Facing problems with oil production decreasing quickly and water content increasing gradually in S103 well area, the Foam Profile Control was studied on the basis of its confirmed agent formula. The facies-controlled geological model of S103 well area was generated using random model based on Petrel software and using numerical simulation based on CMG software. Gas liquid alternating injection pattern was optimized as the optimal solution through the simulation optimization. Two months are optimized as the optimal solution through the simulation optimization. The cumulative oil production is 0.933 × 107 kg which is higher than the value of subsequent water flooding and the other three. Finally, it reaches the goals of slowing down the production decline and controlling the water rising.
 Z. L. Khatib, G. J. Hirasaki and A. H. Falls, “Effects of Capillary Pressure on Coalescence and Phase Mobilities in Foams Flowing Through Porous Media,” SPE Reservoir Engineering, Vol. 3, No. 3, 1988, pp. 919-926.
 A. W. Fisher, R. W. S. Fouiser and S. G. Goodyear, “Mathematical Modeling of Foam Flooding,” SPE/DOE Enhanced Oil Recovery Symposium, Tulsa, 22-25 April 1990, pp. 231-240.
 Z. Q. Li, G. H. Zhou and Z. M. Zhou, “The Feasibility Studies of Polymer Foam Flooding in Gudao Oilfield,” SPE Asia Pacific Oil & Gas Conference and Exhibition, Adelaide, 11-13 September 2006, pp. 1-8.
 H. Pei, G. Zhang, J. Ge, J. Wang, B. Ding and X. Liu, “Investigation of Polymer-Enhanced Foam Flooding with Low Gas/Liquid Ratio for Improving Heavy Oil Recovery,” Canadian Unconventional Resources and International Petroleum Conference, Calgary, 19-21 October 2010, pp. 1-11. http://dx.doi.org/10.2118/137171-MS