, which makes it more difficult to reach a large number of people in a short timeframe. The most responses came from Carroll County – 321 surveys. Columbiana County represented the second largest group of respondents with 230 surveys. Seventy people from Jefferson County, 30 people from Harrison County, 28 from Belmont County filled out the survey. The final 80 responses came from Mahoning, Stark, Summit and Tuscarawas Counties. Finally, nearly fifty responses came from Pennsylvania and West Virginia residents who live along the Ohio border (see Figure right). We promised survey respondents that all names and information would be kept confidential with survey responses presented only in aggregate.
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/01/Listening-Feature-1.jpg400900Ted Auch, PhDhttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngTed Auch, PhD2016-01-08 12:01:222019-09-10 16:53:48Ohio Shale Country Listening Project Part 1
Waste disposal is an issue that causes quite a bit of consternation even amongst those that are pro-fracking. The disposal of fracking waste into injection wells has exposed many “hidden geologic faults” across the US as a result of induced seismicity, and it has been linked recently with increases in earthquake activity in states like Arkansas, Kansas, Texas, and Ohio. Here in OH there is growing evidence – from Ashtabula to Washington counties – that injection well volumes and quarterly rates of change are related to upticks in seismic activity.
Origins of Fracking Waste
Furthermore, as part of this analysis we wanted to understand the ratio of Ohio’s Class II waste that has come from within Ohio and the proportion of waste originating from neighboring states such as West Virginia and Pennsylvania. Out of 960 Utica laterals and 245+ Class II wells, the results speak to the fact that a preponderance of the waste is coming from outside Ohio with out-of-state shale development accounting for ≈90% of the state’s hydraulic fracturing brine stream to-date. However, more recently the tables have turned with in-state waste increasing by 4,202 barrels per quarter per well (BPQPW). Out-of-state waste is only increasing by 1,112 BPQPW. Such a change stands in sharp contrast to our August 2013 analysis that spoke to 471 and 723 BPQPW rates of change for In- and Out-Of-State, respectively.
Brine Production
Figure 1. Ohio Class II Injection Well trends In- and Out-Of-State, Cumulatively, and on Per Well basis (n = 248).
For every gallon of freshwater used in the fracking process here in Ohio the industry is generating .03 gallons of brine (On average, Ohio’s 758 Utica wells use 6.88 million gallons of freshwater and produce 225,883 gallons of brine per well).
Back in August of 2013 the rate at which brine volumes were increasing was approaching 150,000 BPQPW (Learn more, Fig 5), however, that number has nearly doubled to +279,586 BPQPW (Note: 1 barrel of brine equals 32-42 gallons). Furthermore, Ohio’s Class II Injection wells are averaging 37,301 BPQPW (1.6 MGs) per quarter over the last year vs. 12,926 barrels BPQPW – all of this between the initiation of frack waste injection in 2010 and our last analysis up to and including Q2-2013. Finally, between Q3-2010 and Q1-2015 the exponential increase in injection activity has resulted in a total of 81.7 million barrels (2.6-3.4 billion gallons) of waste disposed of here in Ohio. From a dollars and cents perspective this waste has generated $2.5 million in revenue for the state or 00.01% of the average state budget (Note: 2.5% of ODNR’s annual budget).
Freshwater Demand Growing
Figure 2. Ohio Class II Injection Well disposal as a function of freshwater demand by the shale industry in Ohio between Q3-2010 and Q1-2015.
The relationship between brine (waste) produced and freshwater needed by the hydraulic fracturing industry is an interesting one; average freshwater demand during the fracking process accounts for 87% of the trend in brine disposal here in Ohio (Fig. 2). The more water used, the more waste produced. Additionally, the demand for OH freshwater is growing to the tune of 405-410,000 gallons PQPW, which means brine production is growing by roughly 12,000 gallons PQPW. This says nothing for the 450,000 gallons of freshwater PQPW increase in West Virginia and their likely demand for injection sites that can accommodate their 13,500 gallons PQPW increase.
Where will all this waste go? I’ll give you two guesses, and the first one doesn’t count given that in the last month the ODNR has issued 7 new injection well permits with 9 pending according to the Center For Health and Environmental Justice’s Teresa Mills.
