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;

Various analytical, semi-analytical, and empirical models have been proposed to characterize rate and pressure behavior as a function of time in tight/shale gas systems featuring a horizontal well with multiple hydraulic fractures. Despite a small number of analytical models and published numerical studies there is currently little consensus regarding the large-scale flow behavior over time in such systems. The purpose of this work is to construct a fit-for-purpose numerical simulator which will account for a variety of production features pertinent to these systems, and to use this model to study the effects of various parameters on flow behavior. Specific features examined in this work include hydraulically fractured horizontal wells, multiple porosity and permeability fields, desorption, and micro-scale flow effects. The theoretical basis of the model is described in Chapter I, along with a validation of the model. We employ the numerical simulator to examine various tight gas and shale gas systems and to illustrate and define the various flow regimes which progressively occur over time. We visualize the flow regimes using both specialized plots of rate and pressure functions, as well as high-resolution maps of pressure distributions. The results of this study are described in Chapter II. We use pressure maps to illustrate the initial linear flow into the hydraulic fractures in a tight gas system, transitioning to compound formation linear flow, and then into elliptical flow. We show that flow behavior is dominated by the fracture configuration due to the extremely low permeability of shale. We also explore the possible effect of microscale flow effects on gas effective permeability and subsequent gas species fractionation. We examine the interaction of sorptive diffusion and Knudsen diffusion. We show that microscale porous media can result in a compositional shift in produced gas concentration without the presence of adsorbed gas. The development and implementation of the micro-flow model is documented in Chapter III. This work expands our understanding of flow behavior in tight gas and shale gas systems, where such an understanding may ultimately be used to estimate reservoir properties and reserves in these types of reservoirs.

It is essential to understand natural fracture systems embedded in shale-gas reservoirs and the stress fields that influence how induced fractures form in targeted shale units. Multicomponent seismic technology and elastic seismic stratigraphy allow geologic formations to be better images through analysis of different S-wave modes as well as the P-wave mode. Significant amounts of energy produced by P-wave sources radiate through the Earth as downgoing SV-wave energy. A vertical-force source is an effective source for direct SV radiation and provides a pure shear-wave mode (SV-SV) that should reveal crucial information about geologic surfaces located in anisotropic media. SV-SV shear wave modes should carry important information about petrophysical characteristics of hydrocarbon systems that cannot be obtained using other elastic-wave modes. Regardless of the difficulties of extracting good-quality SV-SV signal, direct shear waves as well as direct P and converted S energy should be accounted for in 3C seismic studies. Acquisition of full-azimuth seismic data and sampling data at small intervals over long offsets are required for detailed anisotropy analysis. If 3C3D data can be acquired with improved signal-to-noise ratio, more uniform illumination of targets, increased lateral resolution, more accurate amplitude attributes, and better multiple attenuation, such data will have strong interest by the industry. The objectives of this research are: (1) determine the feasibility of extracting direct SV-SV common-mid-point sections from 3-C seismic surveys, (2) improve the exploration for stratigraphic traps by developing systematic relationship between petrophysical properties and combinations of P and S wave modes, (3) create compelling examples illustrating how hydrocarbon-bearing reservoirs in low-permeable rocks (particularly anisotropic shale formations) can be better characterized using different S-wave modes (P-SV, SV-SV) in addition to the conventional P-P modes, and (4) analyze P and S radiation patterns produced by a variety of seismic sources. The research done in this study has contributed to understanding the physics involved in direct-S radiation from vertical-force source stations. A U.S. Patent issued to the Board of Regents of the University of Texas System now protects the intellectual property the Exploration Geophysics Laboratory has developed related to S-wave generation by vertical-force sources. The University’s Office of Technology Commercialization is actively engaged in commercializing this new S-wave reflection seismic technology on behalf of the Board of Regents. / text

