| Hydrocarbon resources such as tight sands have become one of the most sought after types of unconventional plays, given the extensive amounts of gas they contain. In order to access these reserves, the industry is focused on improving hydraulic fracturing techniques with the purpose of increasing gas recovery. However, proper reservoir management practices, in conjunction with improved completion processes, are also key factors for maximizing these gas reserves. Additionally, reservoir understanding becomes even more relevant when dealing with reservoirs deposited under complex fluvial environments.;This study integrates the accurate stratigraphy and detailed reservoir characterization of a 160-acre 3D fluvial geologic outcrop model with detailed hydraulic fracturing modeling to better understand the effects that fluvial depositional environments have on hydraulic fracture growth. Subsequently, the hydraulic fracturing growth parameters are implemented in a robust 3D reservoir simulation model, representing the heterogeneous geologic environment. Finally, reservoir simulation is used to determine the dynamic flow conditions associated with the fluvial geologic model with the ultimate goal of determining optimum reserve recovery practices such as well spacing and placement, hydraulic fracture design components, etc.;The methodology applied in this study, which starts with the 3D outcrop mapping and characterization, followed by the development of a geostatistical model, hydraulic fracturing modeling, and reservoir simulation are presented. Additionally, the results of a series of cases representing different well counts, locations, spacing, and perforated intervals within the fluvial reservoir model are shown.;Seven different cases, in two geologic models, consisting of various well locations and spacings, are described. First, three cases in a lower geologic model with well locations selected in the most prospective areas of the reservoir. Then, the production of a full field model, which includes the lower model plus an extended geologic interpretation of the outcrop, was evaluated using 40-acre, 20-acre, and 10-acre spacings. Finally, the implementation of a horizontal well was assessed in the full field model.;Results show that the continuity of sandstone bodies in the near wellbore vicinity, whether part of the completion interval or not, is critical to the ultimate reserve recovery and the hydraulic fracture growth pattern is greatly dependent on this sandstone continuity. Additionally, amalgamation of the sandstone bodies, which also affects the hydraulic fracture growth patterns, has a strong effect on gas recoveries. The benefits of infill drilling, in the stratigraphically lower model and in the combined stratigraphically lower and upper intervals, or full field model, comparing the 20-acre and 10-acre scenarios, were mainly obvious in reserve acceleration versus reserve addition. Conversely, in the full field model, the 20-acre spacing scenario achieved drainage of more sandstone bodies than the 40-acre spacing, resulting in an increase of reserves. Finally, for the reservoir evaluated in this study, the horizontal well results are not encouraging when compared to the vertical wells evaluated in the rest of the scenarios. |
