Stochastic Joint Simulation of Facies and Diagenesis: A Case Study on Early Diagenesis of the Madison Formation (Wyoming, USA)

Barbier, Mickaël; Hamon, Youri; Doligez, Brigitte; Callot, Jean‐Paul; Floquet, Marc; Daniel, Jean‐Marc

doi:10.2516/ogst/2011009

Cited by 14 publications

(8 citation statements)

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“…These maps are the basis for conducting further enhanced statistics on the sedimentological and diagenetic relationships (e.g. Barbier et al 2012), eventually suggesting meaningful understanding of reservoir heterogeneities. Accordingly, the lime grainstones of the Arab D reservoirs, which contain syntaxial calcite overgrowth cement (SCO), include the best flow properties in the investigated oilfield.…”

Section: Integrated Quantification Approachmentioning

confidence: 99%

“…Still, conceptual models are qualitative and do not yield quantitative data to be directly used by reservoir engineers for rock-typing and geological modelling (e.g. Jones & Xiao 2005;Youssef et al 2007b;Algive et al 2009b;Consonni et al 2010;Lapponi et al 2011;Barbier et al 2012;De Boever et al 2012). Figure 1 illustrates a workflow that aims at predicting the impact of the relevant diagenetic processes on reservoir properties, leading to improved rock-typing and reservoir modelling.…”

Section: Introductionmentioning

confidence: 99%

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Quantification of diagenesis impact on the reservoir properties of the Jurassic Arab D and C members (Offshore, U.A.E.)

et al. 2013

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An increasing need exists to quantify the impact of diagenesis on complex and heterogeneous geological reservoirs and to predict the related field‐scale porosity‐permeability distribution. Development of approaches to quantify diagenetic events is an important step towards the construction of integrated numerical reservoir models predicting the impact of successive diagenetic events on petrophysical properties at various scales. This article describes two distinct approaches, which allow capturing, quantifying and explaining reservoir heterogeneities of the Jurassic Arab Formation (offshore oilfield in Abu Dhabi, U.A.E.) at the field and plug scale. Based on a classical diagenesis study, whereby the major diagenetic phases were characterized, distribution patterns were highlighted to further explain reservoir heterogeneities through a set of 2D interpolation diagenesis maps across the field. The best reservoir properties are encountered in the central‐northern (grainstones with syntaxial calcite overgrowth cement – typical of Arab D) and south‐western (dolostones – typical of Arab C) parts of the oilfield. Following another independent approach at the scale of the plug, quantification of rock components and description of the pore space connectivity and geometry are obtained by 2D and 3D image analyses, μ‐CT and pore network modelling. This latter approach resulted in a better understanding of the effect of anhydrite dissolution on the pore structure of the investigated dolostone. The overall, presented workflow provides valuable constraints for assessing reservoir heterogeneities in statistical field‐scale models.

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Section: Integrated Quantification Approachmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Quantification of diagenesis impact on the reservoir properties of the Jurassic Arab D and C members (Offshore, U.A.E.)

et al. 2013

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“…This second example proposes an integrated approach through nested simulations to reproduce both facies and diagenetic trends in a static reservoir model based on an outcrop case study (Barbier et al 2011). The presented case is limited to early diagenesis, as this latter is clearly controlled by palaeo-environments and is directly linked to sedimentary facies.…”

Section: Example N°2: Two-steps (Nested) Simulation Of Early Diagenesmentioning

confidence: 99%

“…This allowed dealing with complex spatial relationships between lithotypes that result from different processes, as discussed in Barbier et al (2011) (Figure 9 left). In this study, we have used Gaussian variogram models for the two random fields, in order to generate smooth distributions of the facies.…”

Section: Modelling Workflowmentioning

confidence: 99%

Advanced Workflows For Joint Modelling Of Sedimentary Facies And Diagenetic Overprint, Impact On Reservoir Quality

