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确定地质格架是构建地质和油藏模型的重要问题之一。它是确定流动单元、内插单井数据、进而模拟流体流动的基础。对于Seminole San Andres Unit(SSAU)地层,由露头类比和岩心识别的高频旋回(HFC)及岩石组构相被用于与电测曲线进行关联。在作为地质格架的高频旋回内用岩石组构单元构建了SSAU露头和SSAU两个区块的油藏模型和模拟模型。使用这些模型进行模拟,以查明影响采收率的关键因素。高频旋回和岩石组构单元是模拟浅水碳酸盐岩缓坡油藏的两个关键尺度。描述高频旋回内堆积的岩石组构相为构建地质和油藏模型提供了最精确的格架,因为离散的岩石物理参数可与岩石组构进行拟合,并可用岩石组构流动单元间的K_h值来近似流体流动。应用特定岩石组构的粒间孔隙度和渗透率之间的转换式计算渗透率。岩心分析数据表明孤立孔洞孔隙度对测量相对渗透率和毛细管压力具有非常强烈的影响。本文研究了地层约束条件对随机模拟的影响。同时对用传统的线性内插法、具有地层约束条件的随机模拟和无地层约束条件的随机模拟产生的各种地质模型进行了比较。只有当随机实现由岩石组构流动单元约束时才能观察到碳酸盐岩的地层特征。这些实现的随机模拟结果在采收率上相似,但在产量和注入率上却存在差别。就垂直渗透率和水平渗透率的比值(K_(vh)),研究了渗透率在垂向上的放大。随垂向网格尺寸增至旋回的平均厚度20ft(6.1m),这一比值呈指数递减,且当网格大于20ft(6.1m)时,该值为高频旋回的平均厚度,K_(vh)值稳定在0.06。模拟结果表明影响采收率的关键因素是岩石组构流动单元的叠置型式、k_(vh)值和致密泥灰岩的分布。
Determine the geological framework is one of the important issues in the construction of geological and reservoir models. It is the basis for identifying flow cells, interpolating single well data and then simulating fluid flow. For the Seminole San Andres Unit (SSAU) formation, the high-frequency cycles (HFCs) and petrofacies identified by outcrop analogies and cores are used to correlate electrical measurements. The reservoir model and simulation model of SSAU outcrop and SSAU block were constructed by rock constitutive units in the high-frequency cycle as a geological framework. These models were used to simulate to identify the key factors affecting recovery. High-frequency cycles and rock structural units are two key criteria for simulating shallow-water carbonate gentle-slope reservoirs. The description of the rock-facies assemblages that have been deposited in high-frequency cycles provides the most accurate framework for building geologic and reservoir models because discrete petrophysical parameters can be fitted to rock compositions and can be expressed in terms of rock composition K_h value to approximate the fluid flow. Permeability is calculated using the transition between intergranular porosity and permeability for a particular rock fabric. Core analysis data show that isolated pore porosity has a very strong effect on measuring relative permeability and capillary pressure. This paper studies the influence of stratum constraints on stochastic simulation. At the same time, we compared the various geological models generated by traditional linear interpolation, stochastic simulation with stratum constraints and stochastic simulation without stratum constraints. Stratigraphic features of carbonate rocks can only be observed when stochastic implementation is constrained by the flow of petrostructures. The stochastic simulations of these implementations are similar in recovery, but differ in yield and injection rates. In the vertical permeability and horizontal permeability ratio (K_ (vh)), the permeability of the vertical amplification. This ratio decreases exponentially as the vertical grid size increases to a gyratory average thickness of 20 ft (6.1 m), and is the mean thickness of the high-frequency cycle when the grid is greater than 20 ft (6.1 m). K_ (vh ) Value is stable at 0.06. The simulation results show that the key factor influencing oil recovery is the superimposition type, k vh value of flow units and the distribution of compact marl.