Analysis of Capillary Pressure and Relative Permeability Effects on the Productivity of Naturally Fractured Gas-Condensate Reservoirs

2010 ◽  
Author(s):  
Bander N. Al Ghamdi ◽  
Luis F. Ayala
Keyword(s):  
Capillary Pressure ◽  
Relative Permeability ◽  
Gas Condensate ◽  
Gas Condensate Reservoirs ◽  
Naturally Fractured

Simultaneous Interpretation of Relative Permeability and Capillary Pressure for a Naturally Fractured Carbonate Formation From Wireline Formation Testing

2019 ◽  
Vol 142 (3) ◽  
Author(s):  
Xiangnan Liu ◽  
Daoyong Yang ◽  
Andrew Chen
Keyword(s):  
Capillary Pressure ◽  
Relative Permeability ◽  
Lower Layer ◽  
Numerical Models ◽  
Vertical Direction ◽  
Dual Porosity ◽  
Absolute Permeability ◽  
Carbonate Formation ◽  
Naturally Fractured ◽  
Fractured Carbonate

Abstract In this paper, pragmatic and robust techniques have been developed to simultaneously interpret absolute permeability and relative permeability together with capillary pressure in a naturally fractured carbonate formation from wireline formation testing (WFT) measurements. By using two sets of pressure and flow rate field data collected by a dual-packer tool, two high-resolution cylindrical near-wellbore numerical models are developed for each dataset on the basis of single- and dual-porosity concepts. Then, simulations and history matchings are performed for both the measured pressure drawdown and buildup profiles, while absolute permeability is determined and relative permeability is interpreted with and without considering capillary pressure. Compared to the experimentally measured relative permeability curves for the same formation collected from the literature, relative permeability interpreted with consideration of capillary pressure has a better match than those without considering capillary pressure. Also, relative permeability obtained from dual-porosity models has similar characteristics to those from single-porosity models especially in the region away from the endpoints, though the computational expenses with dual-porosity models are much larger. Absolute permeabilities in the vertical and the horizontal directions of the upper layer are determined to be 201.0 mD and 86.4 mD, respectively, while those of the lower layer are found to be 342.9 mD and 1.8 mD, respectively. Such a large vertical permeability of the lower layer reflects the contribution of the extensively distributed natural fractures in the vertical direction.

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