本文選題：單因素分析 + 灰色關聯(lián)��； 參考：《東北石油大學》2017年碩士論文

【摘要】：隨著油田注水開發(fā)逐漸進入尾聲,聚驅(qū)已經(jīng)成為當前油田開發(fā)的主要增產(chǎn)措施。但是由于儲層物性參數(shù)、地質(zhì)結(jié)構(gòu)等多方面因素的影響,要進行合理開發(fā)油田,實現(xiàn)增產(chǎn)增油,仍需綜合考慮,配置合理生產(chǎn)工藝參數(shù),進而實現(xiàn)優(yōu)化開發(fā)的效果。大慶南七區(qū)地質(zhì)結(jié)構(gòu)復雜,新老油層發(fā)育存在較大差別,部分儲層動用效果差,加之斷層發(fā)育的影響,為實現(xiàn)注聚不同階段的合理開發(fā)增加了難度。注采壓力梯度與聚驅(qū)效果緊密相關,如何構(gòu)建一個合理的聚驅(qū)壓力梯度,顯得尤為重要。本文以南七區(qū)新老油井以及測井解釋資料為基礎,利用Petrel建立地質(zhì)模型,對南七儲層進行精細油藏描述。同時利用Petrel建模結(jié)果在Eclipse軟件中進行數(shù)值模擬。結(jié)合單因素分析以及灰色關聯(lián)權(quán)重計算分析方法篩選出影響地層壓力的因素,并通過建立的簡易聚驅(qū)井流入動態(tài)模型以及礦場實際區(qū)域?qū)Ρ鹊确椒ù_定合理流壓界限。最終結(jié)合已確定的影響聚驅(qū)壓力梯度的因素以及確定的流壓界限進行數(shù)值模擬方案優(yōu)化,從而確定聚驅(qū)不同階段合理的壓力梯度界限并實現(xiàn)注采方案的優(yōu)化。進而對比分析合理壓力梯度界限對采收率以及波及系數(shù)的影響。結(jié)果表明:影響南七區(qū)地層壓力的因素主要有注入強度、產(chǎn)液強度、注入濃度,在聚驅(qū)的不同階段,南七區(qū)的流壓界限不盡相同。南七區(qū)注聚初期的流壓界限在4.7~7.5MPa,下降期在2.5~4.5MPa,回升期在4~5.7MPa。合理的壓力梯度界限初期在0.076~0.094MPa/m間,下降期在0.091~0.107MPa/m間,回升期在0.095~0.116MPa/m之間。采收率和波及系數(shù)均隨壓力梯度增加而增加,從中期到后期波及系數(shù)受壓力梯度影響較小。
[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.
【學位授予單位】：東北石油大學
【學位級別】：碩士
【學位授予年份】：2017
【分類號】：TE357.46
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本文編號：2052837