Advertisement

Arabian Journal for Science and Engineering

, Volume 43, Issue 11, pp 6567–6577 | Cite as

Investigation of Cyclic \(\text {CO}_{2}\) Injection Process with Nanopore Confinement and Complex Fracturing Geometry in Tight Oil Reservoirs

  • Rashid S. Mohammad
  • Shicheng Zhang
  • Ehsan-ul-Haq
  • Ahmed M. AlQadasi
Research Article - Petroleum Engineering
  • 30 Downloads

Abstract

Carbon dioxide is one of the capable processes in improving oil recovery from low-permeable oil reservoirs. However, the evaluation of cyclic \(\text {CO}_{2}\) injection process with nanopore confinement effect in tight reservoirs is deficient in the oil industry. The nanopores confinement plays a significant role in low-permeable formations, creating a high capillary pressure which substantially influences fluid phase behavior and fluid flow in tight reservoirs. In order to consider the effect of nanopore confinement in unconventional reservoirs, the conventional methods need to be modified. Thus, we evolve an effective model for cyclic \(\text {CO}_{2}\) injection process considering the effect of complex fracture geometry with nanopore confinement on the production from tight formations. Firstly, the reservoir fluid properties with nanopore confinement are estimated. Secondly, the minimum miscibility pressure is measured and verified with experimental data. Lastly, the well performance of cyclic \(\text {CO}_{2}\) injection process in unconventional tight reservoirs is evaluated based on few parameters such as \(\text {CO}_{2}\) diffusivity and matrix permeability. The results show that the combined effect of capillary pressure and \(\text {CO}_{2}\) dispersion has significantly influenced the oil production efficiency from tight oil reservoirs. The oil recovery factor of cyclic \(\text {CO}_{2}\) injection process at five years boosts from 14.67% as primary recovery to 22.54% due to \(\text {CO}_{2}\) molecular diffusion effect with overall 7.87% incremental recovery. Moreover, the incremental oil recovery of cyclic \(\text {CO}_{2}\) injection process is increased further by 1.7% while taking into consideration the combine effect of capillary pressure and \(\text {CO}_{2}\) diffusion on the oil recovery. This study provides an appropriate method for predicting the production of cyclic \(\text {CO}_{2}\) injection process with a complex fracture geometry, considering the capillary pressure and \(\text {CO}_{2}\) diffusion on well performance of tight oil reservoirs.

Keywords

Cyclic \(\text {CO}_{2}\) injection Nanopore confinement \(\text {CO}_{2}\) diffusion Capillary pressure and complex fracture 

Preview

Unable to display preview. Download preview PDF.

Unable to display preview. Download preview PDF.

