Integrating Mini-DST-Derived Permeability With Other Sources: A Case Study

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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The reservoir characterization of the Sea Lion Field

Griffiths¹

2015

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The reservoirs that form the Sea Lion Field comprise a series of canyon-fed fans deposited into a deep, anoxic lake, on the hanging wall of the basin boundary fault. The fans primarily form stratigraphic traps with an element of fault seal on the west flank. These fans are dominated by mass flow and high-density turbidite sands, with subordinate low-density turbidites set within lacustrine shales. The fans mapped on seismic profiles are partitioned into lobes, based on sand bodies penetrated into the wells or the conceptual model where correlation between wells is not possible. Ten facies are identified from core but attempts to discriminate facies met with mixed success. Facies are therefore combined into four associations (‘Rock Types’) for use in dynamic flow modelling. Rock Types are distributed within the fans using a hierarchical reservoir architecture (‘fan-lobe-surge’). This paper describes the reservoir and fluid characteristics, and outlines the challenges associated with converting the detailed geological model into a form suitable for reservoir simulation, while preserving the main reservoir features that will influence fluid movement within the reservoir

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Integrating Mini-DST-Derived Permeability With Other Sources: A Case Study

Cited by 10 publications

References 5 publications

Design and interpretation of transient tests at well's inception

Design and interpretation of transient tests at well's inception

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

The reservoir characterization of the Sea Lion Field

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