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Relevant bibliographies by topics / Sedimentary rocks Fluid dynamics

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Academic literature on the topic 'Sedimentary rocks Fluid dynamics'

Author: Grafiati

Published: 4 June 2021

Last updated: 1 February 2022

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Journal articles on the topic "Sedimentary rocks Fluid dynamics"

1

Prezbindowski, Dennis R., and J. Bryan Tapp. "Dynamics of fluid inclusion alteration in sedimentary rocks: a review and discussion." Organic Geochemistry 17, no. 2 (January 1991): 131–42. http://dx.doi.org/10.1016/0146-6380(91)90071-q.

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2

Zhao, Luanxiao, Yirong Wang, Qiuliang Yao, Jianhua Geng, Hui Li, Hemin Yuan, and De-hua Han. "Extended Gassmann equation with dynamic volumetric strain: Modeling wave dispersion and attenuation of heterogeneous porous rocks." GEOPHYSICS 86, no. 3 (April 27, 2021): MR149—MR164. http://dx.doi.org/10.1190/geo2020-0395.1.

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Sedimentary rocks are often heterogeneous porous media inherently containing complex distributions of heterogeneities (e.g., fluid patches and cracks). Understanding and modeling their frequency-dependent elastic and adsorption behaviors is of great interest for subsurface rock characterization from multiscale geophysical measurements. The physical parameter of dynamic volumetric strain (DVS) associated with wave-induced fluid flow is proposed to understand the common physics and connections behind known poroelastic models for modeling dispersion behaviors of heterogeneous rocks. We have derived the theoretical formulations of DVS for patchy saturated rock at the mesoscopic scale and cracked porous rock at microscopic grain scales, essentially embodying the wave-induced fluid-pressure relaxation process. By incorporating DVS into the classic Gassmann equation, a simple but practical “dynamic equivalent” modeling approach, the extended Gassmann equation, is developed to characterize the dispersion and attenuation of complex heterogeneous rocks at nonzero frequencies. Using the extended Gassmann equation, the effect of microscopic or mesoscopic heterogeneities with complex distributions on the wave dispersion and attenuation signatures can be captured. Our theoretical framework provides a simple and straightforward analytical methodology to calculate wave dispersion and attenuation in porous rocks with multiple sets of heterogeneities exhibiting complex characteristics. We also demonstrate that, with the appropriate consideration of multiple crack sets and complex fluid patches distribution, the modeling results can better interpret the experimental data sets of dispersion and attenuation for heterogeneous porous rocks.

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Digby, P. J., and K. Walton. "Wave Propagation Through Elastically-Anisotropic Fluid-Saturated Porous Rocks." Journal of Applied Mechanics 56, no. 4 (December 1, 1989): 744–50. http://dx.doi.org/10.1115/1.3176167.

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An elastically-anisotropic sedimentary rock is modeled by a simple cubic packing of identical, contacting spherical particles. The connected pore space is filled with an inviscid, compressible fluid. A set of averaged equations is derived to relate the constitutive and dynamic coupling coefficients, and hence also the effective wave speeds in any given direction explicitly to the microstructural properties of the rock considered. Simple, explicit results are obtained when the propagation of either a purely longitudinal or a purely transverse wave is considered.

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Angus, Doug A., James P. Verdon, Quentin J. Fisher, and J. M. Kendall. "Exploring trends in microcrack properties of sedimentary rocks: An audit of dry-core velocity-stress measurements." GEOPHYSICS 74, no. 5 (September 2009): E193—E203. http://dx.doi.org/10.1190/1.3183940.

