1. NUMERICAL SIMULATION OF NITROGEN FOAM FLOODING IN HIGH WATER-CUT STAGE OF HIGH-POROSITY AND HIGH-PERMEABILITY RESERVOIR.
- Author
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Jie Liu, Xuejiao Li, Kai Zhang, Chunyan Yang, Shuting Guo, Jingjing Xiao, and Mei Shi
- Abstract
Nitrogen foam fluids play an increasingly important role in oil displacement and profile control and water shutoff. In this paper, taking the H9-05 well group of SY Oilfield as an example, we systematically conducted a numerical simulation study of nitrogen foam flooding in a high water-cut stage of a high-porosity and high-permeability reservoir. Considering structures, a three-dimensional geological model of the target layer is constructed. The remaining oil is scattered, the oil well rows are relatively concentrated, the angle wells are more, and the oil well rows are less (related to the water injection time). The main oil layers are heavily washed and scattered. The remaining oil saturation of H4, H5, H9 and H12 oil layers is low. The remaining oil of HI and H3 oil layers is relatively rich due to poor reservoir physical properties. The influencing factors of nitrogen foam profile control effect were analyzed, the influencing factors of nitrogen foam profile control effect were analyzed, including injection mode, injection stage, surfactant concentration, gas-liquid ratio, and PV value of main slug injection. Studies have shown that the optimal main slug should be divided into three small slugs for injection. The best injection time should be before the water cut of the H9-05 well group reaches 90% to 91%. The optimum range of the mass concentration of the main slug surfactant should be 0.75% to 1.0%. According to the numerical simulation results, the gas-liquid ratio of the main slug should be controlled in the range of 0.7~1.5. The PV number of the main slug should be between 0.15PV and 0.2PV when the maximum oil increase is obtained with a lower injection cost. [ABSTRACT FROM AUTHOR]
- Published
- 2022