Petrophysical Analysis of Mabruk Reservoir in West Mabruk Oil Field, (Sirt Basin, Libya)
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Petrophysical Analysis, Reservoir Rock, Porosity, Permeability, Water Saturation, Net Pay
Abstract
The Sirt Basin in the north-central part of Libya is one of the youngest sedimentary basins on the African craton. Sedimentation was controlled by tectonic and eustatic influences, locally inducing high sedimentation rates with the distribution of the various lithologies being governed by ridge-and-trough paleotopography. The carbonate intervals of the Heira Formation, which include the Mabruk Member, the upper Mabruk unit, which represents the main reservoir producing oil in the Mabruk oil field in Block C17, and the main objective of this study was to evaluate the carbonate reservoir member by petrophysical and geological analysis methods using Techlog and Petrel software for five selected wells (B1-17, B2-17, B3-17, B4-17, and B5-17). The upper Mabruk unit has a gross thickness ranging from 70 to 90 feet, while the net pay thickness ranges from 14 to 46 feet. The results revealed good reservoir quality content, average porosity ranging from 14 to 23%, average permeability ranging from 19 to 309 MD, and average water saturation variations, with some wells reaching 34% and increasing toward the south to 71%, which is located at the edge of oil-water contact. The lateral facies evolution creates petrophysical variations. The heterogeneities have a big impact on carbonate reservoir quality, although this study used only five wells with short distances between the wells, but clear lateral variation was encountered, as in well B4-17 and B5-17. Heterogeneities can enhance physical properties such as permeability, as was in B4-17 and B5-17 (19 and 191 md).
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References
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