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Rock-physics models are used increasingly to link fluid and mechanical deformation parameters for dynamic elastic modeling. We explore the input parameters of an analytical stress-dependent rock-physics model. To do this, we invert for the stress-dependent microcrack parameters of more than 150 sedimentary rock velocity-stress core measurements taken from a literature survey. The inversion scheme is based on a microstructural effective-medium formulation defined by a second-rank crack-density tensor (scalar crack model) or by a second- and fourth-rank crack-density tensor (joint inversion model). Then the inversion results are used to explore and predict the stress-dependent elastic behavior of various sedimentary rock lithologies using an analytical microstructural rock-physics model via the initial modelinput parameters: initial crack aspect ratio and initial crack density. Estimates of initial crack aspect ratio are consistent among most lithologies with a mean of 0.0004, but for shales they differ up to several times in magnitude with a mean of 0.001. Estimates of initial aspect ratio are relatively insensitive to the inversion method, although the scalar crack inversion becomes less reliable at low values of normal-to-tangential crack compliance ratio [Formula: see text]. Initial crack density is sensitive to the degree of damage as well as the inversion procedure. An important implication is that the fourth-rank crack-density term is not necessarily negligible for most sedimentary rocks and evaluation of this term or [Formula: see text] is necessary for accurate prediction of initial crack density. This is especially important because recent studies suggest that [Formula: see text] can indicate fluid content in cracks.

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Holford, Simon P., Nick Schofield, and Peter Reynolds. "Subsurface fluid flow focused by buried volcanoes in sedimentary basins: Evidence from 3D seismic data, Bass Basin, offshore southeastern Australia." Interpretation 5, no. 3 (August 31, 2017): SK39—SK50. http://dx.doi.org/10.1190/int-2016-0205.1.

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There is growing evidence that intrusive magmatic bodies such as sills and dikes can influence the migration of fluids in the deep subsurface. This influence is largely due to permeability contrasts with surrounding sedimentary rocks or because of interconnected open fractures within and around intrusions acting as conduits for migrating fluids. The role of buried volcanoes in influencing crossstratal fluid migration in sedimentary basins is less well-established. However, several studies have highlighted spatial linkages between extinct hydrothermal vent complexes and fluid seepage, suggesting that buried extrusive features can also influence subsurface fluid-flow pathways, potentially leading to migration of hydrocarbon fluids between the source and reservoir. We have developed 3D seismic reflection data from the Bass Basin in offshore southeastern Australia that image an early Miocene volcanic complex with exceptional clarity. This volcanic complex is now buried by [Formula: see text] of younger sediments. The largest volcano within this complex is directly overlain by a vertical feature interpreted to be a fluid escape pipe, which extends vertically for approximately 700 m across the late Miocene-Pliocene succession. We suggest that the buried volcanic complex was able to focus vertical fluid migration to the base of the pipe because its bulk permeability was higher than that of the overlying claystone sequence. The fluid escape pipe may have initiated through either (1) hydraulic fracturing following fluid expulsion from a deep, overpressured subvolcanic source region, (2) differential compaction and doming of the overlying claystones, or (3) a combination of these processes. Our results suggest a hitherto unrecognized role for buried volcanoes in influencing dynamic subsurface processes in sedimentary basins. In particular, our study highlights that buried volcanoes may facilitate cross-stratal migration of hydrocarbons from source to reservoir, or through sealing horizons.

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Radkovets, Nataliya, Kostyantyn Hrygorchuk, Yuriy Koltun, Volodymyr Hnidets, Ihor Popp, Marta Moroz, Yuliya Hayevska, et al. "Dynamics of lithogenesis of Phanerozoic sedimentary sequence of the Carpathian-Black Sea region in the aspect of their oil- and gas-bearing potential." Geology and Geochemistry of Combustible Minerals 1-2, no. 183-184 (2021): 60–75. http://dx.doi.org/10.15407/ggcm2021.01-02.060.

