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Chemistry of Reservoir Fluids in the Aspect of CO 2 Injection for Selected Oil Reservoirs in Poland

Author

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  • Ewa Knapik

    (Drilling, Oil and Gas Faculty, AGH University of Science and Technology, al. Mickiewicza 30, 30-059 Krakow, Poland)

  • Katarzyna Chruszcz-Lipska

    (Drilling, Oil and Gas Faculty, AGH University of Science and Technology, al. Mickiewicza 30, 30-059 Krakow, Poland)

Abstract

Worldwide experiences related to geological CO 2 storage show that the process of the injection of carbon dioxide into depleted oil reservoirs (CCS-EOR, Carbon Capture and Storage—Enhanced Oil Recovery) is highly profitable. The injection of CO 2 will allow an increasing recovery factor (thus increasing CCS process profitability) and revitalize mature reservoirs, which may lead to oil spills due to pressure buildups. In Poland, such a solution has not yet been implemented in the industry. This work provides additional data for analysis of the possibility of the CCS-EOR method’s implementation for three potential clusters of Polish oil reservoirs located at a short distance one from another. The aim of the work was to examine the properties of reservoir fluids for these selected oil reservoirs in order to assure a better understanding of the physicochemical phenomena that accompany the gas injection process. The chemical composition of oils was determined by gas chromatography. All tested oils represent a medium black oil type with the density ranging from 795 to 843 g/L and the viscosity at 313 K, varying from 1.95 to 5.04 mm/s. The content of heavier components C25+ is up to 17 wt. %. CO 2 –oil MMP (Minimum Miscibility Pressure) was calculated in a CHEMCAD simulator using the Soave–Redlich–Kwong equation of state (SRK EoS). The oil composition was defined as a mixture of n-alkanes. Relatively low MMP values ( ca . 8.3 MPa for all tested oils at 313 K) indicate a high potential of the EOR method, and make this geological CO 2 storage form more attractive to the industry. For reservoir brines, the content of the main ions was experimentally measured and CO 2 solubility under reservoir conditions was calculated. The reservoir brines showed a significant variation in properties with total dissolved solids contents varying from 17.5 to 378 g/L. CO 2 solubility in brines depends on reservoir conditions and brine chemistry. The highest calculated CO 2 solubility is 1.79 mol/kg, which suggest possible CO 2 storage in aquifers.

Suggested Citation

  • Ewa Knapik & Katarzyna Chruszcz-Lipska, 2020. "Chemistry of Reservoir Fluids in the Aspect of CO 2 Injection for Selected Oil Reservoirs in Poland," Energies, MDPI, vol. 13(23), pages 1-19, December.
    • Handle: RePEc:gam:jeners:v:13:y:2020:i:23:p:6456-:d:457768
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    References listed on IDEAS

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    1. Fengshuang Du & Bahareh Nojabaei, 2019. "A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control," Energies, MDPI, vol. 12(12), pages 1-33, June.
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    1. Ewa Knapik & Grzegorz Rotko & Marta Marszałek, 2023. "Recovery of Lithium from Oilfield Brines—Current Achievements and Future Perspectives: A Mini Review," Energies, MDPI, vol. 16(18), pages 1-28, September.

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