References

  1. 1.
    Muhammad, R.S.; Zhang, S.; Lu, S; Jamal, S.; Zhao, X.: Simulation study of asphaltene deposition and solution of \(\text{CO}_{2}\) in the brine during cyclic \(\text{ CO }_{2}\) injection process in unconventional tight reservoirs. World Academy of Science, Engineering and Technology. Int. J. Geol. Environ. Eng. 11(6) (2017). https://www.waset.org/publications/10007231
  2. 2.
    Daoyong, Y.; Chengyao, S.; Jiguo, Z.; Guangqing, Z.; Yanmin, J.; Junmin, G.: Performance evaluation of injectivity for water-alternating-\(\text{ CO }_{2}\) processes in tight oil formations Fuel. 139(1), 292–300 (2015).  https://doi.org/10.1016/j.fuel.2014.08.033. ISSN 0016-2361
  3. 3.
    Wan, T.; Sheng, J.J.; Soliman, M.Y.: Evaluate EOR potential in fractured shale oil reservoirs by cyclic gas injection. In: Unconventional Resources Technology Conference, Denver, Colorado, 12–14 August 2013: pp. 1845–1854 (2013).  https://doi.org/10.1190/urtec2013-187
  4. 4.
    Mohammad, R.S.; Zhao, X.; Zhang, S.; et al.: Arab. J. Sci. Eng. 42, 1633 (2017).  https://doi.org/10.1007/s13369-016-2347-4 CrossRefGoogle Scholar
  5. 5.
    Wei, Y.; Lashgari, H.R.; Wu, K.; Sepehrnoori, K.: CO2 injection for enhanced oil recovery in Bakken tight oil reservoirs. In Fuel 159, 354–363 (2015).  https://doi.org/10.1016/j.fuel.2015.06.092. ISSN 0016-2361CrossRefGoogle Scholar
  6. 6.
    Zhang, Y.; Lashgari, H.R.; Di, Y.; Sepehrnoori, K.: Capillary pressure effect on hydrocarbon phase behavior in unconventional reservoirs. Soc. Petrol. Eng. (2016).  https://doi.org/10.2118/180235-MS
  7. 7.
    Wan, T.; Meng, X.; Sheng, J.J.; Watson, M.: Compositional modeling of EOR process in stimulated shale oil reservoirs by cyclic gas injection. Soc. Petrol. Eng. (2014).  https://doi.org/10.2118/169069-MS
  8. 8.
    Nojabaei, B.; Siripatrachai, N.; Johns, R.T.; Ertekin, T.: Effect of saturation dependent capillary pressure on production in tight rocks and shales: a compositionally-extended black oil formulation. Soc. Petrol. Eng. (2014).  https://doi.org/10.2118/171028-MS
  9. 9.
    Zuloaga-Molero, P.; Yu, W.; Xu, Y.; Sepehrnoori, K.; Li, B.: Simulation study of CO2-EOR in tight oil reservoirs with complex fracture geometries. Sci. Rep. 6, 33445 (2016).  https://doi.org/10.1038/srep33445 CrossRefGoogle Scholar
  10. 10.
    Zhang, Y.; Wei, Y.; Sepehrnoori, K.; Di, Y.: Investigation of nanopore confinement on fluid flow in tight reservoirs. J. Petrol. Sci. Eng. 150, 265–271 (2017). https://doi.org/10.101016/j.petrol.2016.11.005. ISSN 0920-4105
  11. 11.
    Zhang, Y.; Di, Y.; Yu, W.; Sepehrnoori, K.: A comprehensive model for investigation of \(\text{ CO }_{2}\)-EOR with nanopore confinement in the Bakken tight oil reservoir. Soc. Petrol. Eng. (2017).  https://doi.org/10.2118/187211-MS
  12. 12.
    Guillermo, G.J.; Kuz, V.A.: Fluid Phase Equilibria. Critical shift of a confined fluid in a nanopore 220(1), 7–9 (2004).  https://doi.org/10.1016/j.fluid.2004.02.014. ISSN 0378-3812CrossRefGoogle Scholar
  13. 13.
    Firoozabadi, A.: Thermodynamics of Hydrocarbon Reservoirs. McGraw-Hill, New York City, New York (1999). http://www.openisbn.com/isbn/0070220719
  14. 14.
    Adamason, A.W.: Physical Chemistry of Surfaces, 5th edn. John Wiley & Sons, New York City (1990).  https://doi.org/10.1002/recl.19911100413 CrossRefGoogle Scholar
  15. 15.
    Reid, R.C.; Prausnitz, J.M.; Poling, B.E.: The Properties of Gases and Liquids. McGraw Hill, New York (1987). https://www.worldcat.org/oclc/801845464.
  16. 16.
    Kong, B.; Wang, S.; Chen, S.: Simulation and optimization of \(\text{ CO }_{2}\) Huff-and-Puff processes in tight oil reservoirs. Soc. Petrol. Eng. (2016) . https://doi.org/10.2118/179668-MS
  17. 17.
    Peng, D.Y.; Robinson, D.B.: A new two-constant equation of state. Ind. Eng. Chem. Fundam. 15, 59–64 (1976). http://pubs.acs.org/doi/pdf/10.1021/i160057a011
  18. 18.
    Li, L.; Lee, S. H.: Efficient field-scale simulation of black oil in a naturally fractured reservoir through discrete fracture networks and homogenized media. Soc. Petrol. Eng. (2008).  https://doi.org/10.2118/103901-PA
  19. 19.
    Xu, Y.; Cavalcante Filho, J.S.A.; Yu, W.; Sepehrnoori, K.: Discrete-fracture modeling of complex hydraulic-fracture geometries in reservoir simulators. Soc. Petrol. Eng. (2017).  https://doi.org/10.2118/183647-PA
  20. 20.
    Yellig, W. F.; Metcalfe, R. S.: Determination and prediction of CO2 minimum miscibility pressures (includes associated paper 8876). Soc. Petrol. Eng. (1980).  https://doi.org/10.2118/7477-PA
  21. 21.
    Christiansen, R.L.; Haines, H.K.: Rapid measurement of minimum miscibility pressure with the rising-bubble apparatus. Soc. Petrol. Eng. (1987).  https://doi.org/10.2118/13114-PA
  22. 22.
    Eksharkaway, A.M.; Poettmann, F.H.; Christiansen, R.L.: Measuring CO2 minimum miscibility pressures: slim-tube or rising bubble method? Energy Fuels 10, 443 (1996).  https://doi.org/10.1021/ef940212f CrossRefGoogle Scholar
  23. 23.
    Rao, D.N.: A new technique of vanishing interfacial tension for miscibility determination. Fluid Phase Equilibria 139(1–2), 311–324 (1997).  https://doi.org/10.1016/S0378-3812(97)00180-5. ISSN 0378-3812CrossRefGoogle Scholar
  24. 24.
    Ahmad, W.; Vakili-Nezhaad, G.; Al-Wahaibi, Y.; Al-Bemani, A.S.: Experimental determination of minimum miscibility pressure. Proc. Eng. 148, 1191–1198 (2016).  https://doi.org/10.1016/j.proeng.2016.06.629. ISSN 1877-7058CrossRefGoogle Scholar
  25. 25.
    Zi-Sen W. et al.: Lattice Boltzmann simulation of fluid flow in complex porous media based on CT image. J. Indu. Intel. Inf. 4(1) (2016). www.jiii.org/uploadfile/2015/1204/20151204045745694.pdf
  26. 26.
    Hawthorne, S.B.; Gorecki, C.D.; Sorensen, J.A.; Steadman, E.N.; Harju, J.A.; Melzer, S.: Hydrocarbon mobilization mechanisms from upper, middle, and lower bakken reservoir rocks exposed to CO. Soc. Petrol. Eng. (2013).  https://doi.org/10.2118/167200-MS

Copyright information

© King Fahd University of Petroleum & Minerals 2018

Authors and Affiliations

  • Rashid S. Mohammad
    • 1
  • Shicheng Zhang
    • 1
  • Ehsan-ul-Haq
    • 2
  • Ahmed M. AlQadasi
    • 1
  1. 1.Oil-Gas Field Development EngineeringChina University of PetroleumBeijingChina
  2. 2.Geological and Geosciences DepartmentChina University of PetroleumBeijingChina

Personalised recommendations