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The objective of this work was to study the environments and processes of ancient sedimentation in the epi- and mesopelagic basins of the Carpathian-Black Sea region and to clarify the conditions of oil and gas basins formation within the study region as well as the main aspects of hydrocarbon generation. The burial history of the basins, some aspects of their fluid regime, issues of lithogenetic record, features of transformation of sedimentary basins into the rock-formation basins and the development of the latter during the Phanerozoic are considered. The spatial and temporal peculiarities of the evolution of epi-mesopelogic systems and their influence on the formation of oil- and gas-bearing strata within the Carpathian-Black Sea region have been studied. It has been established that in the sedimentary basins of the Carpathian-Black Sea continental margin of the Tethys Ocean during the long geological history the different intensity structural and morphological changes took place: changes of the subsidence rate of the basin bottom, inversion uplifts, sedimentation pauses, deformation of the sedimentary fill. This was reflected both in the peculiarities of the development of sedimentary environments and in the processes of substance differentiation with the formation of certain post-sedimentary mineral-structural parageneses. It was proved that discrete processes of differentiated compaction and defluidization of sediments cause a number of deformation phenomena, which can be reflected in the features of the morphology of the sedimentary basin bottom, influencing the nature of sediment transportation and accumulation. On the basis of the conducted investigations a number of practical results were obtained which will allow forming new approaches to criteria of hydrocarbons prospecting, in particular the lithophysical aspect which is concentrated on the reservoir properties of rocks; sedimentary reconstructions and the diversity of cyclicity of the studied sediments as a factor of the establishment of prospective areas, reconstruction of the burial history, which provides an information on the state of transformation of organic matter and hydrocarbons, and therefore the range of prospective depths for oil and gas occurrence.

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Claes, Steven, Fadi H. Nader, and Souhail Youssef. "Coupled experimental/numerical workflow for assessing quantitative diagenesis and dynamic porosity/permeability evolution in calcite-cemented sandstone reservoir rocks." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 73 (2018): 36. http://dx.doi.org/10.2516/ogst/2018027.

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Some of the world best hydrocarbon reservoirs (carbonates and siliciclastics) are also believed to be valuable for subsurface storage of CO2 and other fluids. Yet, these reservoirs are heterogeneous in terms of their mineralogy and flow properties, at varying spatial-temporal scales. Therefore, predicting the porosity and permeability (flow properties) evolution of carbonates and sandstones remains a tedious task. Diagenesis refers to the alteration of sedimentary rocks through geologic time, mainly due to rock-fluid interactions. It affects primarily the flow properties (porosity and permeability) of already heterogeneous reservoir rocks. In this project a new approach is proposed to calculate/quantify the influence of diagenetic phases (e.g. dissolution, cement plugging) on flow properties of typical sandstone reservoir rocks (Early Jurassic Luxembourg Formation). A series of laboratory experiments are performed in which diagenetic phases (e.g. pore blocking calcite cement in sandstone) are selectively leached from pre-studied samples, with the quantification of the petrophysical characteristics with and without cement to especially infer permeability evolution. Poorly and heavily calcite-cemented sandstone samples, as well as some intermediate cemented samples were used. The results show a distinctive dissolution pattern for different cementation grades and varying Representative Elementary Volumes (REVs). These conclusions have important consequences for upscaling diagenesis effects on reservoirs, and the interpretation of geochemical modelling results of diagenetic processes. The same approach can be applied on other type of cements and host-rocks, and could be improved by integrating other petrophysical analyses (e.g. petroacoustic, NMR).

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Kholodov, V. N. "Thermobaric Depth Settings of Sedimentary Rock Basins and Their Fluid Dynamics: Communication 2. Superhigh Pressures and Mud Volcanoes." Lithology and Mineral Resources 54, no. 1 (January 2019): 38–52. http://dx.doi.org/10.1134/s0024490219010036.

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Kholodov, V. N. "Thermobaric depth settings of sedimentary rock basins and their fluid dynamics: Сommunication 2. Superhigh pressures and mud volcanoes." Литология и полезные ископаемые 1, no. 1 (February 16, 2019): 44–59. http://dx.doi.org/10.31857/s0024-497x2019144-59.

