Experimental and numerical modeling of direct injection of CO 2 into carbonate formations

Date

2006-11-20

Author

Izgec, O.
Demiral, B.
Bertin, H.
Akın, Serhat

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Sequestration of carbon dioxide in geological formations is an alternative way to manage the carbon emitted by combustion of fossil fuels. Results of an experimental and numerical modeling study aiming to investigate the important aspects of injection of CO2 in carbonate formations are presented. Different from sandstones, in carbonates surface reaction rates are very high, so mass transfer often limits the overall reaction rate, leading to highly non-uniform dissolution patterns. Often, large flow channels called wormholes are created. A distinctive feature of carbonate reservoirs is the porosity/permeability mismatch. Experiments were conducted to investigate the effect of CO2 injection rate, formation temperature, and brine salinity on chemical kinetics and thus permeability and porosity alteration trends through injection of gaseous CO2 into carbonate formations. Experiments were designed to model fast near well bore flow (in horizontal direction) and slow reservoir flows (in vertical direction). It was observed that small changes in porosity may lead to dramatic changes in permeability (presence of preferential flow paths, worm holes). Results of CT-monitored experiments were then used to calibrate a geochemical numerical model where a multi-phase, non-isothermal commercial simulator in which dissolution and deposition of calcite were considered by means of chemical reactions was used. It was observed that solubility and hydrodynamic storage of CO2 was larger compared to mineral trapping. Chemical kinetics leads to dissolution of carbonate and later precipitation of bicarbonate particles. Numerical models together with experimental results proposed that time required for chemical reactions among formation fluid (brine), rock (carbonate) and CO2 was small, that change in effective permeability and absolute porosity were observed within small periods of time. The calibrated model was then used to analyze field scale injections and to model the CO2 sequestration capacity of a hypothetical carbonate aquifer formation. Copyright 2006, Society of Petroleum Engineers.

Subject Keywords

Carbonates, Computer simulation, Fossil fuels, Geologic models, Porosity, Reaction kinetics, Sandstone

URI

https://www.scopus.com/inward/record.uri?partnerID=HzOxMe3b&scp=33751009124&origin=inward
https://hdl.handle.net/11511/70749

DOI

https://doi.org/10.2118/100809-ms

Conference Name

SPE Annual Technical Conference and Exhibition, ATCE 2006: Focus on the Future

Collections

Department of Petroleum and Natural Gas Engineering, Conference / Seminar

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Citation Formats

O. Izgec, B. Demiral, H. Bertin, and S. Akın, “Experimental and numerical modeling of direct injection of CO 2 into carbonate formations,” San Antonio, TX, Amerika Birleşik Devletleri, 24 - 27 Eylül 2006, 2006, vol. 1, p. 212, Accessed: 00, 2021. [Online]. Available: https://www.scopus.com/inward/record.uri?partnerID=HzOxMe3b&scp=33751009124&origin=inward.