The Fayetteville Shale is composed dominantly of clay, carbonate, and siliciclastic minerals. A variety of facies have been described by other workers and in this study, defined by mineral content, biota, fabric, and texture. Because the Fayetteville Shale is one of the top shale-gas producing plays in the U.S., an inquiry into key drivers of good-quality production is worthwhile. In particular, a hypothesis that intervals of high clay content should be avoided as production targets is investigated in this study. A high level of separation between wire-line log neutron porosity (NPHI) and density porosity (DPHI) in the Fayetteville Shale is observed in contrast to the wire-line log responses from the Barnett and Haynesville Shales. Clay minerals have a significant effect on NPHI, which in turn affects separation between NPHI and DPHI (PHISEP). X-Ray Diffraction (XRD) clay data was available for three wells, and efforts to correlate XRD results to PHISEP led to establishing NPHI as a reasonable proxy for clay. Using NPHI as a proxy it was possible to pick clay-rich intervals, map them across the study area, and to determine net clay in the Fayetteville Shale. Maps of net clay-rich intervals were compared to a map of production, but revealed no obvious correlation. Stratigraphic cross-sections showing the clay-rich intervals revealed a clay-poor interval in the upper part of the lower Fayetteville. This interval is the primary target for horizontal well completion. It is bounded above and below by more clay-rich intervals. Establishing the clay-rich intervals via porosity log separation (PHISEP) is one tool to help determine possible stratigraphic zones of gas production and can lead to a better understanding of intervals in which to expect production. / text

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

The Eagle Ford play in south Texas is currently one of the hottest plays in the United States. In 2012, the average Eagle Ford rig count (269 rigs) was 15% of the total US rig count. Assessment of the oil and gas resources and their associated uncertainties in the early stages is critical for optimal development. The objectives of my research were to develop a probabilistic methodology that can reliably quantify the reserves and resources uncertainties in unconventional oil and gas plays, and to assess Eagle Ford shale oil and gas reserves, contingent resources, and prospective resources. I first developed a Bayesian methodology to generate probabilistic decline curves using Markov Chain Monte Carlo (MCMC) that can quantify the reserves and resources uncertainties in unconventional oil and gas plays. I then divided the Eagle Ford play from the Sligo Shelf Margin to the San Macros Arch into 8 different production regions based on fluid type, performance and geology. I used a combination of the Duong model switching to the Arps model with b = 0.3 at the minimum decline rate to model the linear flow to boundary-dominated flow behavior often observed in shale plays. Cumulative production after 20 years predicted from Monte Carlo simulation combined with reservoir simulation was used as prior information in the Bayesian decline-curve methodology. Probabilistic type decline curves for oil and gas were then generated for all production regions. The wells were aggregated probabilistically within each production region and arithmetically between production regions. The total oil reserves and resources range from a P_(90) of 5.3 to P_(10) of 28.7 billion barrels of oil (BBO), with a P_(50) of 11.7 BBO; the total gas reserves and resources range from a P_(90) of 53.4 to P_(10) of 313.5 trillion cubic feet (TCF), with a P_(50) of 121.7 TCF. These reserves and resources estimates are much higher than the U.S. Energy Information Administration’s 2011 recoverable resource estimates of 3.35 BBO and 21 TCF. The results of this study provide a critical update on the reserves and resources estimates and their associated uncertainties for the Eagle Ford shale formation of South Texas.

Production of oil and gas from shale is often described as a revolution to energyproduction in North America. Since the beginning of this century the shale oilproduction has increased from practically zero to currently supply almost half of theU.S. oil production. This development is made possible by the technology ofhorizontal drilling and hydraulic fracturing. Since the production has not been ongoingfor that long, production data is still fairly limited in length and there are still largeuncertainties in many parameters, for instance production decline, lifespan, drainagearea, geographical extent and future technological development. More research isneeded to be able to estimate future production and resources with more certainty. At the moment shale oil is extracted only in North America but around the worldinvestigations are starting to assess if the conditions are suitable from shale oilextraction elsewhere. The global technically recoverable resource has been estimatedto 345 Gb, 10% of all global technically recoverable resources. Health andenvironmental aspects of shale oil and gas production have not yet been investigatedthoroughly and there is a risk that these parameters may slow down or limit thespreading of shale development. This report aims to examine production patterns of shale oil wells by applying declinecurve analysis. This analysis comprises of analyzing historical production data toinvestigate how the future production may develop. The area of the study is the EagleFord shale play in Texas, U.S. The goal is to fit decline curves to production data andthen use them for making estimates of future production in the Eagle Ford. The production in the shale oil wells included in the study reach their peak already within a few months after production starts. After this point, production is declining.After one year, production has decreased by 75% and after two years the productionis 87% of the peak production. The hyperbolic decline curve has a good fit toproduction data and in many cases the curve is close to harmonic. It is too early todetermine whether the alternative decline curve that is tested, the scaling declinecurve, has a better fit in the long term. The report also investigates how the density of the petroleum affects the declinecurve. The result is that lighter products decline faster than heavier. A sensitivity analysis is performed to illustrate how different parameters affect thefuture production development. In addition to the wells’ decline rate, the assumptionson the maximum number of wells, the maximal production and the rate at which newwells are added affect the ultimately recoverable resource. These parameters all havelarge uncertainties and makes resource estimations more difficult.