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The article discusses the patterns of placement of mud volcanoes, their spatial connection with tectonic faults, anticlinal uplifts, oil and gas fields. The connection of mud volcanic activity with ultrahigh pressures arising in the clay strata of the stratisphere as a result of phase transformations of clay minerals and organic matter is argued. The role of earthquakes in the formation of fractured clays, increasing their permeability and the formation of mud crates is emphasized. On the example of the mud volcano Aligula (Turkmenistan), the processes of dilution of sandstones and clays, the formation of volcanic mud-crates are considered.

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Kholodov, V. N. "Thermobaric depth settings of sedimentary rock basins and their fluid dynamics: Communication 3. Superhigh pressures in the stratisphere and salt diapirs." Литология и полезные ископаемые, no. 2 (March 28, 2019): 130–48. http://dx.doi.org/10.31857/s0024-497x20192130-148.

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The article discusses the patterns of location and the conditions for the formation of salt diapirs. Their formation is associated with thick salt cjmpleses in which phase transformations within closed physicochemical systems form ultrahigh pressures. The latter are the cause of the flow of salts and their penetration through tectonic cracks and fractures to the earth's surface. The similarity of the formation of salt diapirs and mud volcanoes is emphasized. The possibility of the influence of ultrahigh pressures on the autonomous folding of the sedimentary cover is assumed.

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Dissertations / Theses on the topic "Sedimentary rocks Fluid dynamics"

1

Shakeel, Ahmed. "The effect of oriented fractures on elastic wave velocities, attenuation and fluid permeabilities of sandstones." Thesis, Imperial College London, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.318186.

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Astakhov, Dmitriy Konstantinovich. "Permeability evolution as a result of fluid-rock interaction." Diss., Georgia Institute of Technology, 2000. http://hdl.handle.net/1853/21693.

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Adeleye, James Olugbade. "Numerical characterisation of fluid flow in unconventional shale rocks." Thesis, University of Aberdeen, 2018. http://digitool.abdn.ac.uk:80/webclient/DeliveryManager?pid=238833.

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Beasley, Justin M. "Geochemistry and fluid evolution of a carboniferous-hosted sphalerite breccia deposit, Isle of Man." Diss., Columbia, Mo. : University of Missouri-Columbia, 2008. http://hdl.handle.net/10355/6524.

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Thesis (M.S.)--University of Missouri-Columbia, 2008.
The entire dissertation/thesis text is included in the research.pdf file; the official abstract appears in the short.pdf file (which also appears in the research.pdf); a non-technical general description, or public abstract, appears in the public.pdf file. Title from title screen of research.pdf file (viewed July 14, 2009). Includes bibliographical references.

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Manrique-Florindez, Jorge Luis. "A detailed study of geometric factors for probe permeameter measurements on heterogeneous and anisotropic rocks /." Access abstract and link to full text, 1994. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9418376.

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Zhang, Wenbing. "A method and program for quantitative description of fracture data and fracture data extrapolation from scanline or wellbore data /." May be available electronically:, 2001. http://proquest.umi.com/login?COPT=REJTPTU1MTUmSU5UPTAmVkVSPTI=&clientId=12498.

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Kirste, Dirk Marten. "Compositional variation in formation fluids and their relation to fluid flow and water-rock interaction in Devonian to Lower Cretaceous sedimentary rocks of southern Alberta." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2001. http://www.collectionscanada.ca/obj/s4/f2/dsk3/ftp05/nq64868.pdf.

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Teimoori, Sangani Ahmad Petroleum Engineering Faculty of Engineering UNSW. "Calculation of the effective permeability and simulation of fluid flow in naturally fractured reservoirs." Awarded by:University of New South Wales. School of Petroleum Engineering, 2005. http://handle.unsw.edu.au/1959.4/22408.

