南七聚驱不同阶段合理压力梯度界限确定

发布时间：2018-06-22 12:30

  本文选题：单因素分析 + 灰色关联　； 参考：《东北石油大学》2017年硕士论文

【摘要】：随着油田注水开发逐渐进入尾声,聚驱已经成为当前油田开发的主要增产措施。但是由于储层物性参数、地质结构等多方面因素的影响,要进行合理开发油田,实现增产增油,仍需综合考虑,配置合理生产工艺参数,进而实现优化开发的效果。大庆南七区地质结构复杂,新老油层发育存在较大差别,部分储层动用效果差,加之断层发育的影响,为实现注聚不同阶段的合理开发增加了难度。注采压力梯度与聚驱效果紧密相关,如何构建一个合理的聚驱压力梯度,显得尤为重要。本文以南七区新老油井以及测井解释资料为基础,利用Petrel建立地质模型,对南七储层进行精细油藏描述。同时利用Petrel建模结果在Eclipse软件中进行数值模拟。结合单因素分析以及灰色关联权重计算分析方法筛选出影响地层压力的因素,并通过建立的简易聚驱井流入动态模型以及矿场实际区域对比等方法确定合理流压界限。最终结合已确定的影响聚驱压力梯度的因素以及确定的流压界限进行数值模拟方案优化,从而确定聚驱不同阶段合理的压力梯度界限并实现注采方案的优化。进而对比分析合理压力梯度界限对采收率以及波及系数的影响。结果表明:影响南七区地层压力的因素主要有注入强度、产液强度、注入浓度,在聚驱的不同阶段,南七区的流压界限不尽相同。南七区注聚初期的流压界限在4.7~7.5MPa,下降期在2.5~4.5MPa,回升期在4~5.7MPa。合理的压力梯度界限初期在0.076~0.094MPa/m间,下降期在0.091~0.107MPa/m间,回升期在0.095~0.116MPa/m之间。采收率和波及系数均随压力梯度增加而增加,从中期到后期波及系数受压力梯度影响较小。
[Abstract]:With the end of oilfield water injection development, polymer flooding has become the main measure to increase oil production. However, due to the influence of many factors, such as reservoir physical parameters and geological structure, in order to develop oil fields reasonably and to increase production and increase oil production, it is still necessary to consider synthetically and configure reasonable production process parameters to realize the effect of optimal development. The complex geological structure, the great difference in the development of new and old oil layers, the poor production effect of some reservoirs and the influence of fault development increase the difficulty of rational development in different stages of polymer injection. The pressure gradient of injection and production is closely related to the effect of polymer flooding, so how to construct a reasonable pressure gradient of polymer flooding is particularly important. Based on the new and old oil wells and logging interpretation data in Nanqi District, a geological model was established by Petrel to describe the reservoir in Nanqi area. At the same time, using Petrel modeling results in Eclipse software for numerical simulation. Combined with single factor analysis and grey correlation weight calculation method, the factors affecting formation pressure are screened out, and the reasonable flow pressure limit is determined by the simple model of inflow performance of polymer flooding well and the actual area correlation of mine field. Finally, combined with the determined factors affecting the pressure gradient of polymer flooding and the determined boundary of flow pressure, the numerical simulation scheme was optimized to determine the reasonable pressure gradient limits in different stages of polymer flooding and to realize the optimization of injection-production scheme. Then, the influence of reasonable pressure gradient limit on recovery efficiency and sweep efficiency is compared and analyzed. The results show that the main factors affecting formation pressure in Nanqi area are injection intensity, liquid production intensity and injection concentration, and the boundary of flow pressure is different in different stages of polymer flooding. The limit of flow pressure in the early stage of agglomeration in Nanqi region is 4.7 ~ 7.5MPa, in the descending period is 2.5 ~ 4.5MPa, and in the rising period is 40.5.7MPa. The reasonable pressure gradient at the initial stage is between 0.076 ~ 0.094 MPA / m, the descending period is 0.091 ~ 0.107 MPA / m, and the recovery period is between 0.095 ~ 0.116 MPA / m. Both the recovery factor and the sweep coefficient increase with the increase of the pressure gradient, and the sweep efficiency is less affected by the pressure gradient from the middle to the later stage.
【学位授予单位】：东北石油大学
【学位级别】：硕士
【学位授予年份】：2017
【分类号】：TE357.46
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本文编号：2052837