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  • 1
    In: The Depositional Record, Wiley
    Abstract: On the Island of Samos (East Aegean region, Greece), two sedimentary basins are filled by thick continental series dated to the Late Miocene to Early Pliocene. A multidisciplinary study has been performed including (1) the definition of 21 sedimentary facies, (2) a review of the biological components and (3) carbon, oxygen and strontium stable isotope analyses. The succession is characterised by various depositional settings and hydrochemical compositions. Five main stages of basin evolution have been identified: (1) The Late Serravallian is marked by the development of alluvial fans and fan delta; (2) during the Lower Tortonian, isolated shallow lakes with variable salinity, from fresh to brackish, developed under warm and relatively humid conditions; (3) the Middle to Upper Tortonian is marked by the development of a large and deep lake with saline and alkaline waters, under colder and drier conditions; (4) the Latest Tortonian to Messinian period is represented by an ephemeral alluvial system, developed under a dry climate; (5) during the Zanclean, a palustrine and paludal wetland system, dominated by tufa carbonates, developed under moderately humid conditions. This succession is of particular interest for the reconstruction of the palaeoenvironmental evolution of the transition zone between the Mediterranean domain, and the Paratethys and circum‐Paratethys areas. The geochemical data and the presence of flora (diatoms) and fauna (gastropods) of marine affinity suggest transient ingressions of marine‐related water or groundwater inflows as early as the Lower Tortonian. The Samos succession records the complex interaction between the regional geodynamics and climate. The extensional regime of the Eastern Aegean zone generates subsidence, interrupted in the mid‐Tortonian (9 Ma) by a brief compressive event and a major exposure of the basins. Furthermore, the Late Miocene progressive aridification, followed by a change to a more humid climate (Pliocene) is also a major driver of the sedimentation.
    Type of Medium: Online Resource
    ISSN: 2055-4877 , 2055-4877
    Language: English
    Publisher: Wiley
    Publication Date: 2023
    detail.hit.zdb_id: 2816049-6
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  • 2
    Online Resource
    Online Resource
    Canadian Society of Petroleum Geologists ; 2015
    In:  Bulletin of Canadian Petroleum Geology Vol. 63, No. 4 ( 2015-12), p. 277-286
    In: Bulletin of Canadian Petroleum Geology, Canadian Society of Petroleum Geologists, Vol. 63, No. 4 ( 2015-12), p. 277-286
    Type of Medium: Online Resource
    ISSN: 0007-4802
    Language: English
    Publisher: Canadian Society of Petroleum Geologists
    Publication Date: 2015
    detail.hit.zdb_id: 2179258-6
    SSG: 13
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  • 3
    In: Journal of Geodynamics, Elsevier BV, Vol. 101 ( 2016-11), p. 5-29
    Type of Medium: Online Resource
    ISSN: 0264-3707
    Language: English
    Publisher: Elsevier BV
    Publication Date: 2016
    detail.hit.zdb_id: 595646-8
    detail.hit.zdb_id: 1494790-0
    SSG: 16,13
    SSG: 13
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  • 4
    Online Resource
    Online Resource
    Society of Exploration Geophysicists ; 2019
    In:  GEOPHYSICS Vol. 84, No. 4 ( 2019-07-01), p. WA43-WA57
    In: GEOPHYSICS, Society of Exploration Geophysicists, Vol. 84, No. 4 ( 2019-07-01), p. WA43-WA57
    Abstract: Carbonate formations are highly heterogeneous, and the velocity-porosity relationships are controlled by various microstructural parameters, such as the types of pores and their distribution. Because diagenesis is responsible for important changes in the microstructure of carbonate rocks, we have extended the standard effective medium approach to model the impact of diagenesis on the carbonate elastic properties through a step-by-step effective medium modeling. Two different carbonate rocks deposited, respectively, in lacustrine and marine environments are considered in this study. The first key step is the characterization of the diagenesis, which affected the two studied carbonate sample sets. Effective medium models integrating all of the geologic information accessible from petrographic analysis are then built. The evolution of the microstructural parameters during diagenesis is thoroughly constrained based on an extensive experimental data set, including X-ray diffraction analysis, different porosimetry methods, and ultrasonic velocity measurements. A new theoretical approach including two sources of compliance is developed to model the specific behavior of carbonates. A compliant interface is introduced around the main carbonate grains to represent grain contacts and the different pore scales are taken into account through multiscale modeling. Finally, direct calculations with the model provide elastic wave velocities representative of the different diagenetic stages. An extrapolation to permeability evolution is also introduced. This approach allows the identification of the acoustic signature of specific diagenetic events, such as dolomitization, dissolution, or cementation, and the assessment of their impact on the elastic properties of carbonates.