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This thesis is aimed to calculate the effective permeability tensor and to simulate the fluid flow in naturally fractured reservoirs. This requires an understanding of the mechanisms of fluid flow in naturally fractured reservoirs and the detailed properties of individual fractures and matrix porous media. This study has been carried out to address the issues and difficulties faced by previous methods; to establish possible answers to minimise the difficulties; and hence, to improve the efficiency of reservoir simulation through the use of properties of individual fractures. The methodology used in this study combines several mathematical and numerical techniques like the boundary element method, periodic boundary conditions, and the control volume mixed finite element method. This study has contributed to knowledge in the calculation of the effective permeability and simulation of fluid flow in naturally fractured reservoirs through the development of two algorithms. The first algorithm calculates the effective permeability tensor by use of properties of arbitrary oriented fractures (location, size and orientation). It includes all multi-scaled fractures and considers the appropriate method of analysis for each type of fracture (short, medium and long). In this study a characterisation module which provides the detail information for individual fractures is incorporated. The effective permeability algorithm accounts for fluid flows in the matrix, between the matrix and the fracture and disconnected fractures on effective permeability. It also accounts for the properties of individual fractures in calculation of the effective permeability tensor. The second algorithm simulates flow of single-phase fluid in naturally fractured reservoirs by use of the effective permeability tensor. This algorithm takes full advantage of the control volume discretisation technique and the mixed finite element method in calculation of pressure and fluid flow velocity in each grid block. It accounts for the continuity of flux between the neighbouring blocks and has the advantage of calculation of fluid velocity and pressure, directly from a system of first order equations (Darcy???s law and conservation of mass???s law). The application of the effective permeability tensor in the second algorithm allows us the simulation of fluid flow in naturally fractured reservoirs with large number of multi-scale fractures. The fluid pressure and velocity distributions obtained from this study are important and can considered for further studies in hydraulic fracturing and production optimization of NFRs.

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Soltanian, Mohamad Reza. "RELATING REACTIVE TRANSPORT TO HIERARCHICAL AND MULTISCALE SEDIMENTARY ARCHITECTURE." Wright State University / OhioLINK, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=wright1428521270.

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Guilhaumou, Nicole. "Apport de l'étude des inclusions fluides intracristallines à la diagénèse, l'anchizone et les minéralisations associées." Orléans, 1989. http://www.theses.fr/1989ORLE2010.

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Etudes methodologiques concernant l'analyse non destructive des fractions volatiles et des hydrocarbures liquides pieges dans les inclusions fluides par des methodes ponctuelles et non destructives comme la microspectrometrie infra-rouge et raman et la microfluorometrie, et d'autre part la mesure des changements de volume et de composition lors de surchauffes sous pression de confinement dans les inclusions de la fluorine. Les apports originaux des etudes d'inclusions fluides a la connaissance des circulations de fluides dans les bassins sedimentaires et pour la definition des conditions de depot des gites mineraux dans des contextes geologiques differents sont montres. Trois principaux types de solutions peuvent etre definis: les eaux connees de la diagenese faible a moyennement salines; les saumures d'origine diapirique; les solutions qui resultent d'un melange entre eaux connees et solutions hydrothermales

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Books on the topic "Sedimentary rocks Fluid dynamics"

1

Lee, Cheng-Haw. Fluid flow in discontinuous rocks. London: Chapman & Hall, 1993.

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Barenblatt, G. I. Theory of fluid flows through natural rocks. Dordrecht: Kluwer Academic Publishers, 1990.

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Flow and reactions in permeable rocks. Cambridge [England]: Cambridge University Press, 1991.

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Phillips, O. M. Geological fluid dynamics: Sub-surface flow and reactions. Cambridge, UK: Cambridge University Press, 2009.

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Phillips, O. M. Geological fluid dynamics: Sub-surface flow and reactions. Cambridge, UK: Cambridge University Press, 2009.

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V, Marasanova N., Nauchnyĭ sovet po problemam geologii i geokhimii nefti i gaza (Akademii︠a︡ nauk SSSR), and Institut geologii i razrabotki gori︠u︡chikh iskopaemykh (Russia), eds. Fli︠u︡idodinamicheskiĭ faktor v tektonike i neftegazonosnosti osadochnykh basseĭnov. Moskva: "Nauka", 1989.

