Despite significant hydrocarbon production in the UQ field, the reservoir complexity and heterogeneity have made it challenging to accurately characterize the reservoir properties. Hence, the goal of this research was to conduct a complete facies analysis and rock properties characterization of the UQ field in order to improve reservoir understanding and optimize hydrocarbon production. In this research, petrophysical and facies analyses of the UQ field utilizing well logs were conducted. Porosity, permeability, water saturation, net to gross ratio, and net pay thickness are some of the petrophysical characteristics that were taken into account in this study. Four wells in total were taken into account for the investigation, and four reservoirs were successfully identified. The reservoir sands' depositional facies and environment were distinguished using the gamma ray log. Each well underwent a thorough investigation of its petrophysical properties, and the reservoir thickness, net pay, net-to-gross ratio, porosity, and water saturation were all computed. The reservoirs had good petrophysical characteris-tics, with total gross thicknesses ranging from 218.87 to 584.76 feet and net to gross thicknesses varying from 157 to 414 feet due to shale intercalations. The reservoir's N/G ratio of 81% shows that reservoir sands occupy a larger share of the rock's bulk volume. The reservoirs' average water saturations range from 0.17 to 0.41. In general, it is seen that the porosity values within the wells are declining. The four reservoirs' estimated average porosities were between 0.24 and 0.30. The reservoir sands' impacts on particle size and sorting may be primarily responsible for the porosity values. The gamma ray log's form was used to establish the depositional setting for each reservoir. The majority of the basin floor fans and slope fan systems made up the depositional environment for the reservoirs.
Thompson et al. (Fri,) studied this question.