储层综合表征的主要目的是可靠地计算、表征和识别岩石物理参数，包括孔隙度、渗透率、岩石组构、孔径分布、孔隙网络系统、饱和度和毛管压力。这些基本的岩石物理特性可以通过在核心实验室中结合核磁共振 (NMR)、常规和特殊岩心分析 (CCAL/SCAL) 来实现。本研究采用岩心测量和核磁共振技术对 Gachsaran 油田 Asmari 碳酸盐组的 6 个岩心塞样品进行了检验，以评估和比较岩石物理性质。最初，通过芯塞、修整、溶剂清洗和烘箱干燥方法制备塞样品。井伽玛测井与岩心伽玛对比，将深度调整到储层目标的真实位置。然后在准备好的塞子上进行基本的 SCAL 测量，以计算孔隙度、渗透率、毛细管压力和流体运动。然后将干燥的样品用盐水完全饱和，并通过 NMR 方法重新测量基本性质。由 NMR 技术确定的岩石质量值（孔隙度和渗透率）与岩心结果之间的关系表明，通过对 NMR 模型值进行一些调整，可以获得精确的结果。本文中显示的孔径分布曲线证实了 NMR 模拟的孔喉曲线，并表明当与注汞毛细管压力 (MICP) 孔径分布一致时，NMR 可用作估计孔径分布的有用技术。NMR 伪毛管压力曲线与 MICP 测试的毛管压力和饱和行为一致。此外，通过薄片岩相图像检查岩性、岩石结构和孔隙形状，作为储层微观储层特征的代表。在目前的研究中，

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The main purpose of comprehensive reservoir characterization is to reliably calculate, characterize and identify petrophysical parameters including porosity, permeability, rock fabrics, pore size distribution, pore network system, saturation and capillary pressure. These essential petrophysical properties could be achieved by a combination of Nuclear Magnetic Resonance (NMR), conventional and special core analysis (CCAL/SCAL) in core laboratories. In this study, six core plug samples from the Asmari carbonate Formation in Gachsaran oilfield have been examined by the core measurements and NMR technique to evaluate and compare the petrophysical properties. Initially, the plug samples are prepared by core plugging, trimming, solvent cleaning and oven drying methods. Comparison between well Gamma ray log and core gamma ray adjust the depth to the real position of reservoir target. Basic SCAL measurements are then conducted on the prepared plugs in steps to calculate porosity, permeability, capillary pressure and fluid movements. Then the dry samples are completely saturated with brine and the basic properties are re-measured by the NMR method. The relationship between rock quality values (porosity and permeability) determined from NMR technique and core results demonstrate that by applying some adjustments on NMR modeled values, the precise results are achievable. Pore size distribution curves displayed in this paper confirm the NMR modeled pore throat curves and shows NMR could be applied as useful technique for estimating pore size distribution when they are in agreement with Mercury Injection Capillary Pressure (MICP) pore size distribution. The NMR pseudo capillary pressure curves show consistency with capillary pressure and saturation behavior of MICP tests. In addition, the lithology, rock fabric and pore shapes are checked by petrographic images of thin sections as representative of microscopic reservoir characteristics in the reservoir. In present study, applying of NMR technique to the plugs and comparison the obtained results with SCAL results demonstrate how the NMR technique can objectively and quantitatively provide petrophysical analysis for a carbonate reservoir and combination of core analysis and NMR technique could optimize reservoir quality investigation.