Abstract
Image logs have higher resolution than conventional logs and it makes them powerful tools for detailed reservoir characterization and modeling. Hence, thin beds, which are not detectable using conventional logs, can be characterized by image log data. The present study focuses on the Permian-Triassic carbonate reservoirs of Dalan and Kangan formations in one of the gas fields in southern Iran. In this study, the reservoir porosity was estimated using Fullbore Formation Microimager (FMI) image log. Then, the results were compared and validated with the core data. Porosity was estimated as 2-dimentional image by rescaling the FMI image log with Micro-Spherical Focused Log (MSFL). The image log-derived porosity was then compared with conventional logs-derived and core porosities. The image log-derived porosity is in good agreement with the core data. In this paper, a procedure was introduced which can be used to recognize very narrow pay layers (thickness in centimeters). This work is very important for identifying the proper perforation intervals in heterogeneous reservoirs.
Highlights
One of the main goals in evaluation of hydrocarbon fields is the generation of detailed reservoir model
The present study focuses on the Permian-Triassic carbonate reservoirs of Dalan and Kangan formations in one of the gas fields in southern Iran
Porosity was estimated as 2-dimentional image by rescaling the Formation Microimager (FMI) image log with Micro-Spherical Focused Log (MSFL)
Summary
One of the main goals in evaluation of hydrocarbon fields is the generation of detailed reservoir model. Such model requires fine-scale data such as porosity and permeability that should be accurately used in the model; image logs, by their higher resolutions, can be regarded for this aims. In some studies it was attempted to separate and calculate vuggy porosity using electrical image logs [20] [21]. The mentioned reservoirs are very heterogeneous, so tiny porous-permeable parts are vital to be detected for perforation jobs
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