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2015/07/Injection-Feature.jpg400900Ted Auch, PhDhttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngTed Auch, PhD2015-07-09 14:54:002015-07-09 15:12:08OH Class II Injection Wells – Waste Disposal and Industry Water Demand
On December 17, 2014 Governor Cuomo, as well as DEC and DOH Commissioners, said no to fracking in the state of New York.
By Karen Edelstein, NY Program Coordinator, FracTracker Alliance
On Wednesday, December 17, 2014, at an end-of-the-year televised Cabinet Meeting in Albany, New York State Governor Andrew Cuomo, Health Commissioner Howard A. Zucker, and Department of Environmental Conservation Commissioner Joe Martens informed New Yorkers about their decision not to allow high volume hydraulic fracturing in New York State “at this time.
Governor Cuomo instructed Commissioner Martens to complete the Supplemental Generic Environmental Impact Statement (SGEIS) in early 2015, and after additional public comment, the law should go into effect. The New York State Health Commissioner’s report “A Public Health Review of High Volume Hydraulic Fracturing for Shale Gas Development” can be found here.
Watch the history-making statements from Cuomo, Martens, and Zucker in the video below. Cuomo’s comments start 15 seconds into the clip. At about 57:00, hear how FracTracker’s map of bans and moratoria in NY State played a part in cementing Marten’s decision.
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2014/12/NYBansFracking.png400900Karen Edelsteinhttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngKaren Edelstein2014-12-22 11:33:302014-12-22 11:42:35New York State Will Not Permit Fracking
New Report from FracTracker and the Natural Resources Defense Council By Kyle Ferrar, CA Program Coordinator, FracTracker Alliance
The FracTracker Alliance recently contributed to a report released by the Natural Resources Defense Council (NRDC), titled Drilling in California: Who’s at Risk?. In the report, we find that many communities disproportionally burdened by environmental and public health degradation also live in the areas most impacted by oil and gas (O&G) development, including hydraulic fracturing and acidizing. Additionally, the communities most impacted by such oil and gas activity are disproportionately non-white. Key points of the report are listed below, as outlined by the NRDC:
Key Points of “Drilling in California” Report
Expanding oil production in California, in areas already heavily drilled or in new areas, can threaten the health of communities.
New analysis shows that, already, approximately 5.4 million Californians live within a mile of one, or more, of the more than 84,000 existing oil and gas wells.
More than a third of the communities living with oil and gas wells are also burdened with the worst environmental pollution, as measured by CalEPA’s CalEnviroScreen 2.0. These communities, with heightened risks, are 92 percent people of color.
To prevent further environmental damage and public health threats, major improvements are required before hydraulic fracturing, acidizing, and other stimulation techniques are allowed to continue in California.
The analysis used the California Environmental Protection Agency (CalEPA) Office of Health Hazard and Assessment’s (OEHHA) impact screening tool CalEnviroScreen 2.0, which ranks all the census tracts in CA based on various indicators of environmental and public health degradation due to pollution sources. Stimulated and non-stimulated O&G well-site data came from multiple sources including the Division of Oil, Gas and Geothermal Resources; the South Coast Air Quality Management District; and FracFocus.
Visualizing the Data
The interactive web map below (Figure 1) provides a visual understanding of how these areas may be additionally burdened by California’s industrial oil and gas extraction activities. The CalEnviroscreen 2.0 dataset of census tract scores was mapped spatially to show the areas in CA disproportionately burdened by existing environmental stressors and health impacts. The locations of CA’s O&G production wells were overlaid on these maps since the CalEnviroscreen ranks did not specifically take into account the role of O&G extraction activity in communities. The top 20th percentile of total scores are shown in the map’s default view, and more CalEnviroscreen scores are displayable under the “Layers” tab (top right).
Figure 1. The top 20th percentile of highest CalEnviroscreen 2.0 total scores are shown in the map above along with well counts by census tract. Increasing well counts are portrayed with orange circles that increase in size with the number of wells. Click here to explore.
Figures 2-7 below are provide printable examples of several of CalEnviroscreen’s 2.0’s most important rankings when considering O&G extraction activity.
