CO2 INJECTION IN A CARBONATE RESERVOIR FOR EOR PROCESS

  • Omar Kalifa Hammuda Aluhwal
DOI https://doi.org/10.58916/jhas.v7i6.572
Published: 2024-12-10
pdf
49
3

Abstract

ABSTRACT: CO2 injection is a mode that is used for enhanced oil recovery (EOR). The residual oil volume is left in porous media after the secondary recovery method of waterflooding operation which can be considered a remarkable and recoverable amount that must be extracted. Therefore, the tertiary recovery mode such as CO2 injection may be a reliable method for this mission. A carbonate core holder CO2 flooding trial method has been conducted at reservoir condition to investigate the oil recovery factor. Consequently, three experiments have run in the laboratory with three CO2 slug sizes that have been injected into the carbonate reservoir after conventional secondary recovery. The results illustrated that oil flow rate increased after each injected CO2 slug. Firstly, CO2 slug size of 0.25 PV injected into reservoir which gained a recovery factor of 58.52 % with incremental recovery of 6.78 % over waterflooding process. Secondly, CO2 slug size of 0.5 PV injected after waterflooding, so, the recovery factor reached up to 61.88 % and the incremental oil recovery was 8.88 %. Finally, the result has shown a significant final oil recovery of 64.49 % and additional recovery factor of 10.75 % when the system carried out CO2 slug size injection of 1 PV. This might be attributed to good sweep efficiency, capillary force reduction, interfacial tension reduction as well as wettability alteration effectiveness. Consequently, the findings demonstrated that CO2 displacement process is a remarkable method for EOR project.

Keywords: CO2 injection, Carbonate reservoir, Oil recovery factor

How to Cite

Omar Kalifa Hammuda Aluhwal. (2024). CO2 INJECTION IN A CARBONATE RESERVOIR FOR EOR PROCESS. Bani Waleed University Journal of Humanities and Applied Sciences, 7(5), 28-35. https://doi.org/10.58916/jhas.v7i6.572
Crossref
Scopus
Google Scholar
Europe PMC

License

Creative Commons License

This work is licensed under a Creative Commons Attribution 4.0 International License.

References

1.
References
2.
Honarvar, B., Azdarpour, A., Karimi, M., Rahimi, A., Afkhami Karaei, M., Hamidi, H., ... & Mohammadian, E. (2017). Experimental investigation of interfacial tension measurement and oil recovery by carbonated water injection: a case study using core samples from an Iranian carbonate oil reservoir. Energy & Fuels, 31(3), 2740-2748.
3.
Aluhwal, H. Kalifa, O. (2008). Simulation study of improving oil recovery by polymer flooding in a Malaysian reservoir. Master's Thesis, University Technology Malaysia.
4.
Mohr, S. H., Wang, J., Ellem, G., Ward, J., and Giurco, D. (2015). Projection of world fossil fuels by country. Fuel, 141, 120-135.
5.
Aluhwal, O. K. H. (2019). Enhanced Oil Recovery By Surfactant Alternate Carbonated Water Injection (Doctoral dissertation, Universiti Teknologi Malaysia).
6.
Al-Abri, A., & Amin, R. (2010). Phase behaviour, fluid properties and recovery efficiency of immiscible and miscible condensate displacements by SCCO2 injection: experimental investigation. Transport in porous media, 85(3), 743-756.
7.
Aluhwal, O. K. H., Junin, R. B., and Nasri, N. S. B. (2018). Effect of CO2 Content, Reservoir Temperature and Pressure of SACW on Oil Recovery. Advanced Science Letters, 24(6), 4232-4236.
8.
Aluhwal, O. K. H., Junin, R. B., and Nasri, N. S. B. (2017). Surfactant Alternating Carbonated Water Injection (SACW) is a New Process for Enhanced Oil Recovery. Advanced Science Letters, 23(9), 9085-9089.
9.
Badamchi-Zadeh, A., Yarranton, H. W., Svrcek, W. Y., & Maini, B. B. (2009). Phase behaviour and physical property measurements for VAPEX solvents: Part I. Propane and Athabasca bitumen. Journal of Canadian Petroleum Technology, 48(01), 54-61.
10.
Enayati, M., Heidaryan, E., & Mokhtari, B. (2008, June). New investigations into carbon dioxide flooding by focusing on viscosity and swelling factor changes. In Canadian International Petroleum Conference. OnePetro.
11.
Jessen, K., Sam-Olibale, L.C., Kovscek, A.R., Orr, F.M. (2001). Increasing CO2 Storage in Oil Recovery, First National Conference on Carbon Sequestration, sponsored by National Energy Technology Laboratory, Washington DC, 2.
12.
Li, H., Zheng, S., & Yang, D. (2013). Enhanced swelling effect and viscosity reduction of solvent (s)/CO2/heavy-oil systems. Spe Journal, 18(04), 695-707.
13.
Mathiassen, O.M., (2003). CO2 as Injection Gas for Enhanced Oil Recovery and Estimation of the Potential on the Norwegian Continental Shelf, MSc. Thesis, Trondheim, 2.
14.
Shaw, J. C., & Bachu, S. (2002, June). CO2 Flooding Performance Prediction for Alberta Oil Pools. In Canadian International Petroleum Conference. OnePetro.
15.
Stakup, F.I., (1978). Carbon Dioxide Miscible Flooding Miscible Flooding Past, Present and Outlook for the Future, J. Pet. Tech. 1102-1112.
16.
Tuzunoglu, E., and Bagci, S. (2000). Scaled 3-D model studies of immiscible CO2 flooding using horizontal wells. Journal of Petroleum Science and Engineering, 26(1-4), 67-81.
17.
Yazdani, A., & Maini, B. B. (2007).
18.
Measurements and modelling of phase behaviour and viscosity of a heavy oil-butane system. In Canadian International Petroleum Conference. OnePetro.
19.
Yongmao, H., Zenggui, W., Yueming, J.B.Ch., Xiangjie, L., (2004). Laboratory Investigation of CO2 Flooding, Paper SPE Presented at the 28th Annual SPE International Technical Conference and Exhibition in Abuja, Nigeria. 88883.
20.
Zhao, J., Wang, P., Yang, H., Tang, F., Ju, Y., & Jia, Y. (2021). Experimental Investigation of the CO2 Huff and Puff Effect in Low-Permeability Sandstones with NMR. ACS omega, 6(24), 15601-15607.

Most read articles by the same author(s)

1 2 3 4 5 6 7 8 9 10 > >> 

Similar Articles

1-10 of 86

You may also start an advanced similarity search for this article.