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Effect of gravity segregation on CO2 sequestration and oil production during CO2 flooding

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  • Han, Jinju
  • Lee, Minkyu
  • Lee, Wonsuk
  • Lee, Youngsoo
  • Sung, Wonmo

Abstract

In this study, we attempted to analyze CO2 sequestration and oil production in the environment of gravity segregation, and ultimately making a relationship between them during the CO2 flooding. In order to utilize the depleted oil field after finishing the CO2 flooding as CO2 storage, quantitative characteristics of CO2 storage efficiency to be possible in that oil field should be understood for preventing a leak through fractures generated by high-pressured CO2 of free gas state prior to the injection of CO2. As an experimental system, we designed a two dimensional CO2 flooding apparatus equipped with sandstone plate. The apparatus had dip angles of 0° (horizontal system) and 90° (vertical system) to simulate gravity segregation condition. Experimental results for the vertical system showed that oil production was heavily influenced by gravitational effects for immiscible condition. This situation is analogous to thick reservoirs in which gravity dominates over viscous forces. However, for near-miscible condition, the gravity override phenomenon was not significant, and these results suggest that reservoir thickness should not be a criterion when using CO2 flooding. CO2 storage efficiency for near-miscible system was found to be much better than that for immiscible system regardless of the gravitational effect. For designing the CO2 EOR scheme in terms of relationship between CO2 storage and oil production, particularly in the case of high permeable homogeneous sandstone, we found out that the trapped CO2 as free gas state and oil recovery during the CO2 flooding were monotonically decreased without critical value of inflection point corresponding to CO2 injection rate increase.

Suggested Citation

  • Han, Jinju & Lee, Minkyu & Lee, Wonsuk & Lee, Youngsoo & Sung, Wonmo, 2016. "Effect of gravity segregation on CO2 sequestration and oil production during CO2 flooding," Applied Energy, Elsevier, vol. 161(C), pages 85-91.
    • Handle: RePEc:eee:appene:v:161:y:2016:i:c:p:85-91
    DOI: 10.1016/j.apenergy.2015.10.021
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    References listed on IDEAS

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    Cited by:

    1. Xiaolong, Chen & Yiqiang, Li & Xiang, Tang & Huan, Qi & Xuebing, Sun & Jianghao, Luo, 2021. "Effect of gravity segregation on CO2 flooding under various pressure conditions: Application to CO2 sequestration and oil production," Energy, Elsevier, vol. 226(C).
    2. Haider Mahmood & Maham Furqan, 2021. "Oil rents and greenhouse gas emissions: spatial analysis of Gulf Cooperation Council countries," Environment, Development and Sustainability: A Multidisciplinary Approach to the Theory and Practice of Sustainable Development, Springer, vol. 23(4), pages 6215-6233, April.
    3. Lekun Zhao & Guoqiang Sang & Jialei Ding & Jiangfei Sun & Tongjing Liu & Yuedong Yao, 2023. "Research on the Timing of WAG Intervention in Low Permeability Reservoir CO 2 Flooding Process to Improve CO 2 Performance and Enhance Recovery," Energies, MDPI, vol. 16(21), pages 1-24, October.
    4. Jian, Guoqing & Gizzatov, Ayrat & Kawelah, Mohammed & AlYousef, Zuhair & Abdel-Fattah, Amr I., 2021. "Simply built microfluidics for fast screening of CO2 foam surfactants and foam model parameters estimation," Applied Energy, Elsevier, vol. 292(C).
    5. Ajoma, Emmanuel & Saira, & Sungkachart, Thanarat & Ge, Jiachao & Le-Hussain, Furqan, 2020. "Water-saturated CO2 injection to improve oil recovery and CO2 storage," Applied Energy, Elsevier, vol. 266(C).
    6. Zhou, Xiang & Yuan, Qingwang & Rui, Zhenhua & Wang, Hanyi & Feng, Jianwei & Zhang, Liehui & Zeng, Fanhua, 2019. "Feasibility study of CO2 huff 'n' puff process to enhance heavy oil recovery via long core experiments," Applied Energy, Elsevier, vol. 236(C), pages 526-539.
    7. Anand Selveindran & Zeinab Zargar & Seyed Mahdi Razavi & Ganesh Thakur, 2021. "Fast Optimization of Injector Selection for Waterflood, CO 2 -EOR and Storage Using an Innovative Machine Learning Framework," Energies, MDPI, vol. 14(22), pages 1-24, November.
    8. Wang, Sijia & Jiang, Lanlan & Cheng, Zucheng & Liu, Yu & Zhao, Jiafei & Song, Yongchen, 2021. "Experimental study on the CO2-decane displacement front behavior in high permeability sand evaluated by magnetic resonance imaging," Energy, Elsevier, vol. 217(C).
    9. Wu, Qianhui & Ding, Lei & Zhao, Lun & Alhashboul, Almohannad A. & Almajid, Muhammad M. & Patil, Pramod & Zhao, Wenqi & Fan, Zifei, 2024. "CO2 soluble surfactants for carbon storage in carbonate saline aquifers with achievable injectivity: Implications from the continuous CO2 injection study," Energy, Elsevier, vol. 290(C).
    10. Ajoma, Emmanuel & Saira, & Sungkachart, Thanarat & Le-Hussain, Furqan, 2021. "Effect of miscibility and injection rate on water-saturated CO2 Injection," Energy, Elsevier, vol. 217(C).
    11. Ampomah, W. & Balch, R.S. & Cather, M. & Will, R. & Gunda, D. & Dai, Z. & Soltanian, M.R., 2017. "Optimum design of CO2 storage and oil recovery under geological uncertainty," Applied Energy, Elsevier, vol. 195(C), pages 80-92.
    12. Samin Raziperchikolaee & Ashwin Pasumarti & Srikanta Mishra, 2020. "The effect of natural fractures on CO2 storage performance and oil recovery from CO2 and WAG injection in an Appalachian basin reservoir," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 10(5), pages 1098-1114, October.

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