Figure 2. CalEnviroscreen 2.0 highest 20th percentile of census tracts with the most pollution burden from various sources in all of California. The census tract scores are overlaid with active oil and gas (O&G) wells.
Figure 3. Focus on the Greater Los Angeles Basin. Shows the CalEnviroscreen 2.0 highest 20th percentile of census tracts with the most pollution burden from various sources. Census tract scores are overlaid with active O&G wells. Many of the areas most impacted by existing pollution also host much of the O&G extraction activity.
Figure 4. Focus on Los Angeles County, with some of the highest ranking scores for Ozone pollution. These areas also host and are surrounded by many oil/gas wells.
Figure 5. Focus on the Greater Los Angeles Basin. Shows the CalEnviroscreen 2.0 highest 20th percentile of census tracts with the worst air quality impacts resulting from particulate matter (PM2.5) pollution. Census tract scores are overlaid with active O&G wells. Many of the areas most impacted by PM2.5 also host much of the O&G extraction activity.
Figure 6. Focus on Kern County in the Central San Joaquin Valley. Shows the CalEnviroscreen 2.0 highest 20th percentile of census tracts with the worst air quality impacts resulting from particulate matter (PM2.5) pollution. Census tract scores are overlaid with active oil and gas wells. Many of the areas most impacted by PM2.5 also host much of the O&G extraction activity.
Figure 7. Focuses on the areas of Kern County with the CalEnviroscreen 2.0 highest 20th percentile of census tracts with the worst air quality impacts resulting from ambient ozone pollution. Census tract scores are overlaid with active oil and gas wells. Many of the areas most impacted by ozone also host much of the O&G extraction activity.
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2014/10/NRDCFeature.png400900Kyle Ferrar, MPHhttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngKyle Ferrar, MPH2014-10-31 10:12:112014-12-04 14:35:00Disproportionate Drilling and Stimulations in California
Water Resource Reporting and Water Footprint from Marcellus Shale Development in West Virginia and Pennsylvania
Report and summary by Meghan Betcher and Evan Hansen, Downstream Strategies; and Dustin Mulvaney, San Jose State University
The use of hydraulic fracturing for natural gas extraction has greatly increased in recent years in the Marcellus Shale. Since the beginning of this shale gas boom, water resources have been a key concern; however, many questions have yet to be answered with a comprehensive analysis. Some of these questions include:
What are sources of water?
How much water is used?
What happens to this water following injection into wells?
With so many unanswered questions, we took on the task of using publically available data to perform a life cycle analysis of water used for hydraulic fracturing in West Virginia and Pennsylvania.
Summary of Findings
Some of our interesting findings are summarized below:
In West Virginia, approximately 5 million gallons of fluid are injected per fractured well, and in Pennsylvania approximately 4.3 million gallons of fluid are injected per fractured well.
Surface water taken directly from rivers and streams makes up over 80% of the water used in hydraulic fracturing in West Virginia, which is by far the largest source of water for operators. Because most water used in Marcellus operations is withdrawn from surface waters, withdrawals can result in dewatering and severe impacts on small streams and aquatic life.
Most of the water pumped underground—92% in West Virginia and 94% in Pennsylvania—remains there, lost from the hydrologic cycle.
Reused flowback fluid accounts for approximately 8% of water used in West Virginia wells.
Approximately one-third of waste generated in Pennsylvania is reused at other wells.
As Marcellus development has expanded, waste generation has increased. In Pennsylvania, operators reported a total of 613 million gallons of waste, which is approximately a 70% increase in waste generated between 2010 and 2011.
Currently, the three-state region—West Virginia, Pennsylvania, and Ohio—is tightly connected in terms of waste disposal. Almost one-half of flowback fluid recovered in West Virginia is transported out of state. Between 2010 and 2012, 22% of recovered flowback fluid from West Virginia was sent to Pennsylvania, primarily to be reused in other Marcellus operations, and 21% was sent to Ohio, primarily for disposal via underground injection control (UIC) wells. From 2009 through 2011, approximately 5% of total Pennsylvania Marcellus waste was sent to UIC wells in Ohio.
The blue water footprint for hydraulic fracturing represents the volume of water required to produce a given unit of energy—in this case one thousand cubic feet of gas. To produce one thousand cubic feet of gas, West Virginia wells require 1-3 million gallons of water and Pennsylvania wells required 3-4 million gallons of water.
