塔河6-7区多井缝洞单元注水方式数值模拟研究
发布时间：2018-08-06 19:57
【摘要】：塔河6-7区缝洞型油藏目前是塔河油田注水开发的主力油藏,也是井组注水开发的国家技术攻关示范区块。本文围绕塔河6-7区开展了井组的注水方案和注水机理研究,难点在于缝洞形态复杂,地质模型的孔隙度场和渗透率场无法通过地震、测井等勘探手段准确测量出来,对注水动态起着至关重要的地质因素也无法通过地质手段进行识别,而孤立的油藏工程分析又存很大的多解性。 因此,本文以文献调研为基础,归纳总结溶洞型、缝洞型、缝孔型三类储层油水两相渗流特征,分析各自流体流动机理及动态特征；采用地质建模和数值模拟相结合方法将地质和开发动态特征相结合,作为研究6-7区油藏注水开发的有效手段；通过测井曲线矫正、建立渗透率模型和历史拟合等方法完善原始地质模型；根据注水见效期、稳定期、调整期三个阶段含水率特点,对注水方式的组合优化模拟,论证了最佳注水组合的模式及注采参数,以期为注水开发这类油藏提供技术参考。取得的主要成果如下： (1)每种典型单元的注水方式组合分别为：主干断裂典型单元最佳注水组合为先温和持续注水,后温和持续注水,最终转为周期注水的模式；次级断裂典型单元最佳注水组合为全过程周期注水的模式；表层岩溶典型单元最佳注水组合为先温和持续注水,后周期注水,最终转为间歇注水的模式；暗河岩溶典型单元最佳注水组合为先大排量持续注水,后温和持续注水,最终转为周期注水的模式。 (2)结合数值模拟方法与塔河6-7区矿场注水经验,对影响注水效果的注水强度、注水周期和注采比等参数优化后得出：1)主干断裂典型单元三种注水方式的优化结果为见效期持续注水强度范围80-150m3/d,注采比1.5～3.0,稳定期持续注水强度范围50-100m3/d,注采比1.0～1.5,调整期强度为50-80m3/d,注采比0.9左右的常规周期注水注15d停30d方式。2)次级断裂典型单元三种注水方式的优化结果为见效期强度为80-120m3/d,注采比1.0～1.25的常规周期注水注45d停60d方式,稳定期强度为40-100m3/d,注采比0.65-1.0的常规周期注水注30d停60d方式,调整期强度为40-80m3/d,注采比0.6～0.8的常规周期注水注15d停60d方式。3)表层岩溶典型单元三种注水方式的优化结果为见效期持续注水强度范围150-200m3/d,注采比1.5-2.5,稳定期强度为100-150m3/d,注采比1.0～1.5的常规周期注水注60d停15d方式,调整期强度为100-200m3/d,注采比1.0～1.5间隔30d的方式间歇注入。4)暗河岩溶典型单元三种注水方式的优化结果为见效期持续注水强度范围250～350m3/d,注采比2.5～4.5,稳定期持续注水强度范围100～150m3/d,注采比1.0-1.65,调整期强度为80-150m3/d,注采比1.0～1.5的常规周期注水注60d停15d方式。
[Abstract]:At present, fracture-cavity reservoir in Tahe 6-7 area is the main reservoir for water injection development in Tahe oilfield, and it is also the national technical demonstration area for water injection development of well group. In this paper, the water injection scheme and water injection mechanism of well group are studied around Tahe 6-7 area. The difficulty lies in the complexity of fracture and cavity morphology, the porosity field and permeability field of geological model can not be accurately measured by seismic and logging exploration methods. The geological factors that play an important role in water injection performance can not be identified by geological means, and the isolated reservoir engineering analysis has a great variety of solutions. Therefore, on the basis of literature research, this paper summarizes the oil-water two-phase percolation characteristics of three types of reservoirs, cavern type and fracture type, and analyzes their fluid flow mechanism and dynamic characteristics. The combination of geological modeling and numerical simulation is used to combine geological and development characteristics as an effective means to study water injection development in reservoirs in area 6-7. The permeability model and historical fitting method were established to perfect the original geological model, according to the characteristics of water cut in the three stages of water injection effect period, stable period and adjustment period, the combination optimization simulation of water injection mode was carried out. The optimal water injection combination model and injection-production parameters are demonstrated in order to provide a technical reference for waterflooding development of this kind of reservoir. The main results obtained are as follows: (1) the combination of water injection modes of each typical unit is: the best combination of water injection in the typical unit of main fault is first mild continuous injection, then mild continuous water