--> Abstract: Reservoir Characterization and Geocellular Modeling of Deep-Water Sandstones in the Ranger Zone of the Long Beach Unit, East W; #90063 (2007)

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Reservoir Characterization and Geocellular Modeling of Deep-Water Sandstones in the Ranger Zone of the Long Beach Unit, East Wilmington Field, California

 

Tye, Robert S.1, Creties Jenkins1, Don Michel2, Scott Grasse3, Genliang Guo3, Scott Prior4 (1) DeGolyer and MacNaughton, Dallas, TX (2) DeGolyer and MacNaughton, (3) Oxy Long Beach Inc, Long Beach, CA (4) THUMS Long Beach Company, Long Beach, CA

 

Waterflooding of deep-water sandstones in the Long Beach Unit (LBU) began in 1965. Over the years, production from these unconsolidated, Mio-Pliocene reservoirs has been influenced by numerous technological advances and reservoir analyses. In 2005-06, a reservoir characterization study of the eastern portion of the most prolific reservoir zone (the Ranger Zone) was undertaken using a 3D seismic survey, core data, and logs from more than 900 wells.

 

The seismic data facilitated structural horizon mapping and fault delineation, and also holds promise for guiding the distribution of reservoir properties. Core data allowed depositional interpretations and the calibration of net sandstone, porosity, and water saturation calculations from the logs. Petrophysical analysis of the unconsolidated sediments was complicated by conflicting core data, variable lithofacies, and heavy minerals.

 

An existing layering scheme based on field-wide shale picks (Unit markers) was refined by correlating additional stratigraphic markers representing unconformities and flooding surfaces. These were corroborated with injection, production, and pressure data to define fluid-flow barriers/baffles and delineate flow units.

 

The seismic, core, and log data were used to build a geocellular model layered with a combination of constant-thickness and proportional-thickness cells. Lithofacies, porosity, and permeability data were distributed using Sequential Indicator Simulation and Sequential Gaussian Simulation. A height vs. saturation function was used to distribute fluid saturations. Original oil-in-place volumes were calculated and sensitivities to oil-water contacts, pore volume, and other parameter variations were tested. The resulting model will be used in numerical simulation to understand reservoir mechanisms, define under-injected areas, and identify bypassed pay.

 

AAPG Search and Discover Article #90063©2007 AAPG Annual Convention, Long Beach, California