Table 1. Reported water withdrawals for Marcellus wells in West Virginia (million gallons, % of total withdrawals, 2010-2012)
Source: WVDEP (2013a). Note: Surface water includes lakes, ponds, streams, and rivers. The dataset does not specify whether purchased water originates from surface or groundwater. As of August 14, 2013, the Frac Water Reporting Database did not contain any well sites with a withdrawal “begin date” later than October 17, 2012. Given that operators have one year to report to this database, the 2012 data are likely very incomplete.
As expected, we found that the volumes of water used to fracture Marcellus Shale gas wells are substantial, and the quantities of waste generated are significant. While a considerable amount of flowback fluid is now being reused and recycled, the data suggest that it displaces only a small percentage of freshwater withdrawals. West Virginia and Pennsylvania are generally water-rich states, but these findings indicate that extensive hydraulic fracturing operations could have significant impacts on water resources in more arid areas of the country.
While West Virginia and Pennsylvania have recently taken steps to improve data collection and reporting related to gas development, critical gaps persist that prevent researchers, policymakers, and the public from attaining a detailed picture of trends. Given this, it can be assumed that much more water is being withdrawn and more waste is being generated than is reported to state regulatory agencies.
Data Gaps Identified
We encountered numerous data gaps and challenges during our analysis:
All data are self-reported by well operators, and quality assurance and quality control measures by the regulatory agencies are not always thorough.
In West Virginia, operators are only required to report flowback fluid waste volumes. In Pennsylvania, operators are required to report all waste fluid that returns to the surface. Therefore in Pennsylvania, flowback fluid comprises only 38% of the total waste which means that in West Virginia, approximately 62% of their waste is not reported, leaving its fate a mystery.
The Pennsylvania waste disposal database indicates waste volumes that were reused, but it is not possible to determine exactly the origin of this reused fluid.
In West Virginia, withdrawal volumes are reported by well site rather than by the individual well, which makes tracking water from withdrawal location, to well, to waste disposal site very difficult.
Much of the data reported is not publically available in a format that allows researchers to search and compare results across the database. Many operators report injection volumes to FracFocus; however, searching in FracFocus is cumbersome – as it only allows a user to view records for one well at a time in PDF format. Completion reports, required by the Pennsylvania Department of Environmental Protection (PADEP), contain information on water withdrawals but are only available in hard copy at PADEP offices.
In short, the true scale of water impacts can still only be estimated. There needs to be considerable improvements in industry reporting, data collection and sharing, and regulatory enforcement to ensure the data are accurate. The challenge of appropriately handling a growing volume of waste to avoid environmental harm will continue to loom large unless such steps are taken.
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2014/04/GasWellWaterWithdrawals.png732975FracTracker Alliancehttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngFracTracker Alliance2014-04-04 09:31:062018-05-08 15:36:44Water Use in WV and PA
By Kyle Ferrar, CA Program Coordinator, FracTracker Alliance
In collaboration with the environmental advocacy groups Earthworks, Center for Biological Diversity, and Clean Water Action, The FracTracker Alliance has completed a proximity analysis of the locations of California’s Class II oil and gas wastewater injection wells to “recently” active fault zones in California. The results of the analysis can be found in the On Shaky Ground report, available for download at www.ShakyGround.org.1
Production of oil and natural gas results in a large and growing waste stream. Using current projections for oil development, the report projects a potential 9 trillion gallons of wastewater over the lifetime of the Monterey shale. In California the majority of wastewater is injected deep underground for disposal in wells deemed Class II wastewater injection. The connection between seismic activity and underground injections of fluid has been well established, but with the current surge of shale resource development the occurrence of earthquakes in typically seismically inactive regions has increased, including a recent event in Ohio covered by the LA Times. While both hydraulic fracturing and wastewater injection wells have been linked to the induction of seismic activity, the impacts of underground injection wells used for disposal are better documented and linked to larger magnitude earthquakes.
Therefore, while hydraulic fracturing of oil and gas wells has also been documented to induce seismic activity, the focus of this report is underground injection of waste fluids.
