Petroleum Science >2018,??Issue 1:??103-115 DOI: https://doi.org/10.1007/s12182-017-0199-5
A numerical simulation study of CO 2 injection for enhancing hydrocarbon recovery and sequestration in liquid-rich shales Open?Access
文章信息
作者：Sumeer Kalra, Wei Tian and Xingru Wu
作者單位：
Warwick Energy Group, 900 W Wilshire Blvd, Oklahoma City, OK 73116, USA,University of Oklahoma, 100 E Boyd St. Sec 1210, Norman, OK 73019-1003, USA and University of Oklahoma, 100 E Boyd St. Sec 1210, Norman, OK 73019-1003, USA
投稿時(shí)間：2017-06-08
引用方式：Kalra, S., Tian, W. & Wu, X. Pet. Sci. (2018) 15: 103. https://doi.org/10.1007/s12182-017-0199-5
文章摘要
Less than 10% of oil is usually recovered from liquid-rich shales and this leaves much room for improvement, while water injection into shale formation is virtually impossible because of the extremely low permeability of the formation matrix. Injecting carbon dioxide (CO2) into oil shale formations can potentially improve oil recovery. Furthermore, the large surface area in organicrich shale could permanently store CO2 without jeopardizing the formation integrity. This work is a mechanism study of evaluating the effectiveness of CO2-enhanced oil shale recovery and shale formation CO2 sequestration capacity using numerical simulation. Petrophysical and fluid properties similar to the Bakken Formation are used to set up the base model for simulation. Result shows that the CO2 injection could increase the oil recovery factor from 7.4% to 53%. In addition, petrophysical characteristics such as in situ stress changes and presence of a natural fracture network in the shale formation are proven to have impacts on subsurface CO2 flow. A response surface modeling approach was applied to investigate the interaction between parameters and generate a proxy model for optimizing oil recovery and CO2 injectivity.
關(guān)鍵詞
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CO2 EOR, Tight formations, Experimental design, Response surface modeling, Recovery of shale liquid, CO2 sequestration