injection, and finally the mode of periodic water injection; The best combination of water injection in the typical secondary fault unit is the mode of the whole process cycle water injection, and the best combination of water injection in the surface karst typical unit is the mode of first moderate continuous injection, then periodic water injection, and finally the mode of intermittent water injection. The best combination of water injection in typical karst units of the Shahe River is the mode of continuous water injection with large discharge first, followed by mild continuous water injection, and then converted to periodic water injection. (2) combined with numerical simulation method and field water injection experience of Tahe 6-7 area, For the water injection intensity that affects the water injection effect, After optimization of injection cycle and injection-production ratio, the optimization results of three water injection modes of typical unit of main fault are as follows: effective period continuous water injection intensity range 80-150 m3 / d, injection-production ratio 1.5% 3.0, steady period sustained water injection intensity range 50-100 m3 / d, injection-production ratio 50-100 m3 / d, injection-production ratio 1.50 m ~ 3 / d, injection / production range 50 ~ 100 m ~ (3 / d). The optimization results of three water injection modes of typical unit of secondary fault are as follows: the intensity of adjustment period is 50-80 m3 / d, the ratio of injection to production is about 0.9, the injection / production ratio is 0.9 or so, and the conventional cycle injection with injection / production ratio of 1.0 ~ 1.25) is optimized for the typical unit of secondary fault. The optimization results are as follows: the intensity of effective period is 80-120 m3 / d, and the ratio of injection to production is 1.0m ~ (3 / d). Water injection for 45 days, stop for 60 days, The stable period intensity is 40-100 m3 / d and the injection-production ratio is 0.65-1.0. The optimization results of three water injection modes of typical karst units in the surface layer are as follows: continuous water injection intensity of 150-200m3 / d, injection-production ratio of 1.5-2.5, stable period intensity of 100-150m3 / d, the intensity of adjusting period is 40-80m3 / d, injection / production ratio is 0.6 / d, and injection / production ratio is 0.6 ~ 0.8) the optimum results of three water injection modes are as follows: 150-200m3 / d in the typical unit of surface karst. The injection to production ratio of 1.0 ~ 1.5 is the normal mode of injection for 60 days and stops for 15 days. The intensity of adjustment period is 100-200 m3 / d, the injection-production ratio is 1.0 ~ 1.5 interval 30d interval, the interval is 30 days.) the optimization results of three water injection modes of typical unit of karst in the dark river are as follows: the range of continuous water injection intensity in effective period is 250 ~ 350m3 / d, the injection-production ratio is 2.5 ~ 4.5and the steady period is continuous injection. The range of water intensity is 100 ~ 150 m3 / d, the injection-production ratio is 1.0-1.65, the intensity of adjustment period is 80-150 m3 / d, and the injection-production ratio is 1.0 ~ 1.5.
