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Reservoir heterogeneity controls of CO_(2)-EOR and storage potentials in residual oil zones:Insights from numerical simulations

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Petroleum Science 2023年第5期20卷 2879-2891页

作者： Yan-Yong Wang Xiao-Guang Wang Ren-Cheng Dong Wen-Chao Teng Shi-Yuan Zhan Guang-Yong Zeng Cun-Qi Jia College of Energy Chengdu University of TechnologyChengdu610059SichuanChina State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation Chengdu University of TechnologyChengdu610059SichuanChina Engineering Research Center of Geothermal Resources Development Technology and Equipment Ministry of EducationJilin UniversityChangchun130026JilinChina The University of Texas at Austin AustinTX78712USA Department of Energy Resources Engineering Stanford UniversityStanfordCA94305USA State Key Laboratory of Geohazard Prevention and Geoenvironment Protection Chengdu University of TechnologyChengdu610059SichuanChina

Residual oil zones(ROZs)have large potential for CO_(2)enhanced oil recovery(EOR)and geologic *** CO_(2)injection,the migration of CO_(2)in ROZs controls the performance of both EOR and ***,it has not been clearly visualized and understood that how geological heterogeneity factors control the transport of CO_(2)in *** this study,the oil recovery performance and geologic storage potential during continuous CO_(2)injection in a representative ROZ are studied based on geostatistical modelling and high-fidelity three-phase flow *** examined the influence of autocorrelation length of permeability,global heterogeneity(DykstraeParsons coefficient),and permeability anisotropy on cumulative oil recovery and CO_(2)retention *** results indicate that,as the permeability autocorrelation length increases,the cumulative oil recovery and CO_(2)storage efficiency *** results from the accelerated migration of CO_(2)along high permeability zones(i.e.,gas channeling).The increase in global heterogeneity and permeability anisotropies can lead to low oil recovery and poor CO_(2)sequestration performance,depending on the degree of CO_(2)*** net utilization ratio of CO_(2)(CO_(2)retained/oil produced)unfavorably increases with both autocorrelation length and Dykstra eParsons coefficient,but decreases with the increase in kv/*** a decrease is attributed to enlarged swept volume induced by gravity *** study provides important implications for fieldscale CO_(2)EOR and storage applications in ROZs.

关键词： Residual oil zones CO_(2)injection Enhanced oil recovery geologic sequestration

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Sensitivity analysis of CO_2 sequestration in saline aquifers

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Petroleum Science 2010年第3期7卷 372-378页

作者： Zhao Hongjun Liao Xinwei Chen Yanfang Zhao Xiaoliang Key Laboratory of Petroleum Engineering Ministry of Education China University of Petroleum Beijing 102249 China

Carbon capture and storage （CCS） technology has been considered as an important method for reducing greenhouse gas emissions and for mitigating global climate change. Three primary options are being considered for large-scale storage of CO2 in subsurface formations： oil and gas reservoirs, deep saline aquifers, and coal beds. There are very many large saline aquifers around the world, which could make a big contribution to mitigating global warming. However, we have much less understanding of saline aquifers than oil and gas reservoirs. Several mechanisms are involved in the storage of CO2 in deep saline aquifers, but the ultimate goal of injection of CO2 into the aquifers containing salt water is to dissolve the CO2 in the water. So it is important to study the solubility trapping and sensitivity factors of CO2 in saline aquifers. This paper presents results of modeling CO2 storage in a saline aquifer using the commercial reservoir simulator ECLIPSE. The objective of this study was to better understand the CO2/brine phase behavior （PVT properties） and quantitatively estimate the most important CO2 storage mechanism in brine-solubility trapping. This would provide a tool by performing theoretical and numerical studies that help to understand the feasibility of CO2 geological storage. A 3-dimensional, 2-phase （water/gas） conceptional reservoir model used finite, homogenous and isothermal formations into which CO2 is injected at a constant rate. The effects of main parameters were studied, including the vertical to horizontal permeability ratio kv/kh, salinity, and residual phase saturations. The results show that the vertical to horizontal permeability ratio has a significant effect on CO2 storage. Moreover, more CO2 dissolves in the brine at lower kv/kh values.

关键词： CO2 geologic sequestration saline aquifer solubility trapping numerical simulation

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Effect of modeling factors on the dissolution-diffusion-convection process during CO2 geological storage in deep saline formations

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Frontiers of Earth Science 2013年第2期7卷 238-256页

作者： WeiZHANG National geological Library of China (Geoscience Documentation Center) China Geological Survey Beijing 100083 China

It is well known that during CO2 geological storage, density-driven convective activity can significantly accelerate the dissolution of injected CO2 into water. This action could limit the escape of supercritical CO2 from the storage formation through vertical pathways such as fractures, faults and abandoned wells, consequently increasing permanence and security of storage. First, we investigated the effect of numerical perturbation caused by time and grid resolution and the convergence criteria on the dissolution-diffusion-convection （DDC） process. Then, using the model with appropriate spatial and temporal resolution, some uncertainty parameters investigated in our previous paper such as initial gas saturation and model boundaries, and other factors such as relative liquid permeability and porosity modification were used to examine their effects on the DDC process. Finally, we compared the effect of 2D and 3D models on the simulation of the DDC process. The above modeling results should contribute to clear understanding and accurate simulation of the DDC process, especially the onset of convective activity, and the CO2 dissolution rate during the convection-dominated stage.

关键词： climate change carbon dioxide geologic sequestration density-driven convection reactive transport modeling grid resolution

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Geomechanical response of overburden caused by CO_2 injection into a depleted oil reservoir

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Journal of Rock Mechanics and Geotechnical Engineering 2016年第6期8卷 860-872页

作者： Hema J.Siriwardane Raj K.Gondle Sai B.Varre Grant S.Bromhal Thomas H.Wilson Department of Civil and Environmental Engineering West Virginia University Department of Civil and Environmental Engineering University of Massachusetts Lowell National Energy Technology Laboratory U.S. Department of Energy Department of Geology and Geography West Virginia University

This study investigates the hydro-mechanical aspects of carbon dioxide(CO2) injection into a depleted oil reservoir through the use of coupled multiphase fluid flow and geomechanical *** singlephase and multiphase fluid flow analyses coupled with geomechanics were carried out at the West Pearl Queen depleted oil reservoir site,and modeling results were compared with available measured *** site geology and the material properties determined on the basis of available geophysical data were used in the *** results from the coupled multiphase fluid flow and geomechanical analyses show that computed fluid pressures match well with available measured *** hydromechanical properties of the reservoir have a significant influence on computed fluid pressures and surface ***,an accurate geologic characterization of the sequestration site and determination of engineering properties are important issues for the reliability of model *** computed fluid pressure response is also significantly influenced by the relative permeability curves used in multiphase fluid flow *** the multiphase fluid flow models provide more accurate fluid pressure response,single-phase fluid flow models can be used to obtain approximate *** ground surface deformations obtained from single-phase fluid flow models coupled with geomechanics are slightly lower than those predicted by multiphase fluid flow models coupled with ***,the advantage of a single-phase model is the *** field monitoring of subsurface fluid pressure and ground surface deformations during fluid injection can be used in calibrating coupled fluid flow and geomechanical *** calibrated models can be used for investigating the performance of large-scale CO2storage in depleted oil reservoirs.

关键词： Depleted oil reservoirs Multiphase flow Geomechanics geologic sequestration Computational modeling

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