Arbetets syfte är att undersöka svällande alunskiffer i Östersund, vad de senaste framstegen är för vad som orsakar svällning och hur den kan identifieras och hanteras. Enklare laborationsmoment utförs med provmaterial från jord-bergsondering i Östersund, men arbetet är främst en litteraturstudie. Alunskiffer har en varierande sammansättning av organiskt material, kalkrika mineraler och järnsulfider. Svällningen orsakas av oxidationen av järnsulfider vilket leder till bildning av gipskristaller. Omfattande krafter kan utvecklas i samband med svällningen vilket gör det till ett stort problem som kan orsaka deformationer av ovanliggande byggnader. Vårt förslag till hur svällskiffer kan identifieras är att utföra en övergripande kartläggning av alunskiffern i Östersund. Dess beskaffenhet bör undersökas kemiskt för att ta reda på halten svavelkis, magnetskis och andra mineral. Skifferns mekaniska egenskaper bör undersökas ytterligare. För att motverka svällningen föreslår vi att de metoder som tidigare prövats i Östersund och visat sig vara framgångsrika bör undersökas och utvecklas ytterligare. Inspiration kan också tas från gruvindustrin och hur de arbetar för att motverka surt avfall. De laborativa momenten visar att svällförloppet inte var tillräckligt snabbt för att ge ett resultat under testperioden på drygt två veckor. Smektittestet visar att det inte förekommer svällande lera, smektit, i borrkaxprovet från jord-bergsonderingen. / The purpose of the essay is to examine swelling alum shale in Östersund, what the state of the art concerning the cause of the swelling and how it may be identified and dealt with. Minor laboratory experiment is performed with test materials from soil-rock probing in Östersund, although the essay is mainly focused on studying literature. Alum shale has a varied composition of organic matter, calcareous minerals and iron sulphides. The swelling is caused by oxidation of the iron sulphides which forms gypsum. The extensive forces associated with the swelling can inflict deformations in the overlying buildings and is a major issue in Östersund. Our suggestions for how to identify the swelling shale is to make an extensive survey of the Östersund area. The survey would locate the alum shale and take samples to determine the chemical composition of the shale. We also suggest further analysis of the mechanical properties of the shale. Our suggestions for how to deal with the swelling would be to further examine the methods that proved to be successful at earlier attempts in Östersund. Inspiration can also be found in the mining industry and how they deal with acid mine drainage. The smectite test show that there is no swelling clay, also known as smectite, present in the drill cutting sample from the soil-rock probing. The swelling test show no signs of swelling caused by pyrite oxidation and the development of gypsum, during the test period of around two weeks.

The weathering of shales is a globally important process affecting both natural and built environments. Shales form roughly 70 % of worldwide sedimentary rock deposits and therefore the weathering of these rocks has substantial effects on the geochemical cycling of elements such as carbon, iron and sulfur. Microbes have been shown to play a key role in weathering shales, primarily through the oxidation of the iron and sulfur of embedded pyrite and the resultant production of sulfuric acid. Despite significant interest in the microbial weathering of shales within industrial sectors such as biohydrometallurgy and civil engineering, comparatively few studies have investigated microbial shale weathering in natural environments. Furthermore, the role of microbes in natural shale weathering processes beyond iron oxidation has largely remained unexplored. In this thesis, the weathering capabilities of microbial communities from natural weathered shale was investigated. The North Yorkshire coastline was used as a study location, due to the abundance and diversity of natural cliffs and historic, disused industrial sites. Cliff erosion and recession on the North Yorkshire coastline is a major concern for local authorities and is the focus of current research. The aim of this work has been to evaluate microbial shale weathering processes within these environments, and hypothesise the possible contribution they may have to erosive processes. Phenotypic plate assays inoculated with weathered shale material were used to obtain rock weathering bacterial isolates that tested positive for a specific weathering phenotype, such as iron oxidation or siderophore production. Subsequent 16S rRNA sequencing enabled genera level identification, revealing 15 genera with rock weathering capabilities with several being associated with multiple weathering phenotypes including Aeromonas sp., Pseudomonas sp. and Streptomyces sp. Shale enrichment liquid cultures were incubated with shale rock chips to simulate natural biological weathering conditions, and the concentration of rock-leached elements in the fluid measured. No evidence of microbially-enhanced leaching was found consistently for any element, however the significant reduction in leachate iron concentration under biological conditions indicates that iron precipitation occurred via microbial iron oxidation. Enrichment cultures inoculated with weathered shale and containing organic matter (OM) rich rocks in water or M9 medium, both liquids lacking an organic carbon source, were grown over several months. The cultures yielded microbial isolates that could utilise rock bound OM sources and one bacterial isolate, Variovorax paradoxus, was taken forward for ecophysiological study. The shale rock that the organism was isolated from, along with other OM rich rocks (mudstones and coals), elicited complex responses from V. paradoxus including enhanced growth and motility. Finally, mineral microcosms in vitro and mesocosms in situ investigated microbial colonization and weathering of shale-comprising minerals (albite, calcite, muscovite, pyrite and quartz). Microcosms were established using iron oxidizing enrichment cultures, as based on the results of the simulated rock weathering experiments, while the in situ mesocosms were buried within weathered shale scree within a disused mine level. Levels of colonization significantly varied between minerals within the microcosms (pyrite > albite, muscovite > quartz > calcite). Although differences in mineral colonization were seen in the mesocosms, they did not match those in the microcosms and were not statistically significant. Pyrite incubated in the microcosms became significantly weathered, with extensive pit formation across the mineral surface that is consistent with microbial iron oxidation. In the mesocosms, pit formation was not identified on pyrite surfaces but dark etchings into the pyrite surface were found underneath fungi hyphal growth. The results of this thesis highlights that a range of microbial rock weathering mechanisms are abundant across weathered shale environments. Microbial iron oxidizing activity was a dominant biogeochemical process that altered rock-fluid geochemistry and weathered pyrite surfaces. However, the impact on rock or mineral weathering of other microbial mechanisms was not elucidated by this work. Given the known capabilities of these mechanisms, the conditions under which they are active may not have been met within the experimental setup used. Microbial iron oxidation in shale and shale-derived materials has previously been demonstrated to weaken rock structure through acid production and secondary mineral formation. From the results of this thesis, it is clear that microbial iron oxidation is an active process within some of the weathered shale environments studied, including cliff surfaces. Therefore, it can be hypothesised that microbial activity could play a role in structurally weakening shale rock within cliffs and accelerate their erosion. Future work should attempt to quantify the rate and extent of microbial iron oxidizing activity within shale cliff environments and investigate its contribution to erosive processes.

The environment of deposition of the Ohio Shale of the Appalachian Basin has been studied extensively using various geochemical proxies for each of its members. The accumulation of organic matter (OM) and its preservation in the Late Devonian-Early Mississippian black shales of central Kentucky have been studied extensively, especially the possible correlations between trace metal contents and water-column oxygenation. Previous work has centered on geochemical, petrographic, and isotopic analysis of samples collected throughout the central Appalachian Basin. Mechanisms for OM preservation include high productivity, enhanced preservation due to dysoxic or anoxic bottom waters, and a feedback loop due to high productivity that creates enhanced preservation through the periodic cycling and scavenging of essential nutrients. Usually, a combination of these factors results in the accumulation of enough OM to produce these black shales. This research shows the relationships between trace metal data and the environment of deposition of several cores taken along the eastern side of the Cincinnati Arch in the central Appalachian Basin. Whereas the indices do not all agree in every instance across the breadth of the study area, analyzed together a predominant environment of deposition has been inferred for the shales. The Sunbury Shale and upper part of the Cleveland Member of the Ohio Shale were deposited under euxinic conditions, the lower part of the Cleveland Member was likely euxinic in the northern study region and anoxic throughout the central and southern study areas, whereas the Huron Member of the Ohio Shale was deposited under a range of conditions, from oxic, to dysoxic, to anoxic.