Active CA Faults
A spatial overview of the wastewater injection activity in California and recently active faults can be viewed in Figure 1, below.
Figure 1. California’s Faults and Wastewater Injection Wells. With this and all maps on this page, click on the arrows in the upper right hand corner of the map to view it fullscreen and to see the legend and more details.
The focus of the On Shaky Ground report outlines the relationship between does a thorough job reviewing the literature that shows how the underground injection of fluids induces seismic activity. The proximity analysis of wastewater injection wells, conducted by The FracTracker Alliance, provides insight into the spatial distribution of the injection wells. In addition, the report M7.8 earthquake along the San Andreas fault could cause 1,800 fatalities and nearly $213 billion in economic damages.2 To complement the report and provide further information on the potential impacts of earthquakes in California, FracTracker created the maps in Figure 2 and Figure 3.
Shaking Assessments
Figure 2 presents shaking amplification and shaking hazards assessments. The dataset is generated from seismic evaluations. When there is an earthquake, the ground will amplify the seismic activity in certain ways. The amount of amplification is typically dependent on distance to the earthquake event and the material that comprises the Earth’s crust. Softer materials, such as areas of San Francisco built on landfills, will typically shake more than areas comprised of bedrock at the surface. The type of shaking, whether it is low frequency or high frequency will also present varying hazards for different types of structures. Low frequency shaking is more hazardous to larger buildings and infrastructure, whereas high frequency events can be more damaging to smaller structure such as single family houses. Various assessments have been conducted throughout the state, the majority by the California Geological Survey and the United States Geological Survey.
Figure 2. California Earthquake Shaking Amplification and Class II Injection Wells
Landslide Hazards
Below, Figure 3. Southern California Landslide and Hazard Zones expands upon the map included in the On Shaky Ground report; during an earthquake liquefaction of soil and landslides represent some of the greatest hazards. Liquefaction refers to the solid earth becoming “liquid-like”, whereas water-saturated, unconsolidated sediments are transformed into a substance that acts like a liquid, often in an earthquake. By undermining the foundations of infrastructure and buildings, liquefaction can cause serious damage. The highest hazard areas shown by the liquefaction hazard maps are concentrated in regions of man-made landfill, especially fill that was placed many decades ago in areas that were once submerged bay floor. Such areas along the Bay margins are found in San Francisco, Oakland and Alameda Island, as well as other places around San Francisco Bay. Other potentially hazardous areas include those along some of the larger streams, which produce the loose young soils that are particularly susceptible to liquefaction. Liquefaction risks have been estimated by USGS and CGS specifically for the East Bay, multiple fault-slip scenarios for Santa Clara and for all the Bay Area in separate assessments. There are not regional liquefaction risk estimate maps available outside of the bay area, although the CGS has identified regions of liquefaction and landslide hazards zones for the metropolitan areas surrounding the Bay Area and Los Angeles. These maps outline the areas where liquefaction and landslides have occurred in the past and can be expected given a standard set of conservative assumptions, therefore there exist certain zoning codes and building requirements for infrastructure.
Figure 3. California Liquefaction/Landslide Hazards and Class II Injection Wells
Press Contacts
For more information about this report, please reach out to one of the following media contacts:
Arbelaez, J., Wolf, S., Grinberg, A. 2014. On Shaky Ground. Earthworks, Center for Biological Diversity, Clean Water Action. Available at ShakyGround.org
Jones, L.M. et al. 2008. The Shakeout Scenario. USGS Open File Report 2008-1150. U.S. Department of the Interior, U.S. Geological Survey.
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2014/03/shakyground-cover.jpg600464Kyle Ferrar, MPHhttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngKyle Ferrar, MPH2014-03-15 20:37:072014-12-04 14:23:48Class II Oil and Gas Wastewater Injection and Seismic Hazards in CA
By Ted Auch, PhD – OH Program Coordinator, FracTracker Alliance
With all the focus on the existing TransCanada Keystone XL pipeline – as well as the primary expansion proposal recently rejected by Lancaster County, NB Judge Stephanie Stacy and more recently the Canadian National Energy Board’s approval of Enbridge’s Line 9 pipeline – we thought it would be good to generate a map that displays related proposals in the US and Canada.
