Water Injection Adjustment Methods Based on Dynamic Flow Resistance

doi:10.7657/XJPG20230407

Abstract

Abstract:

For the reservoirs in late development stage with ultra-high water cut, which exhibit significant difference in the oil-water two-phase flow capacity and strong dynamic reservoir heterogeneity, the injector interval subdivision method based on static parameters such as permeability and the interval water allocation method using empirical analysis are insufficient to meet the requirements of precise development of multi-layered sandstone reservoirs. Through theoretical analysis, physical simulation, and numerical modeling, the flow behaviors in the oilfields in late development stage with ultra-high water cut were further understood. A flow resistance calculation model for reservoir layers was developed, and aiming at minimizing the variation coefficient of flow resistance in single wells, a method for water injection interval optimization based on flow resistance was established. Additionally, by constructing coefficients of remaining reserves, reasonable injection-production ratio, relative water injection efficiency, and water cut rising rate for intervals, a quantitative adjustment method for water injection in the intervals with ultra-high water cut was developed. This method allows for quantitative water injection under conditions involving multiple wells, multiple layers, and complex injection-production relationships. The method was tested 237 times in wells of a typical block, with a decrease in initial water cut by 0.14%, demonstrating a satisfactory performance in both water control and oil increasement.

Key words: late development stage with ultra-high water cut, heterogeneity, flow resistance, interval optimization, water injection efficiency, water volume adjustment, remaining reserves

CLC Number:

TE341

SHAN Gaojun, WANG Chengxiang, WANG Zhiguo, JIANG Xueyan, GUO Junhui. Water Injection Adjustment Methods Based on Dynamic Flow Resistance[J]. Xinjiang Petroleum Geology, 2023, 44(4): 435-441.

Figures/Tables 8

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Table 1.

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