Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Physics

Dernaika, Moustafa; Jallad, Osama Al; Koronfol, Safouh; Suhrer, Michael; Teh, Woan Jing; Walls, Joel; Matar, Saad; Murthy, Natarajan; Zekraoui, Mohammed

doi:10.2118/178616-ms

Cited by 5 publications

(2 citation statements)

References 1 publication

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“…Interestingly, in Figure 2g, where the radiotracer spans the entire sample, significant regions of the core have no radiotracer present. These flow observations are aligned with observations in other heterogeneous limestone samples presented in the literature (Dernaika et al., 2015; Saenger et al., 2016).…”

Section: Resultssupporting

confidence: 91%

Predictive Soft Computing Methods for Building Digital Rock Models Verified by Positron Emission Tomography Experiments

Ebadi

Armstrong

Mostaghimi

et al. 2022

Water Resources Research

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The influence of core‐scale heterogeneity on continuum‐scale flow and laboratory measurements are not well understood. To address this issue, we propose a fully automated workflow based on soft computing to characterize the heterogeneous flow properties of cores for predictive continuum‐scale models. While the proposed AI‐based workflow inherently has no trained knowledge of rock petrophysical properties, our results demonstrate that image features and morphological properties provide sufficient measures for petrophysical classification. Micro X‐ray computed tomography (μxCT) image features were extracted from full core plug images by using a Convolutional Neural Network and Minkowski functional measurements. The features were then classified into specific classes using Principal Component Analysis followed by K‐means clustering. Next, the petrophysical properties of each class were evaluated using pore‐scale simulations to substantiate that unique classes were identified. The μxCT image was then up‐scaled to a continuum‐scale grid based on the defined classes. Last, simulation results were evaluated against real‐time flooding data monitored by Positron Emission Tomography. Both homogeneous sandstone and heterogeneous carbonate were tested. Simulation and experimental saturation profiles compared well, demonstrating that the workflow provided high‐fidelity characterization. Overall, we provided a novel workflow to build digital rock models in a fully automated way to better understand the impacts of heterogeneity on flow.

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Section: Resultssupporting

confidence: 91%

Predictive Soft Computing Methods for Building Digital Rock Models Verified by Positron Emission Tomography Experiments

Ebadi

Armstrong

Mostaghimi

et al. 2022

Water Resources Research

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show abstract

“…Secondly, secondary corrosion of ultrabasic rocks (e. g. the serpentinization of peridotite) will release H. The infusion of H-rich fluids will compensate for the H needed by the hydrocarbon production of hydrocarbon source rocks, thereby improving the hydrocarbon production efficiency of hydrocarbon source rocks. As a result, the hydrocarbon source rocks with low organic carbon concentration in the basins can also become valid for the production of abundant oil-gas (Larter et al, 2003;Tchanche et al, 2009;Dernaika et al, 20152015). According to research, due to the effect of deep fluids on the hydrogenation of hydrocarbon source rocks, the concentrations of alkanes, aromatic hydrocarbons, heterogeneous components and bitumen in hydrocarbon source rocks are somehow different from those in unaffected areas (Whelan et al, 1994).…”

Section: Introductionmentioning

confidence: 99%

Review of deep fluids in sedimentary basins and their influence on resources, with a focus on oil and geothermal exploitation

Wang

et al. 2023

Front. Earth Sci.

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Deep fluid activity is widespread in large oil-gas basins around the world. Deep fluids, as the links between internal and external factors of a basin, run in the way of organic-inorganic interactions through the oil-gas formation and aggregation. Herein, the identification characteristics of deep fluids in sedimentary basins as well as their influence on oil-gas reservoir formation and geothermal resource are summarized. The deep fluids of sedimentary basins are identified from three aspects, including mineral composition, fluid inclusions, and geochemical characteristics. The effects of deep fluid activities on oil-gas reservoir formation are manifested in two key aspects of matter and energy. As for the matter effects, deep fluids can improve the primary productivity of sedimentary basins and carry abundant inorganic hydrogen, which contributes to improving the hydrocarbon productivity through hydrogenation. As for the energy effects, the heat energy of deep fluids can promote the mature evolution from organic matter to oil and gas. During this process, the heating of deep fluids will cause the oil-generation window depth of the hydrocarbon source rocks to become thinner, and it will also generate very high pressure, which will promote the discharge of abundant hydrocarbons formed by the hydrocarbon source rocks. Furthermore, deep fluids can directly form volcanic rock oil-gas reservoirs. And another manifestation of deep fluid energy is geothermal. And the thermal energy of deep fluids can directly form hot dry rocks, which is the most important existing form of geothermal resources. The geological exploration of hot dry rocks should be supported by further geochemical and geophysical research.

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Workflow Development to Scale up Petrophysical Properties from Digital Rock Physics Scale to Laboratory Scale

Miarelli

Torre

2021

Transp Porous Med

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Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Physics

Cited by 5 publications

References 1 publication

Predictive Soft Computing Methods for Building Digital Rock Models Verified by Positron Emission Tomography Experiments

Predictive Soft Computing Methods for Building Digital Rock Models Verified by Positron Emission Tomography Experiments

Review of deep fluids in sedimentary basins and their influence on resources, with a focus on oil and geothermal exploitation

Workflow Development to Scale up Petrophysical Properties from Digital Rock Physics Scale to Laboratory Scale

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