North American Proposed Pipelines and Current Pipelines
To view the fullscreen version of this map along with a legend and more details, click on the arrows in the upper right hand corner of the map.
The map was last updated in October 2014.
Pipeline Incidents
The frequency and intensity of proposals and/or expansions of existing pipelines has increased in recent years to accompany the expansion of the shale gas boom in the Great Plains, Midwest, and the Athabasca Tar Sands in Alberta. This expansion of existing pipeline infrastructure and increased transport volume pressures has resulted in significant leakages in places like Marshall, MI along the Kalamazoo River and Mayflower, AR. Additionally, the demand for pipelines is rapidly outstripping supply – as can be seen from recent political pressure and headline-grabbing rail explosions in Lac-Mégantic, QC, Casselton, ND, Demopolis, AL, and Philadelphia.1 According to rail transport consultant Anthony Hatch, “Quebec shocked the industry…the consequences of any accident are rising.” This sentiment is ubiquitous in the US and north of the border, especially in Quebec where the sites, sounds, and casualties of Lac-Mégantic will not soon be forgotten.
Improving Safety Through Transparency
It is imperative that we begin to make pipeline data available to all manner of parties ex ante for planning purposes. The only source of pipeline data historically has been the EIA’s Pipeline Network. However, the last significant update to this data was 7/28/2011 – meaning much of the recent activity has been undocumented and/or mapped in any meaningful way. The EIA (and others) claims national security is a primary reason for the lack of data updates, but it could be argued that citizens’ right-to-know with respect to pending proposals outweighs such concerns – at least at the county or community level. There is no doubt that pipelines are magnets for attention, stretching from the nefarious to the curious. Our interest lies in filling a crucial and much requested data gap.
Metadata
Pipelines in the map above range from the larger Keystone and Bluegrass across PA, OH, and KY to smaller ones like the Rex Energy Seneca Extension in Southeast Ohio or the Addison Natural Gas Project in Vermont. In total the pipeline proposals presented herein are equivalent to 46% of EIA’s 34,133 pipeline segment inventory (Table 1).
Table 1. Pipeline segments (#), min/max length, total length, and mean length (miles).
Section
#
Min
Max
Mean
Sum
Bakken
34
18
560
140
4,774
MW East-West
68
5
1,056
300
20,398
Midwest to OK/TX
13
13
1,346
307
3,997
Great Lakes
5
32
1,515
707
3,535
TransCanada
3
612
2,626
1,341
4,021
Liquids Ventures
2
433
590
512
1,023
Alliance et al
3
439
584
527
1,580
Rocky Express
2
247
2,124
1,186
2,371
Overland Pass
6
66
1,685
639
3,839
TX Eastern
15
53
1,755
397
5,958
Keystone Laterals
4
32
917
505
2,020
Gulf Stream
2
541
621
581
1,162
Arbuckle ECHO
25
27
668
217
5,427
Sterling
9
42
793
313
2,817
West TX Gateway
13
1
759
142
1,852
SXL in PA and NY
15
48
461
191
2,864
New England
70
2
855
65
4,581
Spectra BC
9
11
699
302
2,714
Alliance et al
4
69
4,358
2,186
4,358
MarkWest
63
2
113
19
1,196
Mackenzie
46
3
2,551
190
8,745
Total
411
128
1,268
512
89,232†
† This is equivalent to 46% of the current hydrocarbon pipeline inventory in the US across the EIA’s inventory of 34,133 pipeline segments with a total length of 195,990 miles
The map depicts all of the following (Note: Updated quarterly or when notified of proposals by concerned citizens):
We generated this map by importing JPEGs into ArcMAP 10.2, we then “Fit To Display”. Once this was accomplished we anchored the image (i.e., georeferenced) in place using a minimum of 10 control points (Note: All Root Mean Square (RMS) error reports are available upon request) and as many as 30-40. When JPEGs were overly distorted we then converted or sought out Portable Network Graphic (PNG) imagery to facilitate more accurate anchoring of imagery.
We will be updating this map periodically, and it should be noted that all layers are a priori aggregations of regional pipelines across the 4 categories above.
