Petrophysical analysis of lithofacies

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Exploring for Oil and Gas Traps
Series Treatise in Petroleum Geology
Part Predicting the occurrence of oil and gas traps
Chapter Exploring for stratigraphic traps
Author John C. Dolson, Mike S. Bahorich, Rick C. Tobin, Edward A. Beaumont, Louis J. Terlikoski, Michael L. Hendricks
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The reservoir or seal quality of a rock is established soon after deposition. It is strongly influenced by its environment of deposition. Diagenesis can alter or completely change the original pore space of a rock, especially for carbonates. However, if the original pore space is not altered too much, then a relationship exists between lithofacies and reservoiror seal-quality rocks that we can use when prospecting for stratigraphic traps. A petrophysical analysis of the lithofacies of a rock section in a target area can help determine if such a relationship exists.

Procedure

Figure 1 Live oil stain in macroporous strata indicates the direction to move updip.

After lithofacies analysis, a careful petrophysical analysis of shows and production should be made and compared to lithofacies distribution. The table below suggests a procedure for petrophysical analysis.

  1. Gather all available fluid data regarding production, shows, and pressures from prospective intervals.
  2. On structural cross sections, plot intervals that …
    • Were perforated
    • Had DSTs
    • Had RSTs
    • Had mud log shows
    1. Annotate the intervals with the results.
  3. Divide potential reservoir units on the cross sections into intervals of similar petrophysical character (flow units) using log data and, if available, porosity-permeability data. Categorize each flow unit by port type as mega-, macro-, meso-, or microporous.
  4. Calculate water saturation (Sw ) of intervals that …
    • Are productive
    • Had shows
    • Are potential reservoirs
    1. Annotate the log intervals with Sw values.
  5. Estimate the height above free water for zones that appear to have oil or gas.
  6. Analyze the fluid data in the context of the petrophysical data.
    • Do Sw values, shows, and fluid pressures make sense in context with other geological data, including hydrocarbon column height?
    • Do the shows or Sw values indicate the presence of an updip or downdip trap?
  7. Determine whether a relationship exists between the development of reservoir-quality rocks, seal-quality rocks, and lithofacies that can be used to predict location and economic viability of prospective traps.

Example: calibrating logs to cores and shows

Figure 2 Two distinct pressure regimes coinciding with discrete channel systems, delineated with pressure-depth plots. Copyright: Putnam and Oliver;[1] courtesy Canadian Society of Petroleum Geologists. Map courtesy Eric Dahlberg.

Posting core porosity, permeability, and pore throat radius (r35) data directly on wireline logs next to lithofacies descriptions and show data helps us decide about exploitation for stratigraphic traps. In Figure 1, the live oil stain in macroporous strata indicates the direction to move updip. The only macroporous strata present is within an algal mound facies developed in this parasequences at relative highstand. Microporous dolomites comprising the lower portions of the parasequences have poor reservoir characteristics, despite high porosity readings on the logs. Thus, the target of interest is the highstand mound facies.

Example: using pressures

Reservoir scale discontinuities often cannot be detected by primary trapping geometries from sequence stratigraphy alone. Within channel systems of the Lower Cretaceous Mannville Group (Alberta, Canada), fluids distributions may be complex. High-resolution definition of the discrete traps may be possible only by integrating more data.

Figure 2 shows two distinct pressure regimes coinciding with discrete channel systems, delineated with pressure-depth plots. For additional information, refer to Dahlberg.[2]

See also

References

  1. ↑ Putnam, P. E., and T. A. Oliver, 1980, Stratigraphic traps in channel sandstones in the Upper Mannville (Albian) of east-central Alberta: Canadian Society of Petroleum Geologists Bulletin, vol. 28, p. 489–508.
  2. ↑ Dahlberg, E., C., 1982, Applied Hydrodynamics in Petroleum Exploration: New York, Springer-Verlag, 161 p.

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