Reservoir Model Design

Ringrose, Philip; Bentley, Mark

doi:10.1007/978-94-007-5497-3

Cited by 139 publications

(52 citation statements)

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“…This brings the usual question of the representativeness of plug measurements for reservoir characterization (Corbett et al, 2015;Ringrose et al, 2008). Indeed, by analogy, several authors show that multiscale geological medium implies different fluid-flow properties that has to be related to multiscale REVs (Claes, 2015;Corbett, 2009;Nordahl & Ringrose, 2008;Ringrose et al, 2008;Ringrose & Bentley, 2015). Similarly here, the upscaling of elastic properties of lacustrine carbonates shows that we need to take into account several scales of rock heterogeneities, from microscopic to megascopic scales, including pores, cracks, and fractures, following thus the early works of Stierman and Kovach (1979) as well as Moos and Zoback (1983).…”

Section: How To Define the Elastic Properties Of Carbonates At Differmentioning

confidence: 99%

Upscaling of Elastic Properties in Carbonates: A Modeling Approach Based on a Multiscale Geophysical Data Set

et al. 2019

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Linking ultrasonic measurements made on samples, with sonic logs and seismic subsurface data, is a key challenge for the understanding of carbonate reservoirs. To deal with this problem, we investigate the elastic properties of dry lacustrine carbonates. At one study site, we perform a seismic refraction survey (100 Hz), as well as “sonic” (54 kHz) and ultrasonic (250 kHz) measurements directly on outcrop and ultrasonic measurements on samples (500 kHz). By comparing the median of each data set, we show that the P wave velocity decreases from laboratory to seismic scale. Nevertheless, the median of the sonic measurements acquired on outcrop surfaces seems to fit with the seismic data, meaning that sonic acquisition may be representative of seismic scale. To explain the variations due to upscaling, we relate the concept of representative elementary volume with the wavelength of each scale of study. Indeed, with upscaling, the wavelength varies from millimetric to pluri‐metric. This change of scale allows us to conclude that the behavior of P wave velocity is due to different geological features (matrix porosity, cracks, and fractures) related to the different wavelengths used. Based on effective medium theory, we quantify the pore aspect ratio at sample scale and the crack/fracture density at outcrop and seismic scales using a multiscale representative elementary volume concept. Results show that the matrix porosity that controls the ultrasonic P wave velocities is progressively lost with upscaling, implying that crack and fracture porosity impacts sonic and seismic P wave velocities, a result of paramount importance for seismic interpretation based on deterministic approaches.

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Section: How To Define the Elastic Properties Of Carbonates At Differmentioning

confidence: 99%

Upscaling of Elastic Properties in Carbonates: A Modeling Approach Based on a Multiscale Geophysical Data Set

et al. 2019

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“…This requires covering several spatial scales. Multiscale flow modelling is defined as any method used to explicitly represent the flow properties at more than one scale within a reservoir [31]. Reservoir models typically cover at least twelve orders of magnitude, ranging from pore to core to interwell to full field simulations.…”

Section: Introductionmentioning

confidence: 99%

Lattice Boltzmann Simulations of Fluid Flow in Continental Carbonate Reservoir Rocks and in Upscaled Rock Models Generated with Multiple-Point Geostatistics

Soete

Claes

et al. 2017

Geofluids

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Microcomputed tomography ( CT) and Lattice Boltzmann Method (LBM) simulations were applied to continental carbonates to quantify fluid flow. Fluid flow characteristics in these complex carbonates with multiscale pore networks are unique and the applied method allows studying their heterogeneity and anisotropy. 3D pore network models were introduced to single-phase flow simulations in Palabos, a software tool for particle-based modelling of classic computational fluid dynamics. In addition, permeability simulations were also performed on rock models generated with multiple-point geostatistics (MPS). This allowed assessing the applicability of MPS in upscaling high-resolution porosity patterns into large rock models that exceed the volume limitations of the CT. Porosity and tortuosity control fluid flow in these porous media. Micro-and mesopores influence flow properties at larger scales in continental carbonates. Upscaling with MPS is therefore necessary to overcome volume-resolution problems of CT scanning equipment. The presented LBM-MPS workflow is applicable to other lithologies, comprising different pore types, shapes, and pore networks altogether. The lack of straightforward porosity-permeability relationships in complex carbonates highlights the necessity for a 3D approach. 3D fluid flow studies provide the best understanding of flow through porous media, which is of crucial importance in reservoir modelling.

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“…For this reason, geologists and geophysicists explore the distribution of these properties (within the reservoir model) to verify if the property modelling is appropriate or if it has spurious features (outliers) that do not agree with the well data. During these studies, they explore and compare geological attributes to identify correlations between properties and geological or petrophysical trends [RB15]. This task is even more challenging since attributes have different data types (scalar, vector, and tensor) and semantics.…”

Section: Problem Characterizationmentioning

confidence: 99%

Illustrative Multivariate Visualization for Geological Modelling

Rocha

Mota

Hamdi

et al. 2018

Computer Graphics Forum

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In this paper, we present a novel illustrative multivariate visualization for geological modelling to assist geologists and reservoir engineers in visualizing multivariate datasets in superimposed representations, in contrast to the single-attribute visualizations supported by commercial software. Our approach extends the use of decals from a single surface to 3D irregular grids, using the layering concept to represent multiple attributes. We also build upon prior work to augment the design and implementation of different geological attributes (namely, rock type, porosity, and permeability). More specifically, we propose a new sampling strategy to generate decals for porosity on the geological grid, a hybrid visualization for permeability which combines 2D decals and 3D ellipsoid glyphs, and a perceptually-based design that allows us to visualize additional attributes (e.g., oil saturation) while avoiding visual interference between layers. Furthermore, our visual design draws from traditional geological illustrations, facilitating the understanding and communication between interdisciplinary teams. An evaluation by domain experts highlights the potential of our approach for geological modelling and interpretation in this complex domain.A. Rocha et al. / Illustrative Multivariate Visualization for Geological Modelling pinch-outs, or when surfaces intersect each other, such as when grid aligned cross-sections are used to explore 3D internal structures-a common strategy adopted by reservoir engineers and geologists.By combining colormaps, decals, decal-maps as well as a 3D glyph-based representation, we represent the following geological data attributes: rock type (categorical data), porosity (scalar data), permeability (tensor data), and oil saturation (scalar data). For porosity representation, we contribute a new importance-sampling strategy to generate decal distributions on the deformed corner point grid. For permeability, we propose a hybrid visualization strategy that combines 2D decals and 3D ellipsoid glyphs. Our perceptually-based design allows us to visualize additional geological attributes such as oil saturation, while avoiding visual interference between attribute layers. Our visual design draws from traditional geological illustrations, facilitating the understanding and communication between interdisciplinary teams. Moreover, we evaluate our technique with domain experts via real walk-through scenarios to highlight the potential of our approach for geological modelling and interpretation in this complex domain. Our main contributions in this work are as follows:

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Reservoir Model Design

Cited by 139 publications

References 0 publications

Upscaling of Elastic Properties in Carbonates: A Modeling Approach Based on a Multiscale Geophysical Data Set

Upscaling of Elastic Properties in Carbonates: A Modeling Approach Based on a Multiscale Geophysical Data Set

Lattice Boltzmann Simulations of Fluid Flow in Continental Carbonate Reservoir Rocks and in Upscaled Rock Models Generated with Multiple-Point Geostatistics

Illustrative Multivariate Visualization for Geological Modelling

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