Agradecimentos: The authors are grateful to the Center of Petroleum Studies (Cepetro-Unicamp/Brazil), PETROBRAS-Brazil (Grant Agreement No.0050.0022715.06.4), UNISIM and the Petroleum Engineering Department (DEP-FEM-Unicamp/Brazil) for their support of this work. The authors are also grateful to...

Agradecimentos: The authors are grateful to the Center of Petroleum Studies (Cepetro-Unicamp/Brazil), PETROBRAS-Brazil (Grant Agreement No.0050.0022715.06.4), UNISIM and the Petroleum Engineering Department (DEP-FEM-Unicamp/Brazil) for their support of this work. The authors are also grateful to Schlumberger Information Solution for the use of Petrel® and Computer Modelling Group for the use of Black Oil reservoir simulator IMEX

Matrix-to-fracture transfer functions assume that fractures are instantaneously filled with water, leading to constant, time-independent shape factors. However, the water filling fracture regime, which can be observed for some conditions such as small injection rates, does not lead to constant...

Matrix-to-fracture transfer functions assume that fractures are instantaneously filled with water, leading to constant, time-independent shape factors. However, the water filling fracture regime, which can be observed for some conditions such as small injection rates, does not lead to constant shape-factors and is difficult to solve using commercial flow simulators. The purpose of this study is to (1) show the impact of rock wettability in reservoir simulation and upscaling procedures, and, (2) apply an upscaling matching procedure based on time-dependent matrix-fracture fluid transfer term. This work shows that the increase of rock preference for water can lead to upscaling limitations due to the partially immersed fractures behavior observed in cases with small fracture apertures and small injection rates, for water-wet rocks. A time-dependent matrix-fracture fluid transfer term was proposed for upscaling matching procedures. The developed method solves the limitation of time-independent shape factors and allows the dual porosity flow model to properly represent the dynamic behavior for different wettability scenarios. This work aims to contribute for understanding the impact of rock wettability in upscaling and reservoir simulation of fractured reservoirs and, provides solutions for flow simulation of dual porosity flow models under a water filling-fracture regime, which is common in water-wet rocks

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