Hydraulic fracturing has become increasingly popular in the United States during the last ten years. It is a process that is used for the majority of new oil and gas wells, and is used to access the abundance of natural gas in the US. The largest shale bed is the Marcellus Shale which spans the area underneath many states in the Northeast, primarily New York and Pennsylvania. Policy and science have failed to keep up with the boom in fracking that has occurred across the US, which has led the process to be regulated at varying levels of stringency and a lack of understanding of the potential risks associated with fracking. New York decided that the potential adverse effects of fracking outweighed the economic benefits of job creation and increased tax revenue. New York was the 2nd state in the US that banned fracking, and the decision can be attributed to the unique environmental and political factors present. There were six major environmental reasons that New York decided to ban fracking: decreased respiratory health, drinking water contamination, soil contamination, seismic activity, climate change, and boomtown economic effects. Drinking water contamination is especially important in New York because New York’s reservoirs provide water for over 17 million people. These six environmental factors are not unique to New York, but their impact would be more widely felt than in many other states where fracking occurs. The political factors in New York are also critical to understand. New York is a blue state that is being governed by Governor Cuomo who after his re-election desperately needed to re-align with the left wing of New York’s democratic party. The analysis completed in this paper demonstrates that New York is unique in many ways and the decision to ban hydraulic fracturing there may not be easily replicable in other states.

The town of Millerton, Pa., has always been a small, rural farming community. Settled atop of the famed Marcellus Shale in the foothills of the Appalachians, there have always been rumors of natural gas in the hills around town. In 2008, natural gas companies arrived and began drilling. For a select few lucky enough to have property around the gas wells, their arrival means big money. But not all residents will get so lucky. For many folks in Millerton, the arrival of the gas companies means more traffic, more pollution, more crime and more inconvenience without a monthly royalty check to buffer the pain. The sheer amount of natural gas scientists predict is in the Marcellus Shale will forever change how the U.S. and the rest of the world use energy. Politicians tout it as liberation from foreign oil. Scientists see it as an alternative to “dirty” coal. For this small town, natural gas means change. The money the natural gas companies are pumping into this local economy will change the lives of the townsfolk- and the town itself- forever. / text

This research identifies and analyzes the breadth and depth of the network of non-profit environmental organizations, sportsmen-oriented conservation groups, county conservation districts and state parks that advocate for or against Marcellus Shale drilling within northeastern and southwestern Pennsylvania where drilling occurs. The purpose of this study is to identify where resources are being mobilized and where environmental activities that focus on Marcellus Shale issues are underrepresented in the state. Results show that the counties with a higher number of gas wells do not necessarily have a higher level of environmental advocacy and that a lack of resources is a common barrier to this type of work. Organizations are better connected locally within the northeast. Counties which need to bolster their Marcellus Shale advocacy efforts in the northeast include: Carbon, Pike, Potter, Sullivan, Susquehanna and Wayne; and in the southwest: Beaver, Bedford, Blair, Fayette, Fulton, Greene, Somerset and Washington. / McAnulty College and Graduate School of Liberal Arts; / Graduate Center for Social and Public Policy / MA; / Thesis;

The case of mobilization against hydraulic fracturing by interest groups provided an opportunity to examine the influence of three factors (mission, audience, and policy context) on diagnostic, prognostic, and motivational framing. A comparative analysis was conducted of the mobilization activities of five national environmental organizations with a local presence in the Pennsylvania and New York Marcellus Shale regions. The organizations varied with respect to organizational mission, the audiences they were targeting (urban and rural), and the policy context in which they worked (pro and anti-hydraulic fracturing). Data came from eleven semi-structured in-depth interviews with organization personnel, and from the organizations' websites and published documents. The results of this research show how the organizations use diagnostic, prognostic, and motivational framing to mobilize citizens against hydraulic fracturing. They illustrate the influence of organizational mission, audience (urban versus rural), and policy context in how the groups take on these framing tasks. Overall, the findings provide insights into the variation in frames and framing that can occur at the organizational level inside a movement. They illustrate the explanatory value of investigating multiple factors as they affect diagnostic, prognostic, and motivational framing.

The relationship between shale gas development and budgetary and microeconomic externalities was studied. The extraction activity in the Barnett shaleformation provided a case study for assessing per-well highway infrastructure damage and water usage. The creation of a predictive model based upon the Barnett was applied to the Marcellus formation. The results showed support for the hypothesis that shale gas development creates negative externalities that amount to unfunded mandates and freerider problems for states and localities. Implications and policy solutions, including the case for a Pennsylvania natural gas fund, are discussed. / McAnulty College and Graduate School of Liberal Arts; / Graduate Center for Social and Public Policy / MA; / Thesis;

