The Bone Spring and Wolfcamp formations of the Delaware Basin consist of mixed sediment gravity flow and suspension sedimentation deposits. These deposits exhibit high levels of heterogeneity both at and below core and log scales. Conventional characterization efforts are too coarse to capture small-scale changes in lithology, rock properties, and reservoir quality observed in these unconventional deposits. A key goal of this work is to develop a framework to delineate complex heterogeneities at core and log scales. Due to the heterolithic nature of these strata, an integrated, multiscale approach to unconventional reservoir characterization is required to understand factors controlling reservoir quality. This study utilizes well logs and core data from two key wells, including high-resolution image data from thin sections and SEM, to (1) identify facies across multiple scales and (2) provide an in-depth characterization of reservoir properties in the Bone Spring and Wolfcamp formations along the eastern margin of the Delaware Basin. An integrated approach utilizing core (721 ft.), thin sections (70 samples), XRD analysis (64 samples), and high-resolution images (882 images) identified a total of nine facies. Each facies is comprised of different textures, mineralogy, and pore types. These differences and their effects on reservoir properties are illustrated in this research. Core-based measurements of source rock properties and reservoir properties were used to identify two primary reservoir facies, two secondary reservoir facies, two marginal reservoir facies and three non-reservoir facies. Within the study area, Ward County, the Bone Spring and Wolfcamp formations are in the early mature oil window, the preponderance of maturity data suggest a likely maturity of about 0.8% Ro, ranging 0.69%Ro-0.91%Ro. Four reservoir facies are organically rich with average wt.% TOC as follows; argillaceous-siliceous mudstone (3.1 wt.%, n=21), argillaceoussiliceous siltstone (2.0 wt.%, n=7), calcareous-siliceous mudstone (3.0 wt.%, n=15), and calcareous-siliceous siltstone (2.3 wt.%, n=7). The two primary reservoir facies are mudstones and contain comparable bulk mineralogy to the two secondary reservoir facies, which are siliceous siltstones. Secondary reservoir facies contain more detrital grains and less organic matter than their finer-grained mineralogically-equivalent primary reservoir facies. Lower organic content in secondary reservoir facies is related to dilution of organic matter via iv extrabasinal influx of detrital grains and possible consumption by benthic fauna in oxygenated conditions. These detrital grains are associated with higher sedimentation rates which effectively dilutes initial organic content, consequentially constraining present day total organic carbon values. Origin and type of silica is important for reservoir quality. Non-reservoir facies, biogenic siliceous mudstone, is similar in bulk mineralogy to primary reservoir facies, argillaceous siliceous mudstone. The former contains the least amount of...