    Type of Medium: Online Resource
    ISSN: 0016-8033 , 1942-2156
    RVK:
    Language: English
    Publisher: Society of Exploration Geophysicists
    Publication Date: 2019
    detail.hit.zdb_id: 2033021-2
    detail.hit.zdb_id: 2184-2
    SSG: 16,13
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  • 5
    Online Resource
    Online Resource
    Society of Exploration Geophysicists ; 2011
    In:  The Leading Edge Vol. 30, No. 12 ( 2011-12), p. 1392-1398
    In: The Leading Edge, Society of Exploration Geophysicists, Vol. 30, No. 12 ( 2011-12), p. 1392-1398
    Abstract: The porosity of igneous rocks is usually very small, although for some basalts it can be nonnegligible due to gas exsolution. In the case of glass, it is vanishingly small. Why is it of any interest to look at this kind of material from the point of view of rock physics? Two series of reasons indeed motivate such investigations.
    Type of Medium: Online Resource
    ISSN: 1070-485X , 1938-3789
    Language: English
    Publisher: Society of Exploration Geophysicists
    Publication Date: 2011
    detail.hit.zdb_id: 1221792-X
    detail.hit.zdb_id: 2083479-2
    SSG: 16,13
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  • 6
    Online Resource
    Online Resource
    Society of Exploration Geophysicists ; 2015
    In:  Interpretation Vol. 3, No. 4 ( 2015-11-01), p. SAC1-SAC7
    In: Interpretation, Society of Exploration Geophysicists, Vol. 3, No. 4 ( 2015-11-01), p. SAC1-SAC7
    Abstract: Many geophysical studies in reservoir characterization focus on the variations in the elastic properties of rocks. They commonly involve seismic data, which are processed in terms of seismic attributes. These processed data still have to be related to the physical properties of the rock mass and the fluids saturating the pore space. This need motivated the development of research projects based upon the effective medium theory (EMT). We have used the EMT to infer porosity and also fracture data from seismic impedances in part of the Fort Worth Basin, Texas. The main idea was to take advantage of the available impedances to characterize porosity in terms of equant pores and cracks. We then focused on the volume fraction of spherical pores and crack density. Shortly thereafter, we developed an effective medium (EM) model that provided numerical responses for seismic impedances. These responses were then compared to the impedances obtained from stratigraphic inversion. The overall procedure consisted in adjusting the input parameters of the EMT model, which were the spherical porosity and the crack density, to minimize the impedance mismatch. Our case study involved two limestone formations of the Fort Worth Basin (the Marble Falls and Ellenburger Formations) and one shaly formation (the Barnett Shale). The results are promising — The EMT turns out to be a very useful tool to explain reservoir and geophysical data in terms of microstructural properties, in particular, for fractured reservoirs.