Ohio has seen its share of unconventional natural gas extraction in recent years. Now, the state is facing an influx of pipeline infrastructure to manage and distribute the extracted gas. In Portage County, OH, Mountaineer Keystone is of particular interest. FracTracker Alliance and Concerned Citizens Ohio have worked together to better understand the nature and extent of this activity.
Proposal Details
By Gwen Fischer and Trish Harness, Concerned Citizens Ohio, Portage County; Map by Ted Auch
Mt. Keystone will not invest in pipeline easements unless they believe their Return On Investment (ROI) will be great, so we expect them to drill intensively in the areas with many parcels leased and to link those parcels with pipelines wherever they have easements. They may also be seeking new pipeline easements.
Leases and easements are legal documents, and the details (how deep, placement, etc.) are critical to understanding what the industry is allowed to do on the land. Drilling companies don’t always go door to door to get a new lease. Door-to-door “landsmen” need only approach previously unleased properties. If the old lease was open-ended, a drilling company may be able to obtain a permit to drill a deeper well without negotiating new terms. If the lease was restrictive, the drilling company may need to negotiate to put a deep shale well pad or other “surface disturbance” changes not specified earlier. Without examining each lease individually, the map below cannot tell us what exactly is permitted, or where on the property. In addition, landowners should know that (depending on the terms of the lease) leases can be purchased without the owner’s knowledge. Thus, the owner may think they know the drilling company or the oil/gas production company they are dealing with, when in fact the ownership of the drilling or production well has changed.
Another item that the public should be aware of is that obtaining leases for mineral rights does not automatically grant rights for pipeline easements, but the leases could be written so as to allow for both drilling and pipelines.
The easements with Mt. Keystone are for water and waste flowback – but (given some pipeline easements we’ve seen with other companies) it is possible the pipelines could (will) be “re-purposed” for production from shale wells on the leased lands, once the wells are drilled. Even more open-ended options are possible.
About the Map
This map shows land parcels with publicly recorded mineral rights leases (for drilling) and Right of Way (ROW) easements for pipelines registered under Mountaineer Keystone’s name. No other company that might hold easements or leases is included. The map was created using public records, available on the Portage County Recorder’s and the Portage County Auditor’s websites. We utilized the raw and updated Portage County parcel shapefile and identified parcels using dummy variables with -1 identifying Mt. Keystone’s leases (825 parcels, 6,455 total acres, average 8 acres), 1 representing Mt. Keystone Right of Ways (ROWs) for pipelines (132 parcels, 2,837 total acres, average 22 acres), and 0 representing neither. Additionally, 14 of these parcels fall under those that have leases and ROWs (353 acres, average 25 acres)**.
Click on the arrows in the upper right hand corner of the map for the legend and to view the map fullscreen.
Well information comes from ODNR (Ohio Department of Natural Resources) data on their website . All of Portage county was checked for leases or easements, and this represents all of the townships and about half of the actual leases.
New mineral rights leases are parcels where a high volume, horizontal shale (HVHS) production well may be drilled, or the horizontal “laterals”may be drilled under the land. The three existing HVHS wells and their laterals are shown. ROW easements are for pipelines. A few parcels have both easements and leased mineral rights. Since permits for future wells have not yet been applied for, we cannot know exactly where on any parcel a well pad or the laterals will be drilled. Properties with leases for wells already drilled are included. Without examining individual easements, we cannot know exactly where on a parcel pipelines will be laid.
** Recently we added 103 parcels from Geauga County parcels that Mountaineer Keystone purchased from Excalibur Oil within the proposed ROW. These parcels total 1,843 acres with a range of 0.45 to 117 acres and a mean of 18 acres to date.
Our latest Ohio-focused map shows the many companies involved in directional drilling in the state and the contact information for these firms.
