Дисертації з теми "Gas shales"
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Rexer, Thomas. "Nanopore characterisation and gas sorption potential of European gas shales." Thesis, University of Newcastle upon Tyne, 2014. http://hdl.handle.net/10443/2597.
Повний текст джерелаPathi, Venkat Suryanarayana Murthy. "Factors affecting the permeability of gas shales." Thesis, University of British Columbia, 2008. http://hdl.handle.net/2429/5302.
Повний текст джерелаRoychaudhuri, Basabdatta. "Spontaneous Countercurrent and Forced Imbibition in Gas Shales." Thesis, University of Southern California, 2018. http://pqdtopen.proquest.com/#viewpdf?dispub=10635652.
Повний текст джерелаIn this study, imbibition experiments are used to explain the significant fluid loss, often more than 70%, of injected water during well stimulation and flowback in the context of natural gas production from shale formations. Samples from a 180 ft. long section of a vertical well were studied via spontaneous and forced imbibition experiments, at lab-scale, on small samples with characteristic dimensions of a few cm; in order to quantify the water imbibed by the complex multi-porosity shale system. The imbibition process is, typically, characterized by a distinct transition from an initial linear rate (vs. square root of time) to a much slower imbibition rate at later times. These observations along with contact angle measurements provide an insight into the wettability characteristics of the shale surface. Using these observations, together with an assumed geometry of the fracture system, has made it possible to estimate the distance travelled by the injected water into the formation at field scale.
Shale characterization experiments including permeability measurements, total organic carbon (TOC) analysis, pore size distribution (PSD) and contact angle measurements were also performed and were combined with XRD measurements in order to better understand the mass transfer properties of shale. The experimental permeabilities measured in the direction along the bedding plane (10 –1–10–2 mD) and in the vertical direction (~10–4 mD) are orders of magnitude higher than the matrix permeabilities of these shale sample (10–5 to 10 –8 mD). This implies that the fastest flow in a formation is likely to occur in the horizontal direction, and indicates that the flow of fluids through the formation occurs predominantly through the fracture and micro-fracture network, and hence that these are the main conduits for gas recovery. The permeability differences among samples from various depths can be attributed to different organic matter content and mineralogical characteristics, likely attributed to varying depositional environments. The study of these properties can help ascertain the ideal depth for well placement and perforation.
Forced imbibition experiments have been carried out to better understand the phenomena that take place during well stimulation under realistic reservoir conditions. Imbibition experiments have been performed with real and simulated frac fluids, including deionized (DI) water, to establish a baseline, in order to study the impact on imbibition rates resulting from the presence of ions/additives in the imbibing fluid. Ion interactions with shales are studied using ion chromatography (IC) to ascertain their effect on imbibition induced porosity and permeability change of the samples. It has been found that divalent cations such as calcium and anions such as sulfates (for concentrations in excess of 600 ppm) can significantly reduce the permeability of the samples. It is concluded, therefore, that their presence in stimulating fluids can affect the capillarity and fluid flow after stimulation. We have also studied the impact of using fluoro-surfactant additives during spontaneous and forced imbibition experiments. A number of these additives have been shown to increase the measured contact angles of the shale samples and the fluid recovery from them, thus making them an ideal candidate for additives to use. Their interactions with the shale are further characterized using the Dynamic Light Scattering (DLS) technique in order to measure their hydrodynamic radius to compare it with the pore size of the shale sample.
Hine, Lucy Ann. "Onshore oil and gas in Britain : planning problems and policies." Thesis, University of Aberdeen, 1985. http://digitool.abdn.ac.uk/R?func=search-advanced-go&find_code1=WSN&request1=AAIU361902.
Повний текст джерелаWilson, Timothy George Edmund. "Financial aspects of the oil and gas exploration and production industry." Thesis, University of Exeter, 1986. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.302980.
Повний текст джерелаRybalcenko, Konstantin. "Gas flow measurements in shales : laboratory, field and numerical investigations." Thesis, University of Leeds, 2017. http://etheses.whiterose.ac.uk/16966/.
Повний текст джерелаBou, Hamdan Kamel F. "Investigating the role of proppants in hydraulic fracturing of gas shales." Thesis, University of Aberdeen, 2019. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=.
Повний текст джерелаGasparik, Matus [Verfasser]. "Experimental investigation of gas storage properties of black shales / Matus Gasparik." Aachen : Hochschulbibliothek der Rheinisch-Westfälischen Technischen Hochschule Aachen, 2014. http://d-nb.info/1051427770/34.
Повний текст джерелаFink, Reinhard Verfasser], Ralf [Akademischer Betreuer] [Littke, and Andreas [Akademischer Betreuer] Busch. "Experimental investigation of gas transport and storage processes in the matrix of gas shales / Reinhard Fink ; Ralf Littke, Andreas Busch." Aachen : Universitätsbibliothek der RWTH Aachen, 2017. http://d-nb.info/1162499249/34.
Повний текст джерелаFink, Reinhard [Verfasser], Ralf [Akademischer Betreuer] Littke, and Andreas [Akademischer Betreuer] Busch. "Experimental investigation of gas transport and storage processes in the matrix of gas shales / Reinhard Fink ; Ralf Littke, Andreas Busch." Aachen : Universitätsbibliothek der RWTH Aachen, 2017. http://d-nb.info/1162499249/34.
Повний текст джерелаAlaiyegbami, Ayodele O. "Porescale Investigation of Gas Shales Reservoir Description by Comparing the Barnett, Mancos, and Marcellus Formation." Thesis, University of Louisiana at Lafayette, 2014. http://pqdtopen.proquest.com/#viewpdf?dispub=1557534.
Повний текст джерелаThis thesis describes the advantages of investigating gas shales reservoir description on a nanoscale by using petrographic analysis and core plug petrophysics to characterize the Barnett, Marcellus and Mancos shale plays. The results from this analysis now indicate their effects on the reservoir quality. Helium porosity measurements at confining pressure were carried out on core plugs from this shale plays. SEM (Scanning Electron Microscopy) imaging was done on freshly fractured gold-coated surfaces to indicate pore structure and grain sizes. Electron Dispersive X-ray Spectroscopy was done on freshly fractured carbon-coated surfaces to tell the mineralogy. Extra-thin sections were made to view pore spaces, natural fractures and grain distribution.
The results of this study show that confining pressure helium porosity values to be 9.6%, 5.3% and 1.7% in decreasing order for the samples from the Barnett, Mancos and Marcellus shale respectively. EDS X-ray spectroscopy indicates that the Barnett and Mancos have a high concentration of quartz (silica-content); while the Mancos and Marcellus contain calcite. Thin section analysis reveals obvious fractures in the Barnett, while Mancos and Marcellus have micro-fractures.
Based on porosity, petrographic analysis and mineralogy measurements on the all the samples, the Barnett shale seem to exhibit the best reservoir quality.
Mandal, Partha Pratim. "Integrated Geomechanical Characterization of Anisotropic Gas Shales: Field Appraisal, Laboratory Testing, Viscoelastic Modelling,and Hydraulic Fracture Simulation." Thesis, Curtin University, 2021. http://hdl.handle.net/20.500.11937/88568.
Повний текст джерелаChere, Naledi. "Sedimentological and geochemical investigations on borehole cores of the Lower Ecca Group black shales, for their gas potential : Karoo basin, South Africa." Thesis, Nelson Mandela Metropolitan University, 2015. http://hdl.handle.net/10948/d1021201.
Повний текст джерелаHuls, Boyd T. "A feasibility study on modeling and prediction of production behavior in naturally fractured shale reservoirs." Morgantown, W. Va. : [West Virginia University Libraries], 2004. https://etd.wvu.edu/etd/controller.jsp?moduleName=documentdata&jsp%5FetdId=3726.
Повний текст джерелаTitle from document title page. Document formatted into pages; contains viii, 105 p. : ill. (some col.), map. Includes abstract. Includes bibliographical references (p. 96-97).
Gaus, Garri Verfasser], Ralf [Akademischer Betreuer] [Littke, and Andreas [Akademischer Betreuer] Busch. "Experimental investigation of gas transport and storage processes in the matrix of carbonaceous shales / Garri Gaus ; Ralf Littke, Andreas Busch." Aachen : Universitätsbibliothek der RWTH Aachen, 2020. http://d-nb.info/1231317450/34.
Повний текст джерелаZhang, Qian Verfasser], Ralf [Akademischer Betreuer] [Littke, and Reinhard [Akademischer Betreuer] Sachsenhofer. "Petroleum geochemistry and petrophysics of oil and gas shales from south China and northwest Germany / Qian Zhang ; Ralf Littke, Reinhard Sachsenhofer." Aachen : Universitätsbibliothek der RWTH Aachen, 2020. http://d-nb.info/1231118059/34.
Повний текст джерелаStrong, Zachary M. "Evaluating Clay Mineralogy as a Thermal Maturity Indicator for Upper Devonian Black and Grey Shales and Siltstones within the Ohio Appalachian Basin." University of Akron / OhioLINK, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=akron1447684617.
Повний текст джерелаAltun, Naci Emre. "Beneficiation Of Himmetoglu And Beypazari Oil Shales By Flotation And Their Thermal Characterization As An Energy Source." Phd thesis, METU, 2006. http://etd.lib.metu.edu.tr/upload/2/12606990/index.pdf.
Повний текст джерела#8217
s great oil shale reserves.
Rippen, Daniel Verfasser], Ralf [Akademischer Betreuer] [Littke, and Brian [Akademischer Betreuer] Horsfield. "Oil and gas shales of Northern Germany : implications from organic geochemical analyses, petrophysical measurements and 3D numerical basin modelling / Daniel Rippen ; Ralf Littke, Brian Horsfield." Aachen : Universitätsbibliothek der RWTH Aachen, 2015. http://d-nb.info/1130327094/34.
Повний текст джерелаGei, Davide. "Investigation and derivation of anisotropic parameters from microseismic reservoir monitoring." Doctoral thesis, Università degli studi di Trieste, 2013. http://hdl.handle.net/10077/8612.
Повний текст джерелаUn materiale si definisce isotropico quando le sue proprietà non cambiano in funzione della direzione secondo cui vengono misurate. Al contrario, se il mezzo è caratterizzato da una dipendenza direzionale delle sue proprietà, è chiamato anisotropico. Tradizionalmente, l’esplorazione sismica è basata sul processamento e interpretazione di dati acustici relativi a mezzi considerati sismicamente isotropici. Tuttavia, l’isotropia è sempre un modello approssimato per descrivere le formazioni geologiche, specialmente nel caso di bacini sedimentari. L’imaging sismico e la stima delle velocità sismiche nel sottosuolo risultano essere inaccurati quando dati relativi a mezzi anisotropici vengono processati con l’assunzione di isotropia. Conseguentemente è importante definire il modello e l’intensità dell’anisotropia che contraddistinguono l’area in esame e utilizzare queste informazioni per il processamento dei dati sismici. Lo scopo principale di questo studio consiste nella caratterizzazione dell’anisotropia degli scisti bituminosi del giacimento di Abbott, presenti nel Bacino di Arkoma, Oklahoma, USA. I dati consistono in registrazioni sismiche ottenute da due stendimenti di superficie composti da geofoni a sola componente verticale e da accelerometri a tre componenti, acquisite durante la fratturazione idraulica del giacimento. Il monitoraggio sismico di superficie è generalmente meno costoso se comparato al monitoraggio da pozzo, specialmente quando i pozzi di osservazione non sono disponibili e devono essere perforati. La tecnica da superficie è basata sull’acquisizione di dati sismici da centinaia di ricevitori opportunamente distribuiti al suolo ed offre una visione del campo d’onda molto più ampia rispetto al monitoraggio da pozzo, generalmente limitato a qualche decina di ricevitori vicini tra loro. Inoltre, l’analisi dei tempi di arrivo di dati acquisiti da reti di ricevitori di superficie costituisce un metodo più robusto rispetto agli studi di polarizzazione di cui sono oggetto i dati di monitoraggio sismico da pozzo. L’inconveniente è un rapporto segnale rumore sensibilmente più basso a causa delle eterogeneità geologiche presenti in prossimità della superficie. Durante il trattamento degli scisti bituminosi di Abbott, è stato registrato qualche centinaio di eventi microsismici e di questi sono stati analizzati i dieci eventi più forti, oltre che i dati derivanti da scoppi di perforazione. La Vertical Transverse Isotropy (VTI) è, senza dubbio, il modello anisotropico più comune in bacini sedimentari, specialmente in presenza di scisti. La velocità sismica in mezzi VTI varia quando la direzione di propagazione si discosta dalla verticale ma non al variare dell’azimut. L’analisi dei dati sismici relativi alle onde P ha confermato che il modello VTI è quello che meglio si adatta agli scisti di Abbott e/o alle rocce sovrastanti. In mezzi omogenei ed anisotropici di tipo VTI i tempi di arrivo delle onde P ed S si discostano dal moveout iperbolico, che invece caratterizza la propagazione in mezzi omogenei ed isotropici. La non-iperbolicità dei tempi di percorso delle onde sismiche può essere utilizzata per la stima dei parametri di anisotropia. I tempi di arrivo ottenuti dai dati sperimentali possono essere approssimati attraverso l’utilizzo di equazioni analitiche che esprimono i tempi di percorso in funzione dei suddetti parametri di anisotropia. Questa tecnica di inversione è stata testata con dati sintetici e successivamente applicata ai dati del giacimento di Abbott. Dai tempi di arrivo delle onde P ed SH di dieci eventi microsismici sono stati stimati i tre parametri di anisotropia di Thomsen, mentre per quattro scoppi di perforazione è stata applicata l’inversione delle sole onde compressionali. Inoltre è stata accuratamente analizzata la sensibilità del metodo alla presenza di rumore e di eventuale inaccuratezza dei parametri di input. Le inversioni dei tempi di arrivo delle onde P prodotte dagli scoppi di perforazione forniscono parametri di anisotropia tra loro consistenti, mentre i risultati dai tempi di arrivo delle onde compressionali e di taglio relativi agli eventi microsismici sono caratterizzati da una moderata dispersione. Questo risultato può essere spiegato dalla minore accuratezza e più ampia distribuzione spaziale delle sorgenti microsismiche, se paragonate agli scoppi di perforazione. Inoltre, le proprietà elastiche del volume di roccia nell’intorno di ciascuna sorgente microsismica, così come le sue proprietà anisotropiche, variano durante il processo di fratturazione costituendo una possibile causa della dispersione dei parametri di anisotropia stimati. Le inversioni dei tempi di arrivo delle onde SH forniscono elevati valori del parametro di anisotropia associato a questi segnali sismici. Tuttavia è importante sottolineare che si tratta di un’espressione della anisotropia effettiva del mezzo e non di quella intrinseca. Lo shear-wave splitting è considerato un robusto indicatore di anisotropia sismica. Nell’ambito di questo studio, questo fenomeno viene trattato in modo esaustivo, con particolare riguardo ai mezzi VTI. Il tempo di ritardo tra le due onde di taglio soggette a splitting può essere stimato dai dati sismici e quindi invertito per ottenere i parametri di anisotropia. La stima dei tempi di ritardo attraverso il metodo della cross-correlazione fornisce risultati consistenti per ricevitori vicini. L’inversione dei tempi di ritardo è basata sulle approssimazioni dei tempi di percorso delle onde SH ed SV in mezzi debolmente anisotropici e conferma l’anisotropia piuttosto pronunciata già messa in evidenza dalle analisi dei tempi di arrivo delle onde P ed SH. Sono state anche implementate tecniche di analisi dello shear-wave splitting più sofisticate, adatte a modelli di anisotropia più generali. Tuttavia, questi metodi già ampiamente utilizzati per l’analisi di eventi telesismici hanno fornito risultati poco affidabili, principalmente a causa del basso rapporto segnale-rumore caratterizzante i dati del giacimento di Abbott.
A material whose properties do not change with the direction along which they are measured is called isotropic. On the contrary, if the properties of the medium show directional dependency it is called anisotropic. Traditional seismic exploration is based on processing and interpretation of acoustic data and considers seismically isotropic subsoil. However, isotropy is always an approximate model to describe the geological formations, especially in sedimentary basins. Seismic imaging and estimation of subsurface velocities become inaccurate when anisotropic data are treated under the general assumption of isotropy. Consequently it is important to define the model and strength of anisotropy for the study area and use this information in data processing. The main goal of this study is the anisotropy characterization of the Abbott gas shale play located in the Arkoma basin, Oklahoma, USA. The data consist in seismic records obtained from two surface arrays of 1C geophones and 3C accelerometers, respectively, and acquired during the hydraulic fracturing of the reservoir. Surface (or near-surface) monitoring can be less expensive if compared to borehole monitoring when the observation wells must be drilled. The former technique is based on data acquisition from hundreds of receivers widely distributed over the Earth surface and gives a larger field view than borehole monitoring, generally limited to tenth of 3C receivers. Moreover, arrival time analyses of data recorded from surface widely-distributed receiver-networks are generally more robust than polarization studies carried out on borehole microseismic data. The drawback is a significant lower signal-to-noise ratio due to near surface heterogeneities. During the treatment of the Abbott gas shale, a few hundred microseismic events were recorded and the ten strongest events have been analyzed, together with the data from perforation shots. Vertical transverse isotropy (VTI) is, unarguably, the most common anisotropic model for sedimentary basins and particularly for shales. Seismic velocity in VTI media varies with direction of propagation away from the vertical, but not with azimuth. The analysis of the P-waves seismic dataset confirms VTI to be the best-suited model for the Abbott reservoir and/or overburden. P- and S-waves arrival times in homogeneous VTI media deviate from the hyperbolic moveout, which characterize seismic propagation in homogeneous isotropic media. The nonhyperbolicity of the traveltime can be used to estimate anisotropy parameters. The actual arrival times, picked from the experimental data, can be approximated considering analytic traveltime equations, which depend on such parameters. This inversion technique is tested with full wave synthetic data and applied to the Abbott dataset. The three Thomsen anisotropy parameters are estimated from P- and SH-arrival times of ten microseismic events, while only compressional waves are used for the inversion of four perforation shots. Moreover, the sensitivity of the P-wave arrival time inversion to picking noise and inaccuracies of input parameters is thoroughly analyzed. The inversions of the P-wave arrival times of the perforation shots give quite consistent anisotropy parameters, while the results from the compressional and shear waves arrival time inversions of the microseismic events are characterized by moderate scattering. This can be explained by the lower location accuracy and widespread distribution of the microseismic events, compared with the perforation shots. Moreover, the elastic properties of the sismogenic volume, as well as the local anisotropic properties, vary due to the process of fracturing and possibly cause the moderate scattering of the parameters inverted from the microseismic events. The inversions of the SH-wave arrival times result in consistently high values of the anisotropy parameter related to this wave mode. However, it is important to remark that this is the expression of effective and not intrinsic anisotropy. Shear-wave splitting is considered a robust indicator of seismic anisotropy. Such phenomenon is exhaustively addressed and described for VTI media, specifically. The time-delay between the two split waves can be estimated from the seismic records and inverted for anisotropy parameters. The estimation of the splitting times of a seismic event through the cross- correlation method gives consistent results for adjacent receivers. The inversion of the estimated time delays is based on SH- and SV-traveltimes approximations in weakly anisotropic media, and confirms the relatively high degree of anisotropy already highlighted by the P- and SH-wave arrival time analyses. More complex techniques of shear-wave splitting analysis, suitable for more general anisotropic models are also implemented. However, these methods, widely used for teleseismic shear-waves data, give unreliable results mainly because of the low signal-to-noise ratio characterizing the seismic data.
XXV Ciclo
1970
Labed, Ismail. "Gas-condensate flow modelling for shale gas reservoirs." Thesis, Robert Gordon University, 2016. http://hdl.handle.net/10059/2144.
Повний текст джерелаKalantari-Dahaghi, Amirmasoud. "Reservoir modeling of New Albany Shale." Morgantown, W. Va. : [West Virginia University Libraries], 2010. http://hdl.handle.net/10450/11022.
Повний текст джерелаTitle from document title page. Document formatted into pages; contains xii, 81 p. : ill. (some col.), col. maps. Includes abstract. Includes bibliographical references (p. 68-69).
Zou, Jie. "Assessment of Gas Adsorption Capacity in Shale Gas Reservoirs." Thesis, Curtin University, 2019. http://hdl.handle.net/20.500.11937/75387.
Повний текст джерелаKnudsen, Brage Rugstad. "Production Optimization in Shale Gas Reservoirs." Thesis, Norwegian University of Science and Technology, Department of Engineering Cybernetics, 2010. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-10035.
Повний текст джерелаNatural gas from organic rich shales has become an important part of the supply of natural gas in the United States. Modern drilling and stimulation techniques have increased the potential and profitability of shale gas reserves that earlier were regarded as unprofitable resources of natural gas. The most prominent property of shale gas reservoirs is the low permeability. This is also the reason why recovery from shale gas wells is challenging and clarifies the need for stimulation with hydraulic fracturing. Shale gas wells typically exhibit a high initial peak in the production rate with a successive rapid decline followed by low production rates. Liquid accumulation is common in shale wells and is detrimental on the production rates. Shut-ins of shale gas wells is used as a means to prevent liquid loading and boost the production. This strategy is used in a model-based production optimization of one and multiple shale gas well with the objective of maximizing the production and long-term recovery. The optimization problem is formulated using a simultaneous implementation of the reservoir model and the optimization problem, with binary variables to model on/off valves and an imposed minimal production rate to prevent liquid loading. A reformulation of the nonlinear well model is applied to transform the problem from a mixed integer nonlinear program to a mixed integer linear program. Four numerical examples are presented to review the potential of using model-based optimization on shale gas wells. The use of shut-ins with variable duration is observed to result in minimal loss of cumulative production on the long term recovery. For short term production planning, a set of optimal production settings are solved for multiple wells with global constraints on the production rate and on the switching capacity. The reformulation to a mixed integer linear program is shown to be effective on the formulated optimization problems and allows for assessment of the error bounds of the solution.
Al-Dulaimi, Zaid. "Non-aqueous shale gas recovery system." Thesis, Cardiff University, 2017. http://orca.cf.ac.uk/104172/.
Повний текст джерелаKlein, Michael. "Hydraulic fracturing and shale gas extraction." Kansas State University, 2012. http://hdl.handle.net/2097/15160.
Повний текст джерелаDepartment of Chemical Engineering
James Edgar
In the past decade the technique of horizontal drilling and hydraulic fracturing has been improved so much that it has become a cost effective method to extract natural gas from shale formations deep below the earth’s surface. Natural gas extraction has boomed in the past few years in the United States, enough that it has driven prices to an all time low. The amount of natural gas reserves in the U.S. has led to claims that it can lead the country to energy independence. It has also been touted as a cleaner fuel for electricity generation and to power vehicles. This report explains hydraulic fracturing and horizontal drilling particularly with regards to utilizing the techniques for natural gas extraction from shale gas. It also discusses the environmental impact due to the drilling and gas extraction. It demonstrates that although the natural gas beneath the U.S. is a valuable resource, the impacts to the planet and mankind are not to be taken lightly. There is the potential for the effects to be long term and detrimental if measures are not taken now to control them. In addition although on the surface natural gas seems to be a greener fuel, particularly in comparison to gasoline, it is also considered worse for the environment.
Burnett, Andrew Patrick. "Come Shale Away: Estimating Short-run Supply Elasticities of Shale Natural Gas." Miami University / OhioLINK, 2017. http://rave.ohiolink.edu/etdc/view?acc_num=miami1500992422730534.
Повний текст джерелаHartigan, David Anthony. "The petrophysical properties of shale gas reservoirs." Thesis, University of Leicester, 2015. http://hdl.handle.net/2381/32213.
Повний текст джерелаXiong, Fengyang. "Desorption and Adsorption of Subsurface Shale Gas." The Ohio State University, 2020. http://rave.ohiolink.edu/etdc/view?acc_num=osu1591975402482308.
Повний текст джерелаDrouven, Markus G. "Mixed Integer Programming Models for Shale Gas Development." Research Showcase @ CMU, 2017. http://repository.cmu.edu/dissertations/874.
Повний текст джерелаDeshpande, Vaibhav Prakashrao. "General screening criteria for shale gas reservoirs and production data analysis of Barnett shale." [College Station, Tex. : Texas A&M University, 2008. http://hdl.handle.net/1969.1/ETD-TAMU-2357.
Повний текст джерелаSharma, Shekar. "Evaluating Leachability of Residual Solids Generated from Unconventional Shale Gas Production Operations in Marcellus Shale." Thesis, Virginia Tech, 2014. http://hdl.handle.net/10919/50514.
Повний текст джерелаMaster of Science
Boswell, Zachary (Zachary Karol). "A study of natural gas extraction in Marcellus shale." Thesis, Massachusetts Institute of Technology, 2011. http://hdl.handle.net/1721.1/66827.
Повний текст джерелаCataloged from PDF version of thesis.
Includes bibliographical references (p. 73-74).
With the dramatic increases in crude oil prices there has been a need to find reliable energy substitutions. One substitution that has been used in the United States is natural gas. However, with the increased use of natural gas, conventional sources are being depleted rapidly. Due to the strong use of conventional gas sources people have turned to unconventional gas sources. Unconventional gas sources are deemed economically infeasible to produce at the current price of natural gas. The reason some sources are unconventional is because the formation that holds the natural gas is highly impermeable, eg shale. Sources of unconventional natural gas in the United States are found in shales across the country; the Marcellus shale is one of these sources. The Marcellus shale is the largest natural gas source in the United States and is quickly becoming a major gas play. Estimates show that there are trillions of cubic feet of natural gas stored within the Marcellus shale, and energy companies are flocking to the area to extract it. This paper will discuss the techniques used by operators to extract natural gas in the Marcellus Shale. The focus will be on the drilling and hydraulic fracturing processes. A discussion regarding the environmental concerns when extracting natural gas follows. It was found that the methods used to extract natural gas, while effective, can harm the areas water supply. New technologies are being developed that use less water, are safer for the environment, and just as effective as the older methods in most situations.
by Zachary Boswell.
M.Eng.
Tan, Siah Hong. "Applications of optimization to shale oil and gas monetization." Thesis, Massachusetts Institute of Technology, 2017. http://hdl.handle.net/1721.1/111403.
Повний текст джерелаCataloged from PDF version of thesis.
Includes bibliographical references (pages 259-274).
This thesis addresses the challenges brought forth by the shale oil and gas revolution through the application of formal optimization techniques. Two frameworks, each addressing the monetization of shale oil and gas resources at different ends of the scale spectrum, are developed. Importantly, these frameworks accounted for both the dynamic and stochastic aspects of the problem at hand. The first framework involves the development of a strategy to allocate small-scale mobile plants to monetize associated or stranded gas. The framework is applied to a case study in the Bakken shale play where large quantities of associated gas are flared. Optimal strategies involving the continuous redeployment of plants are analyzed in detail. The value of the stochastic solution with regards to uncertainty in resource availability is determined and it indicates that mobile plants possess a high degree of flexibility to handle uncertainty. The second framework is a comprehensive supply chain optimization model to determine optimal shale oil and gas infrastructure investments in the United States. Assuming two different scenario sets over a time horizon of twenty-five years, the features of the optimal infrastructure investments and associated operating decisions are determined. The importance of incorporating uncertainty into the framework is demonstrated and the relationship between the stability of the stochastic solution and the variance of the distribution of future parameters is analyzed. The thesis also analyzes the Continuous Flow Stirred Tank Reactor (CFSTR) equivalence principle as a method for screening and targeting favorable reaction pathways, with applications directed towards gas-to-liquids conversion. The principle is found to have limited usefulness when applied to series reactions due to an unphysical independence of the variables which allows for the maximization of production of any intermediate species regardless of the magnitude of its rate of depletion. A reformulation which eliminates the unphysical independence is proposed. However, the issue of arbitrary truncation of downstream reactions remains.
by Siah Hong Tan.
Ph. D.
Ahmadi, Mahdi. "Ozone Pollution of Shale Gas Activities in North Texas." Thesis, University of North Texas, 2016. https://digital.library.unt.edu/ark:/67531/metadc849624/.
Повний текст джерелаCarrero-Parreño, Alba. "Modeling and optimization of shale gas water management systems." Doctoral thesis, Universidad de Alicante, 2018. http://hdl.handle.net/10045/102228.
Повний текст джерелаTestamanti, Maria Nadia. "Assessment of Fluid Transport Mechanisms in Shale Gas Reservoirs." Thesis, Curtin University, 2018. http://hdl.handle.net/20.500.11937/75650.
Повний текст джерелаFleming, Ruven C. "Shale gas extraction in Europe and Germany : the impacts of environmental protection and energy security on emerging regulations." Thesis, University of Aberdeen, 2015. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=228565.
Повний текст джерелаNordsveen, Espen T. "Mixed Integer Model Predictive Control of Multiple Shale Gas Wells." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for teknisk kybernetikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-18400.
Повний текст джерелаHersandi, Sandi Rizman. "Modeling of Water Behavior in Hydraulically-Fractured Shale Gas Wells." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2013. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-23614.
Повний текст джерелаCooper, Jasmin. "Life cycle sustainability assessment of shale gas in the UK." Thesis, University of Manchester, 2017. https://www.research.manchester.ac.uk/portal/en/theses/life-cycle-sustainability-assessment-of-shale-gas-in-the-uk(692252b3-faab-4428-899c-afbcdeec787a).html.
Повний текст джерелаHudson, Michael Robert. "Numerical simulation of hydraulic fracturing in tight gas shale reservoirs." Thesis, University of Leeds, 2017. http://etheses.whiterose.ac.uk/18351/.
Повний текст джерелаPetersen, H. "Decision-making under uncertainty : the political economy of shale gas." Thesis, City, University of London, 2016. http://openaccess.city.ac.uk/19213/.
Повний текст джерелаHammond, Christopher D. (Christopher Daniel). "Economic analysis of shale gas wells in the United States." Thesis, Massachusetts Institute of Technology, 2013. http://hdl.handle.net/1721.1/83718.
Повний текст джерелаCataloged from PDF version of thesis.
Includes bibliographical references (pages 65-66).
Natural gas produced from shale formations has increased dramatically in the past decade and has altered the oil and gas industry greatly. The use of horizontal drilling and hydraulic fracturing has enabled the production of a natural gas resource that was previously unrecoverable. Estimates of the size of the resource indicate that shale gas has the potential to supply decades of domestically produced natural gas. Yet there are challenges surrounding the production of shale gas that have not yet been solved. The economic viability of the shale gas resources has recently come into question. This study uses a discounted cash flow economic model to evaluate the breakeven price of natural gas wells drilled in 7 major U.S. shale formations from 2005 to 2012. The breakeven price is the wellhead gas price that produces a 10% internal rate of return. The results of the economic analysis break down the breakeven gas price by year and shale play, along with P20 and P80 gas prices to illustrate the variability present. Derived vintage supply curves illustrate the volume of natural gas that was produced economically for a range of breakeven prices. Historic Natural Gas Futures Prices are used as a metric to determine the volumes and percentage of total yearly production that was produced at or below the Futures Price of each vintage year. From 2005 to 2008, the total production of shale gas resulted in a net profit for operators. A drop in price in 2009 resulted in a net loss for producers from 2009 to 2012. In 2012, only 26.5% of the total gas volume produced was produced at or below the 2012 Natural Gas Futures Price.
by Christopher D. Hammond.
S.B.
Tavakkoli, Sakineh. "A Systems-level Approach for Integrated Shale Gas Wastewater Management." Thesis, University of Pittsburgh, 2019. http://pqdtopen.proquest.com/#viewpdf?dispub=13819974.
Повний текст джерелаEconomic benefits of shale gas production in addition to its potential for enabling energy security are driving the strategic development of unconventional natural gas in the U.S. However, shale gas production poses potential detrimental impacts on the surrounding ecosystems. In particular, sustainable management of high salinity wastewater is one of the critical challenges facing shale gas industry. While recycling shale gas wastewater is a practical short-term solution to minimize total water use in the fracturing process it may not be a viable strategy from a long-term management perspective. Moreover, direct disposal into Salt Water Disposal (SWD) wells which is the most common management strategy in the U.S. is not cost effective in Marcellus shale play due to limited disposal capacity.
This work develops a systems-level optimization framework for guiding economically conscious management of high salinity wastewater in Marcellus shale play in Pennsylvania (PA) with a focus on using membrane distillation (MD) as the treatment technology. Detailed technoeconomic assessment (TEA) is performed to assess the economic feasibility of MD for treatment of shale gas wastewater with and without availability of waste heat. Natural gas compressor stations (NG CS) are chosen as potential sources of waste heat and rigorous thermodynamic models are developed to quantify the waste heat recovery opportunities from NG CS. The information from waste heat estimation and TEA are then utilized in the optimization framework for investigating the optimal management of shale gas wastewater. Wastewater management alternatives ranging from direct disposal into SWD wells to advanced centralized, decentralized, and onsite treatment options using MD are included in the optimization model.
The optimization framework is applied to four case studies in Greene and Washington counties in southwest and Susquehanna and Bradford counties in Northeast PA where major shale gas development activities take place. The results of this analysis reveal that onsite treatment of wastewater at shale gas extraction sites in addition to treating wastewater at NG CS where available waste heat could be utilized to offset the energy requirements of treatment process are the most economically promising management options that result in major economic benefit over direct disposal into SWD.
Jafary, Dargahi Hanieh. "Shale gas prospectivity studies in the Perth Basin, Western Australia." Thesis, Curtin University, 2014. http://hdl.handle.net/20.500.11937/453.
Повний текст джерелаWu, Xinyang. "Nature of Solid Organic Matters in Shale." Marietta College Honors Theses / OhioLINK, 2013. http://rave.ohiolink.edu/etdc/view?acc_num=marhonors1335652417.
Повний текст джерелаBotner, Elizabeth. "Elevated methane levels from biogenic coalbed gas in Ohio drinking water wells near shale gas extraction." University of Cincinnati / OhioLINK, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=ucin1439295392.
Повний текст джерелаVillamor, Lora Rafael. "Geomechanical Characterization of Marcellus Shale." ScholarWorks @ UVM, 2015. http://scholarworks.uvm.edu/graddis/420.
Повний текст джерелаMontgomery, Justin B. (Justin Bruce). "Characterizing shale gas and tight oil drilling and production performance variability." Thesis, Massachusetts Institute of Technology, 2015. http://hdl.handle.net/1721.1/98600.
Повний текст джерелаCataloged from PDF version of thesis.
Includes bibliographical references (pages 137-147).
Shale gas and tight oil are energy resources of growing importance to the U.S. and the world. The combination of horizontal drilling and hydraulic fracturing has enabled economically feasible production from these resources, leading to a surge in domestic oil and gas production. This is providing an economic boon and reducing reliance on foreign sources of energy in the U.S., but there are still a number of environmental, economic, and technical challenges that must be overcome to unlock the resource's full potential. One key challenge is understanding variability in individual well performance-in terms of both drilling time (a key driver of well cost) and well productivity-which has led to greater than anticipated economic risk associated with shale gas and tight oil development. Thus far, more reliable forecasting has remained elusive due to its prohibitive cost and the poorly understood nature of the resource. There is an opportunity to make use of available drilling and production data to improve the characterization of variability. For my analysis, I use publicly-available well production data and drilling reports from a development campaign. In order to characterize variability, I use a combination of graphical, statistical, and data analytics methods. For well productivity, I use probability plots to demonstrate a universality to the distribution shape, which can accurately be described as lognormal. Building on this distributional assumption, I demonstrate the utility of Bayesian statistical inference for improving estimates of the distribution parameters, which will allow companies to better anticipate resource variability and make better decisions under this uncertainty. For drilling, I characterize variability in operations by using approximate string matching to compare drilling activity sequences, leading to a metric for operational variability. Activity sequences become more similar over time, consistent with the notion of standardization. Finally, I investigate variability of drilling times as they progress along the learning curve, using probability plots again. I find some indication of lognormality, with implications for how learning in drilling should be measured and predicted. This thesis emphasizes the relevance of data analytics to characterizing performance variability across the spectrum in shale gas and tight oil. The findings also demonstrate the value of such an approach for identifying patterns of behavior, estimating future variability, and guiding development strategies.
by Justin B. Montgomery.
S.M. in Technology and Policy