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A modified failure criterion for transversely isotropic rocks

Geoscience Frontiers 2014年第2期5卷 215-225页

作者： Omid Saeidi Vamegh Rasouli Rashid Geranmayeh Vaneghi Raoof Gholami seyed rahman torabi Faculty of Mining Petroleum and Geophysics Shahrood University of Technology Department of Petroleum Engineering Curtin University Rock Mechanics Division Tarbiat Modares University Department of Chemical and Petroleum Engineering Curtin University of Technology

A modified failure criterion is proposed to determine the strength of transversely isotropic rocks. Me-chanical properties of some metamorphic and sedimentary rocks including gneiss, slate, marble, schist, shale, sandstone and limestone, which show transversely isotropic behavior, were taken into consider-ation. Afterward, introduced triaxial rock strength criterion was modified for transversely isotropic rocks. Through modification process an index was obtained that can be considered as a strength reduction parameter due to rock strength anisotropy. Comparison of the parameter with previous anisotropy in-dexes in literature showed reasonable results for the studied rock samples. The modified criterion was compared to modified Hoek-Brown and Ramamurthy criteria for different transversely isotropic rocks. It can be concluded that the modified failure criterion proposed in this study can be used for predicting the strength of transversely isotropic rocks.

关键词： Transversely isotropic rock Strength anisotropy Failure criterion Triaxial test

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Surfactant and nanoparticle synergy:Towards improved foam stability

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Petroleum 2023年第2期9卷 255-264页

作者： Arifur rahman Farshid torabi Ezeddin Shirif Petroleum Systems Engineering Faculty of Engineering and Applied ScienceUniversity of ReginaReginaSK S4S 0A2Canada Petroleum and Mining Engineering School of Applied Science&TechnologyShahjalal University of Science and TechnologySylhet3114Bangladesh

Surfactant foam stability gets a lot of interest while posing a significant obstacle to many industrial *** of the viable solutions for addressing gas mobility concerns and boosting reservoir fluid sweep efficiency during solvent-based enhanced heavy oil recovery processes is foam *** synergistic effect of nanoparticles and surfactants in a porous reservoir media can help create a more durable and sturdier *** study aims to see how well a combination of the nanoparticles(NPs)and surfactant can generate foam for controlling gas mobility and improving oil *** research looked at the effects of silicon and aluminum oxide nanoparticles on the bulk and dynamic stability of sodium dodecyl surfactant(SDS)-foam in the presence and absence of *** foam height,liquid drainage,half-decay life,nanoparticle deposition,and bubble size distribution of the generated foams with time were used to assess static foam stability in the bulk phase,while dynamic stability was studied in the *** understand the processes of foam stabilization by nanoparticles,the microscopic images of foam and the shape of bubbles were *** nanoparticles were applied in foamability testing in bulk and dynamic phase,the foam generation and stability were improved by 23%and 17%,*** comparison to surfactant alone,adding nanoparticles to surfactant solutions leads to a more significant pressure drop of 17.34 psi for SiO_(2)and 14.86 psi for Al_(2)O_(3)NPs and,as a result,a higher reduction in gas mobility which ultimately assists in enhancing oil recovery.

关键词： Foam stability Nanoparticles Surfactant Foam decay Pressure drop Enhanced oil recovery Etc

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Nanoparticle-stabilized CO2 foam flooding for enhanced heavy oil recovery: A micro-optical analysis

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Petroleum 2024年第4期 696-704页

作者： Arifur rahman Ezeddin Shirif Farshid torabi Petroleum Systems Engineering Faculty of Engineering and Applied Science University of Regina Petroleum and Mining Engineering School of Applied Science & Technology Shahjalal University of Science and Technology

Surfactant flooding is a well-known chemical approach for enhancing oil recovery. Surfactant flooding has the disadvantage that it cannot withstand the harsh reservoir conditions. Improvements in oil recovery and release are made possible by the use of nanoparticles and surfactants and CO2co-injection because they generate stable foam, reduce the interfacial tension（IFT） between water and oil, cause emulsions to spontaneously form, change the wettability of porous media, and change the characteristics of flow. In the current work, the simultaneous injection of SiO2, Al2O3nanoparticles, anionic surfactant SDS, and CO2in various scenarios were evaluated to determine the microscopic and macroscopic efficacy of heavy oil recovery. IFT（interfacial tension） was reduced by 44% when the nanoparticles and SDS（2000 ppm） were added, compared to a reduction of roughly 57% with SDS only. SDS-stabilized CO2foam flooding, however, is unstable due to the adsorption of SDS in the rock surfaces as well as in heavy oil. To assess foam's potential to shift CO2from the high permeability zone（the thief zone） into the low permeability zone, directly visualizing micromodel flooding was successfully executed（upswept oil-rich zone）. Based on typical reservoir permeability fluctuations, the permeability contrast（defined as the ratio of high permeability to low permeability） for the micromodel flooding was selected. However, the results of the experiment demonstrated that by utilizing SDS and nanoparticles, minimal IFT was reached. The addition of nanoparticles to surfactant solutions, however, greatly boosted oil recovery,according to the findings of flooding studies. The ultimate oil recovery was generally improved more by the anionic surfactant（SDS） solution including nanoparticles than by the anionic surfactant（SDS） alone.

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