    Type of Medium: Online Resource
    ISSN: 2324-8858 , 2324-8866
    Language: English
    Publisher: Society of Exploration Geophysicists
    Publication Date: 2015
    detail.hit.zdb_id: 2741968-X
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  • 7
    Online Resource
    Online Resource
    Society of Exploration Geophysicists ; 2017
    In:  GEOPHYSICS Vol. 82, No. 4 ( 2017-07-01), p. M67-M80
    In: GEOPHYSICS, Society of Exploration Geophysicists, Vol. 82, No. 4 ( 2017-07-01), p. M67-M80
    Abstract: The accurate inference of reservoir properties such as porosity and permeability is crucial in reservoir characterization for oil and gas exploration and production as well as for other geologic applications. In most cases, direct measurements of those properties are done in wells that provide high vertical resolution but limited lateral coverage. To fill this gap, geophysical methods can often offer data with dense 3D coverage that can serve as proxy for the variable of interest. All the information available can then be integrated using multivariate geostatistical methods to provide stochastic or deterministic estimate of the reservoir properties. Our objective is to generate multiple scenarios of porosity at different scales, considering four formations of the Fort Worth Basin altogether and then restricting the process to the Marble Falls limestones. Under the hypothesis that a statistical relation between 3D seismic attributes and porosity can be inferred from well logs, a Bayesian sequential simulation (BSS) framework proved to be an efficient approach to infer reservoir porosity from an acoustic impedance cube. However, previous BBS approaches only took two variables upscaled at the resolution of the seismic data, which is not suitable for thin-bed reservoirs. We have developed three modified BSS algorithms that better adapt the BSS approach for unconventional reservoir petrophysical properties estimation from deterministic prestack seismic inversion. A methodology that includes a stochastic downscaling procedure is built and one that integrates two secondary downscaled constraints to the porosity estimation process. Results suggest that when working at resolution higher than surface seismic, it is better to execute the workflow for each geologic formation separately.
    Type of Medium: Online Resource
    ISSN: 0016-8033 , 1942-2156
    RVK:
    Language: English
    Publisher: Society of Exploration Geophysicists
    Publication Date: 2017
    detail.hit.zdb_id: 2033021-2
    detail.hit.zdb_id: 2184-2
    SSG: 16,13
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  • 8
    Online Resource
    Online Resource
    Society of Exploration Geophysicists ; 2019
    In:  GEOPHYSICS Vol. 84, No. 4 ( 2019-07-01), p. WA97-WA113
    In: GEOPHYSICS, Society of Exploration Geophysicists, Vol. 84, No. 4 ( 2019-07-01), p. WA97-WA113
    Abstract: Carbonate formations are characterized by multiscale heterogeneities that control their acoustic response and flow properties. At the laboratory scale, carbonate rocks do not indicate a strong correlation between P- and S-wave velocities and porosity. The velocity disparities between carbonates of similar mineralogy and porosity result from different microstructures derived from their sedimentary facies and subsequent diagenetic transformations. The still-discussed applicability of Biot-Gassmann’s equation for fluid substitution in carbonate rocks remains another key issue. We have developed an integrated experimental workflow that allows a consistent checking of the applicability of Biot-Gassmann’s equation and provides key geologic and microstructural information to understand the petroacoustic signature of carbonate rocks. The defined approach is based on the phase-velocity measurements performed in liquid-saturated conditions using polar and nonpolar fluids. It allows the identification of the whole set of parameters required by Biot-Gassmann’s equation including the bulk modulus of the solid matrix. This approach is implemented on samples representative of two different carbonate formations deposited in lacustrine and marine environments, respectively. The obtained results demonstrate the applicability of Biot-Gassmann’s equation for the two studied carbonate families and indicate the link between their petroacoustic signature and diagenetic history.
    Type of Medium: Online Resource
    ISSN: 0016-8033 , 1942-2156
    RVK:
    Language: English
    Publisher: Society of Exploration Geophysicists
    Publication Date: 2019
    detail.hit.zdb_id: 2033021-2
    detail.hit.zdb_id: 2184-2
    SSG: 16,13
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  • 9
    In: Marine and Petroleum Geology, Elsevier BV, Vol. 93 ( 2018-05), p. 182-204
    Type of Medium: Online Resource
    ISSN: 0264-8172
    Language: English
    Publisher: Elsevier BV
    Publication Date: 2018
    detail.hit.zdb_id: 1494910-6
    detail.hit.zdb_id: 48427-1
    SSG: 13
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  • 10
    In: Tectonophysics, Elsevier BV, Vol. 693 ( 2016-12), p. 143-156
    Type of Medium: Online Resource
    ISSN: 0040-1951
    Language: English
    Publisher: Elsevier BV
    Publication Date: 2016
    detail.hit.zdb_id: 2012830-7
    detail.hit.zdb_id: 204243-5
    SSG: 16,13
    SSG: 13
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