测井探测范围内井周剩余油分布、相对渗透率与核磁响应关系研究

绝对渗透率决定产液能力，相渗决定产液性质，相同的含油饱和度可以有不同的剩余油气分布和相渗特性,这是导致测井储层流体性质识别或水淹层解释困难的关键因素。本项目在测井探测范围内，通过多种核磁实验技术（一维、二维、三维成像）和核磁测井结合，应用不同尺度（全直径、常规柱塞、毫米尺度）CT扫描数字岩心技术和核磁成像实验技术，定量表征尺度因子、层理、纹层、裂缝、沉积韵律、侵入（驱替）等宏观参数变化下剩余油空间分布和孔隙分布（大、中、小、微孔隙）规律；通过构建多尺度融合的数字岩心模型研究剩余油分布算法和相对渗透率计算模型，并与T2 mapping相对渗透率计算方法交互检验；进一步建立不同含油性条件下剩余油分布和相对渗透率与核磁的对应关系和判别模型；通过核磁T2谱重构技术、水谱提取技术把建立的核磁判别模型拓展到一维、二维核磁测井，探索复杂储层定量评价和流体性质识别新方法。

Absolute permeability dominates liquid-producing capacity, while phase permeability determines liquid-producing property. Residual oil/gas distribution and phase permeability characteristics may vary drastically with the same oil saturation, which are the key factors for identifying reservoir fluid properties and interpreting water flooded layers. This project intends to combine the NMR logging and multiple NMR experiment technology (1D, 2D, 3D imaging) in the logging detection range. With the use of multi-scale(whole core scale, core plug scale, millimeter scale) digital core technology and NMR imaging experiment technology, we characterize the law of residual oil distribution in space and pores(big, medium, small, tiny pores) quantitatively with different macro-factors such as scale factors, bedding, lamina, crack, sedimentary cycle, intrusion(displacement). We study the algorithm of residual oil distribution and models of relative permeability by using multi-scale digital core models and interactively verify the relative permeability calculated by T2 mapping, and set up the corresponding relations and discrimination models among residual oil distribution, relative permeability and NMR response in different oil containing conditions. Lastly we extend the residual oil distribution and relative permeability model to the 1D, 2D NMR logs with the T2 spectrum reconstitution and water spectrum extraction technology, and put forward a new approach for complex reservoir quantitative evaluation and fluid property identification.