HIGH RESOLUTION CT AND PORE-NETWORK MODELS TO ASSESS PETROPHYSICALPROPERTIES OF HOMOGENEOUS AND HETEROGENEOUS CARBONATES (2007)

High Resolution CT and Pore-Network Models to Assess Petrophysical Properties of Homogeneous and Heterogeneous Carbonates S. Youssef; S. Youssef Institut Français du Pétrole Search for other works by this author on: This Site Google Scholar E. Rosenberg; E. Rosenberg Institut Français du Pétrole Search for other works by this author on: This Site Google Scholar N. Gland; N. Gland Institut Français du Pétrole Search for other works by this author on: This Site Google Scholar J. A. M. Kenter; J. A. M. Kenter Chevron Energy Technology Company Search for other works by this author on: This Site Google Scholar M. Skalinski; M. Skalinski TengizChevroil, Atyrau, Kazakhstan Search for other works by this author on: This Site Google Scholar O. Vizika O. Vizika Institut Français du Pétrole Search for other works by this author on: This Site Google Scholar Paper presented at the SPE/EAGE Reservoir Characterization and Simulation Conference, Abu Dhabi, UAE, October 2007. Paper Number: SPE-111427-MS https://doi.org/10.2118/111427-MS Published: October 28 2007 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Youssef, S., Rosenberg, E., Gland, N., Kenter, J. A. M., Skalinski, M., and O. Vizika. "High Resolution CT and Pore-Network Models to Assess Petrophysical Properties of Homogeneous and Heterogeneous Carbonates." Paper presented at the SPE/EAGE Reservoir Characterization and Simulation Conference, Abu Dhabi, UAE, October 2007. doi: https://doi.org/10.2118/111427-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Reservoir Characterisation and Simulation Conference and Exhibition Search Advanced Search Abstract Carbonate rocks often present complex pore-structures involving multiple porosity systems with various interconnectivity degrees. These pore-systems, from microporosity to vugs/fissures, drastically affect petrophysical properties. Pore network models are well suited to calculate petrophysical properties of rocks from pore space structure information. The predictability of such models depends on the accuracy with which the complex geometry and topology of the pore network are captured. Computed MicroTomography (μCT) produces 3D images of the porous medium at the micron scale thus giving the opportunity to describe quantitatively and with a high precision the geometrical and topological characteristics of the 3D pore space. By providing a full description of pore space connectivity and geometry, such studies promise to improve both the understanding of diagenetic overprint and predictability of pore network models used to calculate petrophysical properties of these porous media.This methodology is applied to a set of rocks with various heterogeneity degrees from the Tengiz buildup (Precaspian Basin). The Tengiz central platform contains a succession of cyclic shallow water deposits ranging from Famennian to Bashkirian in age. The distribution of reservoir rock-types in this depositional zone is determined by a combination of primary deposition and burial diagenetic modification and includes spatial variations of both porosity enhancing as well as porosity filling effects. A pilot study using pore-network modeling from μ-CT imagery of several selected samples resulted in spatial pore and pore-throat size distributions, level and type of pore interconnectivity. Porosity, permeability and capillary pressure were calculated from μ-CT analyses and show a close match with those derived from measurements. Most strikingly, μ-CT allowed the extraction of 3Ddistribution of pore type and connectivity as well as cement types, information essential to reservoir quality assessment but very difficult to reconstruct using the classic petrographic approach. These models can be used for rock-typing, up scaling, to extrapolate petrophysical properties to uncored wells and to investigate new phenomena like evolution of properties due to dissolution/precipitation inherent in CO2 injection. Keywords: Upstream Oil & Gas, coordination number, petrophysical property, carbonate, skeleton, Reservoir Characterization, pore network, flow in porous media, resolution, pore Subjects: Reservoir Characterization, Fluid Characterization, Reservoir Fluid Dynamics, Reservoir Simulation, Formation Evaluation & Management, Information Management and Systems, Fluid modeling, equations of state, Flow in porous media Copyright 2007, Society of Petroleum Engineers You can access this article if you purchase or spend a download.