Author:
Wang Zhou-Hua,Sun Bo-Wen,Guo Ping,Wang Shuo-Shi,Liu Huang,Liu Yong,Zhou Dai-Yu,Zhou Bo
Abstract
AbstractFlue gas flooding is one of the important technologies to improve oil recovery and achieve greenhouse gas storage. In order to study multicomponent flue gas storage capacity and enhanced oil recovery (EOR) performance of flue gas water-alternating gas (flue gas–WAG) injection after continuous waterflooding in an oil reservoir, a long core flooding system was built. The experimental results showed that the oil recovery factor of flue gas–WAG flooding was increased by 21.25% after continuous waterflooding and flue gas–WAG flooding could further enhance oil recovery and reduce water cut significantly. A novel material balance model based on storage mechanism was developed to estimate the multicomponent flue gas storage capacity and storage capacity of each component of flue gas in reservoir oil, water and as free gas in the post-waterflooding reservoir. The ultimate storage ratio of flue gas is 16% in the flue gas–WAG flooding process. The calculation results of flue gas storage capacity showed that the injection gas storage capacity mainly consists of N2 and CO2, only N2 exists as free gas phase in cores, and other components of injection gas are dissolved in oil and water. Finally, injection strategies from three perspectives for flue gas storage, EOR, and combination of flue gas storage and EOR were proposed, respectively.
Subject
Economic Geology,Geochemistry and Petrology,Geology,Geophysics,Energy Engineering and Power Technology,Geotechnical Engineering and Engineering Geology,Fuel Technology
Reference52 articles.
1. Agartan E, Gaddipati M, Yip Y, et al. CO2 storage in depleted oil and gas fields in the Gulf of Mexico. Int J Greenh Gas Control. 2018;72:38–48. https://doi.org/10.1016/j.ijggc.2018.02.022.
2. Bachu S. Comparison between methodologies recommended for estimation of CO2 storage capacity in geological media by the CSLF task force on CO2 storage capacity estimation and the USDOE capacity and fairways subgroup of the regional carbon sequestration partnerships program, phase III report. In: Carbon sequestration leadership forum (CSLF), 21 April, 2008, Washington, DC.
3. Bachu S. Review of CO2 storage efficiency in deep saline aquifers. Int J Greenh Gas Control. 2015;40:188–202. https://doi.org/10.1016/j.ijggc.2015.01.007.
4. Bachu S, Shaw JC, Pearson RM. Estimation of oil recovery and CO2 storage capacity in CO2 EOR incorporating the effect of underlying aquifers. In: SPE/DOE symposium on improved oil recovery, 17–21 April, 2004, Tulsa, Oklahoma. https://doi.org/10.2118/89340-MS.
5. Bachu S, Bonijoly D, Bradshaw J, et al. CO2 storage capacity estimation: methodology and gaps. Int J Greenh Gas Control. 2007;1(4):430–43. https://doi.org/10.1016/S1750-5836(07)00086-2.
Cited by
24 articles.
订阅此论文施引文献
订阅此论文施引文献，注册后可以免费订阅5篇论文的施引文献，订阅后可以查看论文全部施引文献