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在建立地质和储层模型中最重要的问题是确定地质格架,它是确定流动单元,推导井的数据和模拟流体流动的基础。对于Seminole San Andres单元(SSAU),根据露头模拟和岩芯确定的高频率旋回(HFC′S)和岩石组构单元可用来校正电缆测井。用作为一种地质格架的HFC′S内的岩石组构单元来建立SSAU两条剖面区储层和露头的模拟模型。使用这些模型对影响采收率关键因素的研究进行模拟。在模拟浅海碳酸盐岩缓坡储层中,HFC′S和岩石组构单元是两项关键的尺度。对叠加在HFC′S内的岩石组构相加以描述,可为建立地质和储层模型提供最准确的格架。因为不连续的岩石物性函数可与岩石组构相拟合,而流体的流动能与岩石组构流动单元之间的Kh值相适应。利用粒间孔隙度和渗透率之间的岩石组构特殊转换就可以计算渗透率。岩芯分析数据表明:分离的晶洞孔隙对影响相对渗透率和毛细管压力的测量有着巨大的作用。我们研究了对随机模拟的地层限制的影响。对比了常规性线型推导产生的地质模拟,以及具有地层限制的随机模型和没有地层限制的随机模型。只有当受到岩石组构流动单元的制约时,碳酸盐岩的地层形态才可能在随机识别中被观察到。在现实中的模拟结果与采收率的模拟结果一样,但不同于产量知注入量的模拟结果。根据垂向渗透率和水平渗透率的比值(Kvh),研究了渗透率在垂向上的递增。随着垂直网格块尺寸上升到平均旋回尺寸20英尺(6.1米),渗透率比值呈指数下降,并保持了对网格块尺寸超过20英尺(为HFC′S的平均厚度)的0.06的数值。从模型中得出结果表明:影响采收率的主要因素是—岩石组构流动单元的叠加形式。Kvh和致密泥岩的分布。
The most important issue in establishing geologic and reservoir models is determining the geologic framework, which is the basis for identifying flow cells, deriving well data and simulating fluid flow. For the Seminole San Andres unit (SSAU), high-frequency cycles (HFC’s) and rock formation units based on outcrop and core determinations can be used to correct cable logs. A simulation model of reservoir and outcrops in the SSAU two profile zones was established using rock structural units within HFCs as a geological framework. These models were used to simulate the study of the key factors affecting oil recovery. In simulating shallow-sea carbonate gentle-slope reservoirs, HFC’s and rock structural units are two key dimensions. The addition of the rock composition superimposed on the HFC’s to describe it provides the most accurate grid for establishing geological and reservoir models. Because the discontinuous petrophysical function can be fitted to the rock composition, the fluid flow can be adapted to the Kh value between the flow elements of the rock structure. Permeability can be calculated using a special transformation of rock composition between intergranular porosity and permeability. Core analysis data show that the separation of caves pores has a huge effect on the measurement of relative permeability and capillary pressure. We studied the effect of stratigraphic constraints on stochastic simulations. Comparisons of the geological modeling generated by conventional linear derivation, as well as the stochastic model with stratigraphic restriction and the stochastic model without stratigraphic limitation. Only when constrained by the flow unit of the rock structure, can the formation pattern of carbonate rocks be observed in stochastic identification. The simulation results in reality are the same as the simulation results of recovery but different from the simulation results of injection yield. Based on the ratio of vertical permeability to horizontal permeability (Kvh), the vertical permeability increase was studied. As the vertical grid block size increases to a mean spin size of 20 feet (6.1 meters), the permeability ratio decreases exponentially and maintains a value of 0.06 for grid block sizes over 20 feet (the average thickness of HFC’s) . The results from the model show that the main factor affecting oil recovery is the superposition of the flow units in the rock structure. Distribution of Kvh and tight mudstone.