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Peach, Colin Jack. Influence of deformation on the fluid transport properties of salt rocks. [Utrecht: Facultiet Aardwetenschappen der Rijksuniversiteit Utrecht], 1991.

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1970-, Liu Weiqun, and Chen Zhanqing 1961-, eds. Cai dong yan ti shen liu li lun. Beijing: Ke xue chu ban she, 2004.

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J, Sanderson D., ed. Numerical modelling and analysis of fluid flow and deformation of fractured rock masses. Amsterdam: Pergamon, 2002.

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Rasmussen, T. C. Fluid flow and solute transport modeling through three-dimensional networks of variably saturated discrete fractures. Washington, DC: Division of Engineering, Office of Nuclear Regulatory Research, U.S. Nuclear Regulatory Commission, 1989.

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Book chapters on the topic "Sedimentary rocks Fluid dynamics"

1

Pedersen, Tom, Magnus Wangen, and Harald Johansen. "Flow Along Fractures in Sedimentary Basins." In Fluid Flow and Transport in Rocks, 213–33. Dordrecht: Springer Netherlands, 1997. http://dx.doi.org/10.1007/978-94-009-1533-6_13.

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Bjørlykke, Knut. "Lithological Control on Fluid Flow in Sedimentary Basins." In Fluid Flow and Transport in Rocks, 15–34. Dordrecht: Springer Netherlands, 1997. http://dx.doi.org/10.1007/978-94-009-1533-6_2.

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House, Leigh S., and Roderick Flores. "Seismological Studies of a Fluid Injection in Sedimentary Rocks, East Texas." In The Mechanism of Induced Seismicity, 371–401. Basel: Birkhäuser Basel, 2002. http://dx.doi.org/10.1007/978-3-0348-8179-1_16.

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Barenblatt, G. I., V. M. Entov, and V. M. Ryzhik. "The Basic Physical Concepts and Models of Subterranean Fluid Dynamics." In Theory of Fluid Flows Through Natural Rocks, 1–56. Dordrecht: Springer Netherlands, 1990. http://dx.doi.org/10.1007/978-94-015-7899-8_1.

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Callot, Jean-Paul, Liesbeth Breesch, Nicole Guilhaumou, François Roure, Rudy Swennen, and Nadège Vilasi. "Paleo-Fluids Characterisation and Fluid Flow Modelling Along a Regional Transect in Northern United Arab Emirates (UAE)." In Lithosphere Dynamics and Sedimentary Basins: The Arabian Plate and Analogues, 177–201. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-30609-9_9.

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Zambrano, Miller, Lucia Mancini, and Emanuele Tondi. "The Use of Synchrotron-Based X-ray Microtomography for the Pore Network Quantitative and Computational Fluid Dynamics Experiments on Porous Carbonate Rocks." In Synchrotron Radiation Science and Applications, 203–17. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-72005-6_16.

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"Evolution of Sedimentary Basins and Petroleum Highlighted by the Facies of the Host Rocks and Coal." In Global Water Dynamics. CRC Press, 2004. http://dx.doi.org/10.1201/9780203025703.ch11.

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"Evolution of Sedimentary Basins and Petroleum Highlighted by the Facies of the Host Rocks and Coal." In Global Water Dynamics, 230–41. CRC Press, 2004. http://dx.doi.org/10.1201/9780203025703-21.

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Adua Awejori, Gabriel, and Mileva Radonjic. "Review of Geochemical and Geo-Mechanical Impact of Clay-Fluid Interactions Relevant to Hydraulic Fracturing." In Hydraulic Fracturing [Working Title]. IntechOpen, 2021. http://dx.doi.org/10.5772/intechopen.98881.

