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3-D Reservoir Modeling and Simulation of Fullerton Clear Fork Unit, Andrews County, West Texas
November 2004 Presentation in PDF Format
Fullerton Clear Fork Field

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Figure 2

Simulation Model Permeability

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Figure 14

Reservoir Simulation

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Figure 15

Integrated Geological and Engineering Characterization of
Fullerton Clear Fork Field in Andrews County, Texas
3-D Reservoir Modeling and Simulation

To characterize flow through the reservoir, a representative 2,000-acre (Figure 2) area of the field was chosen for detailed characterization, modeling, and simulation on the basis of the availability of cores and modern wireline log suites.

The following steps were taken to construct the reservoir model:

  1. Construction of a cycle-based reservoir framework based on facies- and cycle-stacking patterns defined from outcrops and subsurface cores and their correlation throughout the area using calibrated wireline logs. This framework forms the basic architecture for the model.

  2. Calculation of porosity from wireline logs using petrophysical relationships derived from integrated core and wireline logs.

  3. Calculation of permeability from wireline-log porosity based on rock-fabric porosity /permeability interrelationships.

  4. Delineation of flow layers based on reservoir framework and calculated permeability distribution.

  5. Calculation of original oil saturation from rock-fabric-based capillary pressure modeling.

  6. Construction of fine-scale geological model (Figure 14) containing 3.2 million cells (140×90×256) was based on rock-fabric flow layers.

  7. Upscaling of fine-scale model to coarse reservoir model containing 135,000 cells (73×48×39) for reservoir simulation.

The simulation study is divided into three phases: (1) sensitivity study, (2) history matching, and (3) performance prediction. From the sensitivity study we are ranking the importance of reservoir parameters affecting production performance. Through history matching, optimal fluid and rock properties are being determined, such as initial oil saturation and current oil saturation (Figure 15). In the prediction phase, a variety of recovery technologies for maximizing oil recovery are being analyzed.

For more information, please contact Steve Ruppel, principal investigator. Telephone 512-471-2965; e-mail stephen.ruppel@beg.utexas.edu.
January 2004