Details for "Geological Approaches to Carbonate Reservoir Model Construction"
Carbonate reservoir systems are typically highly complex assemblages of depositional and diagenetic facies whose character, extent and petrophysical properties can be difficult to define. Nevertheless, high confidence reservoir
models must be built around a high-resolution geological framework in order to define the spatial distribution of each of these complex attributes. Ongoing characterization studies of PermianBasin reservoirs by the Bureau of
Economic Geology have identified key steps in the development of geologically based reservoirs models that are applicable to most carbonate reservoirs.
Perhaps the most critical geological element of all detailed reservoir models
is the stratigraphic framework. The framework provides essential constraints
on issues like pay continuity and allows for realistic flow models to be
constructed. To be valid, the framework must be based on rock description –
ideally from both outcrop analogs and cores - and integrated with subsurface geophysical data. The recently completed analysis of the giant Fullerton
Clear Fork field provides an excellent recipe for work flows, procedures, and techniques that form the basis for realistic reservoir characterization and
modeling.
Like many carbonate reservoirs in the PermianBasin, Fullerton Clear Fork
reservoir displays a very low recovery efficiency (18%) despite more than 60
years of primary and secondary recovery activities. An incomplete
understanding of the reservoir architecture was an important contributing factor
to recovery issues. Multidisciplinary study of the reservoir was based on the following rock-based approaches: (1) geological models of analogous outcrops, (2) description of > 14,000 feet of core, and (3) new core analyses for rock fabric interpretation. Some of the key rock-driven insights from the study include: (1) seismic reflections define depositional and diagenetic facies not time lines or sequence boundaries. (2) permeability is a function of depositional facies,
whereas porosity is a function of diagenetic facies, (3) porosity development
is in part due to early diagenesis, (4) limestones in this dominantly dolostone reservoir, are low permeability flow baffles in peritidal rocks, but permeable,
high-flow layers in subtidal rocks, and (5) porosity logs can be better tools for identifying and correlating depositional cycles than other wireline logs. These
data and interpretations were used to guide construction of the reservoir
framework and development a 3-D seismic inversion porosity model, ultimately leading to the construction of a rock-based, full field static model and flow simulation model.
Stephen C. Ruppel is a Senior Research Scientist at the Bureau of Economic Geology at The University of Texas at Austin where he has engaged in the study of carbonate depositional systems since 1981. He holds the PhD degree from the University of Tennessee at Knoxville and previously worked as a geologist for Chevron Oil Co. in New Orleans. For the past 20 years, his research has focused on understanding the depositional and diagenetic evolution of Paleozoic carbonate reservoirs in the PermianBasin. He is currently director of the Bureau’s Permian Basin Geological Synthesis Program and also plays a key role in the Bureau’s programs in shale gas reservoir research.
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Stephen C. Ruppel is a Senior Research Scientist at the Bureau of Economic Geology at The University of Texas at