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Shale rocks are an integral part of petroleum systems. Though, originally viewed primarily as source and seal rocks, introduction of horizontal drilling and hydraulic fracturing technologies have essentially redefined the role of shale rocks in unconventional reservoirs. In the geological setting, the deposition, formation and transformation of sedimentary rocks are characterised by interactions between their clay components and formation fluids at subsurface elevated temperatures and pressures. The main driving forces in evolution of any sedimentary rock formation are geochemistry (chemistry of solids and fluids) and geomechanics (earth stresses). During oil and gas production, clay minerals are exposed to engineered fluids, which initiate further reactions with significant implications. Application of hydraulic fracturing in shale formations also means exposure and reaction between shale clay minerals and hydraulic fracturing fluids. This chapter presents an overview of currently available published literature on interactions between formation clay minerals and fluids in the subsurface. The overview is particularly focused on the geochemical and geomechanical impacts of interactions between formation clays and hydraulic fracturing fluids, with the goal to identify knowledge gaps and new research questions on the subject.

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Douglas, Jessica, Kenneth J. Curry, and Richard H. Bennett. "Three-Dimensional Reconstruction of Marine Clay Nano- and Microfabric: Importance to Fluid Flow Dynamics." In Sedimentary Basins: Origin, Depositional Histories, and Petroleum Systems. SEPM Society for Sedimentary Geology, 2014. http://dx.doi.org/10.5724/gcs.14.33.0426.

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Conference papers on the topic "Sedimentary rocks Fluid dynamics"

1

Wei, Wu, Li Yong, and Ma Guowei. "Discrete Modeling of Fluid Flow in Fractured Sedimentary Rocks." In 9th International Conference On Analysis of Discontinues Deformation: New Developments and Applications. Singapore: Research Publishing Services, 2009. http://dx.doi.org/10.3850/9789810844554-0028.

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Goldstein, Robert H., Sahar Mohammadi, and Andrew Michael Hollenbach. "HISTORY AND MECHANISMS OF ACTIVE FLUID FLOW THROUGH LOW-PERMEABILITY SEDIMENTARY ROCKS." In 54th Annual GSA South-Central Section Meeting 2020. Geological Society of America, 2020. http://dx.doi.org/10.1130/abs/2020sc-343778.

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Vakhnenko, Oleksiy O. "Soft-ratchet modeling of slow dynamics in the nonlinear resonant response of sedimentary rocks." In INNOVATIONS IN NONLINEAR ACOUSTICS: ISNA17 - 17th International Symposium on Nonlinear Acoustics including the International Sonic Boom Forum. AIP, 2006. http://dx.doi.org/10.1063/1.2210331.

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Vellinga, A. J., M. J. B. Cartigny, E. W. M. Hansen, P. J. Tallinga, M. A. Clare, E. J. Sumner, and J. T. Eggenhuisen. "Process-based Modelling of Turbidity Currents - From Computational Fluid-dynamics to Depositional Signature." In Second Conference on Forward Modelling of Sedimentary Systems. Netherlands: EAGE Publications BV, 2016. http://dx.doi.org/10.3997/2214-4609.201600374.

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Marion, D., P. Rowbotham, E. Insalaco, P. Swaby, and B. Michel. "Static reservoir properties and uncertainties from seismic inversion and sedimentary modelling." In EAGE/SEG Research Workshop on Reservoir Rocks - Understanding reservoir rock and fluid property distributions - measurement, modelling and applications. European Association of Geoscientists & Engineers, 2001. http://dx.doi.org/10.3997/2214-4609.201406728.

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Cadoret, T., J. Marrauld, and L. Jacquelin-Valle. "From 2D sedimentary model to synthetic seismic section - a case study." In EAGE/SEG Research Workshop on Reservoir Rocks - Understanding reservoir rock and fluid property distributions - measurement, modelling and applications. European Association of Geoscientists & Engineers, 2001. http://dx.doi.org/10.3997/2214-4609.201406729.

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Ndonhong, Vanessa, Ding Zhu, and Alfred Daniel Hill. "Acid Jetting on Carbonate Rocks: A Computational Fluid Dynamics Study at Laboratory Scale." In SPE Europec featured at 80th EAGE Conference and Exhibition. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/190849-ms.