Layer Descriptions
1. UNIVERSAL WELL SERVICES
Universal Well Services Inc. is a major firm involved in all manner of directional drilling services with an office in Wooster, OH, one in Allen, KY, six in Pennsylvania, six in Texas, and one in West Virginia
2. LLC & MLP’s
This is an inventory of 410 Ohio directional drilling affiliated LLC and MLP firms and contact information. Seventy-eight percent of these firms are domiciled in Ohio. The other primary states that house these firms are Pennsylvania (22), Texas (23), and West Virginia (9). The Economist wrote of these types of firms:
The move away from the C corporation began in earnest in 1975. Wyoming, that vibrant business hub, adopted a new entity structure, the limited-liability company (LLC). Imported from Panama, it provided the tax treatment of a partnership while preserving the corporate protection from individual liability for company debts and litigation. Other states followed in adopting the model. Businesses were quick to see the advantages. The various new types of firm that have risen in the wake of the LLC… make similar use of partnership structures. They have tended to be industry- or sector-specific, at least to begin with. The energy business has a lot of MLPs not only because it needs capital but because it is an easy place to set them up: since 1987, tax law has allowed “mineral or natural resource” companies to operate as listed partnerships, while withholding that privilege from others. But as with other pass-through structures, the constraints are being lowered and circumvented.
3. DRILLING FIRMS
This is an inventory of 393 Ohio Department of Natural Resources permitted directional and injection drilling firms with single locations and their contact information. Seventy-six percent of these firms are domiciled in Ohio with the other primary states of incorporation being Pennsylvania (15), Texas (14), Michigan (11), and West Virginia (9). Only 3 of these firms listed in the Ohio RBDMS Microsoft Access Database contained correct contact information or addresses. According to ODNR staff – and primary FOIA contact:
… it looks like the [active drillers] list [doesn’t contain] much information on the companies in general…We have mailing information for the operating companies, but a lot of the time they subcontract out to get their drillers. We do not require the information of the drillers they contract.
4. ADDITIONAL DRILLERS
This is an inventory of the 40 known locations for six firms permitted to drill in Ohio. The same lack of contact and address data for these firms were true for this data. The primary firms are Butch’s Rathole and Nomac Drilling Corporation. Given that the ODNR RBDMS does not indicate the actual location from which these companies migrated into the Ohio shale industry we decided to include all known locations for these firms.
5. CANADIAN FIRMS
This is an inventory of the 14 known locations for the 5 Canadian drilling firms permitted in Ohio. The primary firm is Savannah Drilling, which is composed of 10 locations across Alberta and Saskatchewan.
6. AMERICAN SUPPORTING CO.
This is an inventory of 1,837 Ohio energy firms operating in the Utica and Marcellus shale or servicing it in a secondary or tertiary fashion. Seventy-five percent (1,386) of these firms are domiciled in Ohio with secondary hotspots in Texas (76), West Virginia (65), Pennsylvania (49), Michigan (34), Colorado (27), Illinois (22), Oklahoma (21), California (16), New York and New Jersey (27), Kentucky (14).
7. ADDITIONAL SUPPORTING CO.
This shows an inventory of 10 Ohio energy firms operating in the Utica and Marcellus shale or servicing it in a secondary or tertiary fashion extracted from the ODNR RBDMS that did not contain locational or contact information.
8. CANADIAN SUPPORTING CO.
This is an inventory of 5 (1 company Mar Oil Company was not found) Canadian energy firms operating in the Utica and Marcellus shale or servicing it in a secondary or tertiary fashion.
9. BRINE HAULERS
This is an inventory of 505 ODNR permitted brine haulers active in the transport and disposal of hydraulic fracturing waste either via injection or waste landfill disposal. Seventy-six percent of these firms are domiciled in Ohio with the primary cities being Zanesville (18), Cambridge, Wooster, and Millersburg (12 each), Canton and Marietta (11 each), Columbus (9), Jefferson (9), Logan (8), and North Canton and Newark (7 each). Pennsylvania and West Virginia are home to 84 and 32 brine haulers, respectively.
https://stg.fractracker.org/a5ej20sjfwe/wp-content/uploads/2014/02/Screen-Shot-2014-02-06-at-12.22.35-PM.png324696Ted Auch, PhDhttps://www.fractracker.org/a5ej20sjfwe/wp-content/uploads/2016/05/New-FT-Website-Logo.pngTed Auch, PhD2014-02-06 10:24:172017-10-25 12:04:05Ohio Production and Injection Well Firms Map
The use of hydraulic fracturing for natural gas extraction has greatly increased in recent years in the Marcellus Shale. Since the beginning of this shale gas boom, water resources have been a key concern; however, many questions have yet to be answered with a comprehensive analysis. Some of these questions include:
