Mohammed Thaiban Al-Garni, Bandar Duraya Al-Anazi


The main task of a petroleum reservoir engineer is to produce oil and gas reservoirs with maximum economic rate and reaching the ultimate recovery. Reservoir evaluation processes need a reservoir description as completely and accurately as possible using a variety of methods from seismic and well testing to logging, cuttings analysis and coring. These methods present the engineer with a valuable and wide range of scales of information to well evaluate the reservoir and control its performance and improve oil recovery. The main goal of core analysis is to reduce uncertainty in reservoir evaluation processes created by the uncertainty degree in the input parameters at the different levels from reserve estimate level to the enhancement of reservoir performance level. In order to reach these targets, the exact determination of certain petrophysical properties are necessary such as rock porosity, relative permeability, water saturation, and capillary pressure at all stages of reservoir life and rock wettability. Predicting reservoir wettability and its effect on fluid distribution and hydrocarbon recovery remains one of the major challenges in reservoir evaluation and engineering. Current laboratory based techniques require the use of rock-fluid systems that are representative of in situ reservoir wettability. Several parameters like relative permeability's, residual saturations, and capillary depressurization curves change with the wettability state of the reservoir. In addition all these parameters, can greatly impact oil recovery. Thus, there is a need to relate all these parameter to wettability state of the reservoir.
In this study, irreducible oil saturation and capillary pressures using rock centrifuge measurements for Berea Sandstone rock samples and Saudi oils will be tested during drainage and imbibitions cycles by varying each time the wettability of the tested samples by using different Saudi oils (Heavy, Medium, and Light). The capillary pressure for the aged samples will be measured again by the rock centrifuge. Hence, the changes in capillary pressure curve before and after wettability alteration will be obtained. Hence, wettability, capillary pressure, initial fluids saturation, will be correlated for Saudi reservoirs.

Полный текст:



>1. Anderson,W.G.: “Wettability Literature Survey – Part 2: Wettability Measurement”, JPT (Nov.1986) 1246-1262.

2. Anderson,W.G.: “Wettability Literature Survey – Part 4: Effects of Wettability on Capillary Pressure”, JPT (Oct. 1987) 1283-1300.

3. Anderson,W.G.: “Wettability Literature Survey – Part 5: Effects of Wettability on Relative Permeability”, JPT (Nov. 1987) 1453-1468.

4. Babadagli, T.: "Analysis of Oil Recovery by Spontaneous Imbibition of Surfactant Solution," SPE 84866, SPE International IOR Conference, 2003.

5. Anderson, W.G.: "Wettability Literature Survey-Part 1: Rock/Oil/Brine Interactions, and the Effects of Core Handling on Wettability," JPT (Oct. 1986) 1125-44.

6. Anderson, W.G.: "Wettability Literature Survey-Part 3: "The Effects of Wettability on the Electrical Properties of Porous Media," JPT (Dec. 1986) 1371-78.

7. Fatt, I. and Klikoff, W. A.: "Effect of Fractional Wettability on Multiphase Flow through Porous Media," Trans., AIM (1959) 216, 426-32.

8. Singhal, A. K., Mukherjee, D.P., and Somerton, W.H.: "Effect of Heterogeneous Wettability on Flow of Fluids through Porous Media," J. Cdn. Pet. Tech. (July-Sept. 1976) 15, No. 3, 63-70.

9. AS DAHAB, A. OMAR, M.H. SAYYOUH, and A. HEMEIDA "Effects of Clay Content on Permeability Damage, Capillary Pressure and Wettability Characteristics of Saudi Reservoir Rocks", Journal of The Japan Petroleum Institute .Vol. 36, No.3, May, 1993

10. Christoffersen K.R. and C.H. Whitson, 1995: “Gas/Oil Capillary Pressure of Chalk at Elevated Pressures”, SPE Formation Evaluation, SPE 26613, p 153-159.

11. Hirasaki G.J., 1991: ”Wettability: Fundamentals and Surface Forces”, SPE Formation Evaluation,SPE 17367, p 217-232.

12. Dahab, A. S., Omar, A. E., EI-Gassier, M. M., Awad el Kariem, H., Revue de l'Institut Francais de Petro Ie, 44, 5,(1989).

13. Leverett, M. C., “Capillary Behavior in Porous Solids,” Trans. AIME, 1941.

14. Timur, A., “An Investigation of Permeability, Porosity, and Residual Water Saturation Relationships,” AIME, June 1968.

15. Dykstra, H., and Parsons, R. L., “The Prediction of Oil Recovery by Water Flood,” In Secondary Recovery of Oil in the United States, 2nd ed., pp.160–174. API, 1950.

16. Geertsma, J., “The Effect of Fluid Pressure Decline on Volumetric Changes of Porous Rocks,” Trans. AIME, 1957, pp. 210, 331–340.

17. Baker, O. and Swerdloff, W., “Calculations of Surface Tension-3: Calculations of Surface Tension Parachor Values,” OGJ, December 5, 1955, Vol.43, p. 141.

18. Rose, W. D., and Bruce, W. A., “Evaluation of Capillary Character Petroleum Reservoir Rock,” Trans. AIME, 1949, pp. 127, 186.

19. Craft, B., Hawkins, M., and Terry, R., Applied Petroleum Reservoir Engineering, 2nd ed. Prentice Hall, 1991.

20. Dake, L. P., Fundamentals of Reservoir Engineering. Amsterdam: Elsevier,1978.

21. Dake, L., The Practice of Reservoir Engineering. Amsterdam: Elsevier,1994.

22. Edwardson, M. et al., “Calculation of Formation Temperature Disturbances Caused by Mud Circulation,” JPT, April 1962, pp. 416–425; Trans. AIME, p. 225.

23. Buckley, S., and Leverett, M., “Mechanism of Fluid Displacement in Sands,” Trans. AIME, 1962, Vol. 146, p. 107.

24. Deppe, J., “Injection Rates—The Effect of Mobility Ratio, Areal Sweep, and Pattern,” SPEJ, June 1961, pp. 81–91.

25. Muskat, M., Flow of Homogeneous Fluids Through Porous Systems. Ann Arbor, MI: J. W. Edwards, 1946.

26. Johnson, C., “Prediction of Oil Recovery by Waterflood - A Simplified Graphical Treatment of the Dykstra-Parsons Method,” Trans. AIME, 1956,Vol. 207, pp. 345–346.


  • На текущий момент ссылки отсутствуют.

© 2021 УГНТУ.
Все права защищены.