Use of Net-to-Gross (NTG) concept in reservoir modeling has been a debate as it involves choice of cutoff, a simplified representation of reality. In-place hydrocarbon volumes highly depend on the cutoff, thus some authors suggest avoiding use of this concept. However, when building a reservoir model, a process involving upscaling the well log curves to the reservoir grid resolution is often needed. This requires the investigators to account for the portion of an active cell that can allow fluid to flow. Thus, when carefully evaluated, the NTG method can be a necessary and acceptable approximation. From outcrop studies we also observe that no turbidite sequences have consisted of 100% net reservoir sands. The variations of net sand percentages depend on the vertical and lateral variations of strata that serve as the building bricks of the overall sequences. Several methods have been tested to model the NTG for various deepwater reservoirs in the Gulf of Mexico (GOM): Calibration of acoustic impedance (AI) curve into NTG from each individual well and propagating the NTG using stochastic method guided by seismically inverted AI and facies distribution Scaling Gamma Ray (GR) or shale volume (VSH) curve to NTG by fixing the end members (sand and shale), scaling the curves linearly, and then conducting Sequential Gaussian Simulation to propagate NTG from wells to the reservoir model Using VSH cutoff to generate initial NTG for the wells, correlating the NTG with AI, and developing multi-relationships from the NTG-AI space to estimate NTG at the model scale. The multi-relationships serve as a tool for sensitivity test in the reservoir model Using total porosity frequency distribution from well logs to separate effective porosity for reservoir sands and uneffective porosity for non-reservoir rocks, then using porosity cutoff to distinguish sand from shale, and upscale the well log curves to model grid resolution to account for NTG Estimating NTG directly from whole cores Using some case studies, we compared the difference of in-place volumes estimated based on different approaches. The studies show that as long as the assumptions for each method are physically sound, the NTG estimates are consistent. We conclude that the NTG of deepwater reservoir sands and their connectivity are the most important factors controlling total resource distribution and flow capability.