【学位授予单位】：西南石油大学
【学位级别】：硕士
【学位授予年份】：2015
【分类号】：TE357.6
本文编号：2168827
[Abstract]:At present, fracture-cavity reservoir in Tahe 6-7 area is the main reservoir for water injection development in Tahe oilfield, and it is also the national technical demonstration area for water injection development of well group. In this paper, the water injection scheme and water injection mechanism of well group are studied around Tahe 6-7 area. The difficulty lies in the complexity of fracture and cavity morphology, the porosity field and permeability field of geological model can not be accurately measured by seismic and logging exploration methods. The geological factors that play an important role in water injection performance can not be identified by geological means, and the isolated reservoir engineering analysis has a great variety of solutions. Therefore, on the basis of literature research, this paper summarizes the oil-water two-phase percolation characteristics of three types of reservoirs, cavern type and fracture type, and analyzes their fluid flow mechanism and dynamic characteristics. The combination of geological modeling and numerical simulation is used to combine geological and development characteristics as an effective means to study water injection development in reservoirs in area 6-7. The permeability model and historical fitting method were established to perfect the original geological model, according to the characteristics of water cut in the three stages of water injection effect period, stable period and adjustment period, the combination optimization simulation of water injection mode was carried out. The optimal water injection combination model and injection-production parameters are demonstrated in order to provide a technical reference for waterflooding development of this kind of reservoir. The main results obtained are as follows: (1) the combination of water injection modes of each typical unit is: the best combination of water injection in the typical unit of main fault is first mild continuous injection, then mild continuous water injection, and finally the mode of periodic water injection; The best combination of water injection in the typical secondary fault unit is the mode of the whole process cycle water injection, and the best combination of water injection in the surface karst typical unit is the mode of first moderate continuous injection, then periodic water injection, and finally the mode of intermittent water injection. The best combination of water injection in typical karst units of the Shahe River is the mode of continuous water injection with large discharge first, followed by mild continuous water injection, and then converted to periodic water injection. (2) combined with numerical simulation method and field water injection experience of Tahe 6-7 area, For the water injection intensity that affects the water injection effect, After optimization of injection cycle and injection-production ratio, the optimization results of three water injection modes of typical unit of main fault are as follows: effective period continuous water injection intensity range 80-150 m3 / d, injection-production ratio 1.5% 3.0, steady period sustained water injection intensity range 50-100 m3 / d, injection-production ratio 50-100 m3 / d, injection-production ratio 1.50 m ~ 3 / d, injection / production range 50 ~ 100 m ~ (3 / d). The optimization results of three water injection modes of typical unit of secondary fault are as follows: the intensity of adjustment period is 50-80 m3 / d, the ratio of injection to production is about 0.9, the injection / production ratio is 0.9 or so, and the conventional cycle injection with injection / production ratio of 1.0 ~ 1.25) is optimized for the typical unit of secondary fault. The optimization results are as follows: the intensity of effective period is 80-120 m3 / d, and the ratio of injection to production is 1.0m ~ (3 / d). Water injection for 45 days, stop for 60 days, The stable period intensity is 40-100 m3 / d and the injection-production ratio is 0.65-1.0. The optimization results of three water injection modes of typical karst units in the surface layer are as follows: continuous water injection intensity of 150-200m3 / d, injection-production ratio of 1.5-2.5, stable period intensity of 100-150m3 / d, the intensity of adjusting period is 40-80m3 / d, injection / production ratio is 0.6 / d, and injection / production ratio is 0.6 ~ 0.8) the optimum results of three water injection modes are as follows: 150-200m3 / d in the typical unit of surface karst. The injection to production ratio of 1.0 ~ 1.5 is the normal mode of injection for 60 days and stops for 15 days. The intensity of adjustment period is 100-200 m3 / d, the injection-production ratio is 1.0 ~ 1.5 interval 30d interval, the interval is 30 days.) the optimization results of three water injection modes of typical unit of karst in the dark river are as follows: the range of continuous water injection intensity in effective period is 250 ~ 350m3 / d, the injection-production ratio is 2.5 ~ 4.5and the steady period is continuous injection. The range of water intensity is 100 ~ 150 m3 / d, the injection-production ratio is 1.0-1.65, the intensity of adjustment period is 80-150 m3 / d, and the injection-production ratio is 1.0 ~ 1.5.
【学位授予单位】：西南石油大学
【学位级别】：硕士
【学位授予年份】：2015
【分类号】：TE357.6
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