Abstract
Field development typically requires detailed petrophysical analysis and well defined hydraulic flow units for comprehensive formation evaluation and reservoir characterization. In the present study, pay zones petrophysics are studied using an assembly of well log data from 8 wells together with core plugs measurements. Petrophysical analysis showed a good reservoir quality with average water saturation increasing toward the East and Southeast of the study area. Using a multi-linear regression technique on well logs and core data, permeability is estimated at well locations for flow unit characterization and flow capacity calculation. Results showed that five hydraulic flow units are identified through the studied wells, with relatively good correlation. Such correlation indicated a good continuity in the net pay zone of Abu Madi Formation in the Nile Delta reservoirs. The developed hydraulic flow units (HFUs) are classified according to its hydraulic conductivity into two main categories: the first category comprises the units with low permeability (K 1270 mD). The reservoir flow capacity (RFC) of these units indicated the development of 4 distinct classes (~11, ~30, ~80, and greater than 130 D.ft). The wells within the Northwestern part of the study area showed three HFUs that relatively vary from those located at the Southeast where two HFUs are only developed. In addition, the Southeastern part of the reservoir is characterized by good RFC as indicated by the development of high order HFUs (3, 4, and 5) compared to the Northeastern part with predominated low order HFUs (1, 2, and 3). Such results are crucial for the efficient field development and profound reservoir management of oil and gas fields in the Nile Delta.
Highlights
Effective description for efficient reservoir characterization and the synergy of geological and engineering techniques are the key parameters for a comprehensive reservoir management [1]
The developed hydraulic flow units (HFUs) are classified according to its hydraulic conductivity into two main categories: the first category comprises the units with low permeability (K < 220 mD), and the second category involves the units with high permeability (K > 1270 mD)
The hydraulic flow capacity (HFC = [Thickness*Hydraulic conductivity]/1000) of HFU1 indicates that AMD3 well has the highest flow capacity among the studied wells, but the associating high standard deviation indicates reservoir heterogeneity that results in tortuous flow regimes at this location
Summary
Effective description for efficient reservoir characterization and the synergy of geological and engineering techniques are the key parameters for a comprehensive reservoir management [1]. Saner et al [30] applied a similar methodology for a carbonate reservoir, whereas Rios et al [31] used principal component regressions of Nuclear Magnetic Resonance (NMR) and Mercury Injection Capillary Pressure (MICP) data to predict permeability of carbonate rocks These successful applications proved that it is possible to apply the MLR for the development of permeability correlations to the Abu Madi Formation. A detailed methodology to characterize the pay zones of Abu Madi into HFUs and calculate their flow capacity is described using permeability-derived from multiple linear regression of available well log data Such information is crucial for understanding the hydrocarbon flow across the reservoir and helps improving the efficiency of the static reservoir models
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