methane and other higher order hydrocarbons, through C4, with interest in further developing reactions important to methane- and ethane-related chemistry. With the increased demand for energy and the declining conventional hydrocarbons worldwide, energy companies, both majors and independents, are turning to unconventional resources to produce the hydrocarbons required to meet market demand. From coalbed methane to low permeability (tight) gas reservoirs and gas shales, energy companies are making substantial progress in developing the technologies required to bring these unconventional reserves to the market. A common misconception is that there are not enough domestic oil and gas reserves to fuel our economy. The United States imports most of the oil used for transportation fuel and several TCF of natural gas annually. However, there is a very large resource of natural gas in unconventional reservoirs, with over 2,200 TCF of gas in place in just the gas shale formations that have been identified in the energy arena (Navigant Study 2008). There are still major gas shale plays and basins that have not been explored and are waiting to be evaluated and developed. The natural gas in shales and other unconventional reservoirs can be used to generate electricity, or it can be turned into liquids and used by the transportation industry. It is also misconstrued that gas shales are relatively new in our industry and something of the future. The first commercially viable gas shale well was drilled in the early 1920s in Pennsylvania, before the famous oil well drilled by Colonel Drake. The objectives of this study are to (1) complete literature review to establish which geologic parameters affect completion techniques in five emerging gas shales: the Antrium, the Barnett, the Haynesville, the Marcellus, and the Woodford; (2) identify the different completion methods; (3) create an economic model for the completion techniques discussed; (4) develop a sensitivity analysis on various economic parameters to determine optimal completion strategy; and (5) create completion flowcharts. Based on the literature review I have done for several gas shale basins, I have identified seven pertinent geologic parameters that influence completion practices. These are depositional environment, total organic content (TOC), average gas content, shale mineralogy, shale thickness, and reservoir pressure. Next, I identified different completion and simulation trends in the industry for the different shale plays. The results from this study show that although there are some stark differences between depths (i.e. the Antrim Shale and the Haynesville Shale), shale plays are very similar in all other geologic properties. Interestingly, even with a large range for the different geological parameters, the completion methods did not drastically differ indicating that even if the properties do not fall within the range presented in this paper does not automatically rule them out for further evaluation in other plays. In addition to the evaluation of geologic properties, this study looked at drilling cost and the production profile for each play. Due to the volatility of the energy industry, economic sensitivity was completed on the price, capital, and operating cost to see what affect it would have on the play. From the analysis done, it is concluded that horizontal drilling in almost any economic environment is economic except for one scenario for the Woodford Shale. Therefore, gas shales plays should still be invested in even in lower price environments and companies should try to take advantage of the lower cost environments that occur during these times. With continual development of new drilling and completion techniques, these plays will become more competitive and can light the path for exploration of new shale plays worldwide.

The Marcellus Shale is an important resource play prevalent in several states in the eastern United States. The productive zone of the Marcellus Shale has variations in rock properties such as clay content, kerogen content and pore aspect ratio, and these variations may strongly effect elastic anisotropy. The objective of this study is to characterize surface seismic sensitivity for variations in anisotropic parameters relating to kerogen content and aspect ratio of kerogen saturated pores. The recognized sensitivity may aid to characterize these reservoir from surface seismic observations for exploration and production of hydrocarbon. In this study, I performed VTI anisotropic modeling based on geophysical wireline log data from Harrison County, WV. The wireline log data includes spectral gamma, density, resistivity, neutron porosity, monopole and dipole sonic logs. Borehole log data were analyzed to characterize the Marcellus Shale interval, and quantify petrophysical properties such as clay content, kerogen content and porosity. A rock physics model was employed to build link between petrophysical properties and elastic constants. The rock physics model utilized differential effective medium (DEM) theory, bounds and mixing laws and fluid substitution equations in a model scheme to compute elastic constants for known variations in matrix composition, kerogen content and pore shape distribution. The seismic simulations were conducted applying a vertical impulse source and three component receivers. The anisotropic effect to angular amplitude variations for PP, PS and SS reflections were found to be dominantly controlled by the Thomsen Ɛ parameter, characterizing seismic velocity variations with propagation direction. These anisotropic effect to PP data can be seen at large offset (>15o incidence angle). The most sensitive portion of PS reflections was observed at mid offset (15o-30o). I also analyzed seismic sensitivity for variations in kerogen content and aspect ratio of structural kerogen. Elastic constants were computed for 5%, 10%, 20% and 30% kerogen content from rock physics model and provided to the seismic model. For both kerogen content and aspect ratio model, PP amplitudes varies significantly at zero to near offset while PS amplitude varied at mid offsets (12 to 30 degree angle of incidences). / text

No description available.

In order to test the hypothesis that fractures in outcrops are equivalent to subsurface fracture systems I compare fracture cement morphology, texture, mineralogy and geochemistry from a suite of outcrop samples from Union Springs, NY, with fractures in four cores from a currently producing reservoir in southwest Pennsylvania. Transmitted light-microscope petrography and cold cathodoluminescence of calcite of outcrop and core samples reveals a variety of cement morphologies including crack-seal and blocky fracture cement textures that are interpreted as a record multiple repeated stages of fracture opening and sealing, as well as fibrous calcite fill and other mineral phases. The stable isotopic composition of calcite fracture cements from different fracture types in cores and outcrop range from -21.5 to +4.4‰ δ13C PDB and -8.0 to -12.0 ‰ δ18O PDB and indicate calcite precipitation temperatures between 46 and 89°C. Fluid inclusion microthermometry from secondary fluid inclusions indicates trapping temperatures between 110 and 120°C. Microprobe analysis of fracture calcite cement indicates a range in Fe, Mn, and Mg composition, with subsurface and outcrop cement of similar composition. Assuming burial history predicts thermal history, isotopic compositions together with fluid inclusions suggest calcite precipitated in vertical fractures during prograde burial, during the Acadian to early Alleghanian orogenies. These findings indicate that fractures in outcrops of the Marcellus Formation can be used as a proxy for those in the subsurface. / text

No description available.