Doligez

Hamon

Barbier

et al. 2011

SPE Annual Technical Conference and Exhibition

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The relationships between sedimentological facies and diagenetic properties differ depending on burial and geological history. In this paper we propose several examples where different quantitative expressions of diagenetic imprints lead to different workflows to be applied, to obtain final simulations reproducing both the sedimentary facies and the diagenetic trends in reservoir models.A first case is based on an outcrop study of mixed siliciclastic-carbonate facies. The relationships between sedimentary facies and diagenesis have been used to define truncation rules for the plurigaussian algorithm, which aims at simulating both the distribution of sedimentary facies and the diagenetic overprint. Another workflow has been developed on this example, using the bi-plurigaussian simulation algorithm to address the problem of heterotopic bivariate conditional simulation (the two variables are known at different locations).A second example is related to early diagenesis characterization. In this example (Madison Formation, Wyoming, USA), diagenetic imprints have been quantified, corresponding to a succession of diagenetic phases (micritization, calcite cementation, dolomitization...), that can coexist in the same sedimentary facies. The workflow using plurigaussian and nested simulation algorithms shows the impact of such joint simulations, as the diagenesis may completely modify the distribution of reservoir properties only based on a facies simulation.In a third example, the modeled Aptian/Albian formation includes hydrothermal dolomites (HDT) associated to fractures and faults hosted in reefal and slope limestones. Simulations succeed in redistributing the HTD correctly at the surface and in the subsurface. Hence, in the deeper parts of the Aptian/Albian reefal rock unit, the dolomite is inherently associated to fractures, while at shallower levels, dolomitization seems to be more lateral, affecting probably more permeable facies. These results provide insights and numerical means for estimating volumes of dolomites (vertically and laterally) in an excellent case study of fracture-related HTD.Diagenesis alters the original relationships between depositional facies and petrophysical properties in a reservoir. The quantitative integration of sedimentological facies and diagenetic properties is a key point to obtain a realistic geological model in reservoir studies.

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“…Due to the uncertainty in the description of the occurring diagenesis phases and their effects in the facies deposition model, a stochastic framework may be preferred. Several authors (Barbier et al 2012;Doligez et al 2011;Hamon et al 2015;Labourdette et al 2007) investigated and applied geostatistical methods to integrate depositional facies and diagenetic overprint models. The leading idea consists first in identifying the major diagenetic phases, which modify the petrophysical properties and second in qualitatively or semiquantitatively establishing the relationship linking the diagenetic phases to the depositional facies.…”

Section: Introductionmentioning

confidence: 99%

Accounting for diagenesis overprint in carbonate reservoirs using parametrization technique and optimization workflow for production data matching

Carrera

Barbier

Ravalec

2018

J Petrol Explor Prod Technol

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Diagenesis is rarely accounted for in the standard modeling workflows for carbonate reservoirs, although it has a huge impact on both porosity and permeability. This can be explained by at least two reasons: first, it is difficult to quantify the influence of diagenetic overprints on porosity and permeability; second, the integration of the diagenetic effects in carbonate reservoir models makes history matching much more difficult. Herein, a modeling methodology is proposed, in which the diagenetic imprints are included in the reservoir model and calibrated with dynamic data. The key point consists in defining a parametrization technique able to capture these diagenetic imprints. We assume that distinct regions of occurrence of a given diagenetic phase can be identified within the reservoir. Therefore, restricting our attention to a facies, we may distinguish regions characterized by low, medium or high proportions of the targeted diagenetic phase. The advantage of this parametrization technique is that the proportions of these regions can be easily driven by a reduced number of proportionality coefficients. Then, the overall modeling approach is integrated in an optimization workflow making it possible to vary the proportions of the region with a given occurrence for a given diagenetic phase, the variograms characterizing the spatial distribution of the regions, or even the way they are spatially distributed. The optimization process is run to adjust these various unknown parameters in order to match production history. The potential of the proposed methodology is finally investigated through the study of a two-dimensional numerical example.

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Stochastic Joint Simulation of Facies and Diagenesis: A Case Study on Early Diagenesis of the Madison Formation (Wyoming, USA)

Cited by 14 publications

References 37 publications

Quantification of diagenesis impact on the reservoir properties of the Jurassic Arab D and C members (Offshore, U.A.E.)

Quantification of diagenesis impact on the reservoir properties of the Jurassic Arab D and C members (Offshore, U.A.E.)

Advanced Workflows For Joint Modelling Of Sedimentary Facies And Diagenetic Overprint, Impact On Reservoir Quality

Accounting for diagenesis overprint in carbonate reservoirs using parametrization technique and optimization workflow for production data matching

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