| At present, the horizontal well techniques have been widely used in oil development, especially in the development of bottom water reservoir. Because of the production of horizontal have the characteristics such as production pressure differential small and discharging oil, large area can slow bottom water ridge, control water rise in speed, increased production, improve the development result liquid entrainment .It have been applied more and more widely in oil production.Based on the oil production history of Q2 blocks, combined with the evaluation empirical formulas and theoretical formula for water flooding through recovery, moisture content, water cut the rate, pressure maintain a level, well network calculation of the adaptability of development indexes in this block development effect, comprehensive analysis the development effect, Results show that the prediction of the biggest block cumulative yield for 25.69×10~4t, and eventually water drive recovery for 31.48%; From September 2005 block until September 2010, converted the water injection development in a relatively short time, converted water injection to June 2010, after June 2010 water utilization effect became poor, to the later water flooding measure effect became worse; before water injection block pressure retain poor level, but after water injection, stress levels remain better; According to the water flooding reserves control degree and waterflooding reserves producing degree evaluation ,it appeared injection-production patterns nets are not suitable to present mining situation, need to convert development mode.Taking use of numerical simulation techniques, we built a geological model according to the actual reservoir by petrel software and studied the remaining oil distribution of blocks by eclipse software. The history matching resulted that: the calculation of geological reserves is 8.25×10~4t, the actual geological reserves is 81.6×10~4t, the relative error is 1.0%, calculation of cumulative oil production is 12.77×10~4t, the actual data is 12.95×10~4t, the relative error is only0.3%, a simulation of comprehensive moisture content is 20.87%, the actual moisture content is 20.68%, relative error was 0.4%.The depth of current oil-water interface is -2575m. the top oil are not flooding, bottom basic reservoir water flooding serious, low parts potential layer is mainly distributed in the 1-7 layers and height area of 8, 9, 10 layers. residual oil reserve gradually diminishing longitudinal, mainly distributed in 1~10 layers. The recovery degree of each layer is uneven, the 2, 3, 6, 7 layer recovery degree is higher.Though the selection of injection wells, injection wells in the reservoir level position, the horizontal oil well horizontal length of three categories of comparison of 10 programs, the optimal well spacing program Option 3, that is, in the original well pattern for a new deployment horizontal injection wells and one horizontal wells h5 h4, h5 deployed in the block to take the edge of the horizontal wells in the central parts of water, h4 deployed in the high parts of the central block, the horizontal section of about 450m in length, the original injection wells 14-312 and 15-313 to production wells, To predict the end of September 2030, cumulative oil production was 31.80×10~4t, cumulative growth over the oil based solution 6.41×10~4t, 38.97% degree of recovery, recovery value-added 8.13%, moisture content was 91.05%. |
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