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Satti, Rajani, Stephen N. Zuklic, Derek Bale, Nils Koliha, Andrew Fager, Gana Balasubramanian, Bernd Crouse, and David Freed. "Advanced Analysis of Clean-Up and Productivity from Perforated Rocks Using Computational Fluid Dynamics." In SPE Western Regional Meeting. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/190113-ms.

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Ridde, August R., and John S. Oldow. "STRAIN IMPLICATIONS FOR THE FORMATION OF FLUID ESCAPE STRUCTURES DURING SYNEXTENSIONAL DEPOSITION OF MIOCENE VOLCANICLASTIC SEDIMENTARY ROCKS IN THE VOLCANIC HILLS, SOUTHWEST NEVADA." In GSA Annual Meeting in Seattle, Washington, USA - 2017. Geological Society of America, 2017. http://dx.doi.org/10.1130/abs/2017am-303487.

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A. Barton, Colleen, and Colleen A. Barton. "Fractures, Fluid Flow And In Situ Stress Indicators In Shallow Sedimentary Rocks At The Proposed Wake/Chatham Low Level Nuclear Waste Disposal Site, North Carolina." In 9th EEGS Symposium on the Application of Geophysics to Engineering and Environmental Problems. European Association of Geoscientists & Engineers, 1996. http://dx.doi.org/10.3997/2214-4609-pdb.205.1996_043.

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Reports on the topic "Sedimentary rocks Fluid dynamics"

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Guidati, Gianfranco, and Domenico Giardini. Joint synthesis “Geothermal Energy” of the NRP “Energy”. Swiss National Science Foundation (SNSF), February 2020. http://dx.doi.org/10.46446/publication_nrp70_nrp71.2020.4.en.

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Abstract:

Near-to-surface geothermal energy with heat pumps is state of the art and is already widespread in Switzerland. In the future energy system, medium-deep to deep geothermal energy (1 to 6 kilometres) will, in addition, play an important role. To the forefront is the supply of heat for buildings and industrial processes. This form of geothermal energy utilisation requires a highly permeable underground area that allows a fluid – usually water – to absorb the naturally existing rock heat and then transport it to the surface. Sedimentary rocks are usually permeable by nature, whereas for granites and gneisses permeability must be artificially induced by injecting water. The heat gained in this way increases in line with the drilling depth: at a depth of 1 kilometre, the underground temperature is approximately 40°C, while at a depth of 3 kilometres it is around 100°C. To drive a steam turbine for the production of electricity, temperatures of over 100°C are required. As this requires greater depths of 3 to 6 kilometres, the risk of seismicity induced by the drilling also increases. Underground zones are also suitable for storing heat and gases, such as hydrogen or methane, and for the definitive storage of CO2. For this purpose, such zones need to fulfil similar requirements to those applicable to heat generation. In addition, however, a dense top layer is required above the reservoir so that the gas cannot escape. The joint project “Hydropower and geo-energy” of the NRP “Energy” focused on the question of where suitable ground layers can be found in Switzerland that optimally meet the requirements for the various uses. A second research priority concerned measures to reduce seismicity induced by deep drilling and the resulting damage to buildings. Models and simulations were also developed which contribute to a better understanding of the underground processes involved in the development and use of geothermal resources. In summary, the research results show that there are good conditions in Switzerland for the use of medium-deep geothermal energy (1 to 3 kilometres) – both for the building stock and for industrial processes. There are also grounds for optimism concerning the seasonal storage of heat and gases. In contrast, the potential for the definitive storage of CO2 in relevant quantities is rather limited. With respect to electricity production using deep geothermal energy (> 3 kilometres), the extent to which there is potential to exploit the underground economically is still not absolutely certain. In this regard, industrially operated demonstration plants are urgently needed in order to boost acceptance among the population and investors.

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