A Critical Review of CO₂ Enhanced Oil Recovery in Tight Oil Reservoirs of North America and China
Primary oil recovery remains less than 10% in tight oil reservoirs, even after expensive multistage horizontal well hydraulic fracturing stimulation. Substantial experiments and pilot tests have been performed to investigate CO2-EOR potential in tight reservoirs; however, some results conflict with each other. The objective of this paper is to diagnose how these conflicting results occurred and to identify a way to narrow the gap between experimental results and field performance through a comprehensive literature review and data analysis. Peer-reviewed journal papers, technical reports, and SPE publications were collected, and three key steps were taken to reach our goal. First, rock and fluid properties of tight reservoirs in North America and China were compared, and their potential effect on tight oil production was analyzed. Afterward, based on published experimental studies and simulation works, the CO2-EOR mechanisms were discussed, including molecular diffusion, CO2-oil interaction considering nanopore confinement, and CO2-fluid-rock minerals interaction. Subsequently, pilot projects were examined to understand the gap between laboratory works and field tests, and the challenges faced in China's tight oil exploitation were rigorously analyzed. Compared with Bakken and Eagle Ford formation, China's tight oil reservoirs feature higher mud content and oil viscosity while they have a lower brittleness index and formation pressure, leading to confined stimulated reservoir volume and further limited CO2-oil contact. The effect of CO2 molecular diffusion was relatively exaggerated in experimental results, which could be attributed to the dual restrictions of exposure time and oil-CO2 area in field scale. Numerical modeling showed that the improved phase properties in nanopores led to enhanced oil recovery. The development of nano-scale chips withholding high pressure/ temperature may advance the experimental study on nano-confinement's effect. Oil recovery can be further enhanced through wettability alteration due to CO2 adsorption on nanopores and reaction with rock minerals. CO2 huff-n-puff operations were more commonly applied in North America than China, and the huff time is in the order of 10 days, but the soaking time is less. Conformance control was essential during CO2 flooding in order to delay gas breakthrough and promote CO2-oil interaction. There is less than 5% of tight oil reserve surrounded by CO2 reservoirs in China, limiting the application of CO2-EOR technologies. An economic incentive from the government is necessary to consider the application of CO2 from power plants, refineries, etc. This work provides an explanation of conflicting results from different research methods and pilot tests, and helps researchers and oil operators understand where and when the CO2-EOR can be best applied in unconventional reservoirs. New directions for future work on CO2-EOR in tight formations are also recommended.
Z. Song et al., "A Critical Review of CO₂ Enhanced Oil Recovery in Tight Oil Reservoirs of North America and China," Proceedings of the SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition (2019, Bali, Indonesia), Society of Petroleum Engineers (SPE), Oct 2019.
The definitive version is available at https://doi.org/10.2118/196548-MS
SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition 2019, APOG 2019 (2019: Oct. 29-31, Bali, Indonesia)
Geosciences and Geological and Petroleum Engineering
Center for Research in Energy and Environment (CREE)
Keywords and Phrases
CO2 injection; Enhanced oil recovery; Pilot test; Recovery mechanism; Tight oil
International Standard Book Number (ISBN)
Article - Conference proceedings
© 2019 Society of Petroleum Engineers (SPE), All rights reserved.
31 Oct 2019