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Geological Society, London, Special Publications; 2004; v. 237; p. 279-282;
DOI: 10.1144/GSL.SP.2004.237.01.16
© 2004 Geological Society of London

Case Studies - Water and Petroleum Fluid Compositional Variations

Evidence of reservoir compartmentalization by calcite cement layers in deepwater sandstones, Bell Canyon Formation, Delaware Basin, Texas

Shirley P. Dutton1 & William A. Flanders2

1 Bureau of Economic Geology, The University of Texas at Austin, Austin, Texas 78713, USA shirley.dutton{at}beg.utexas.edu
2 Transpetco Engineering, 110 N. Marienfeld Place, Suite 525, Midland, Texas 79701, USA

Sandstones of the Upper Permian Bell Canyon Formation were deposited by turbidity currents in a basin-floor setting. The sandstones were deposited in a channel-levee system that terminated in broad lobes; overbank splays filled topographically low inter-channel areas. Diagenesis and reservoir quality of the sandstones were examined in cores from East Ford field, which is undergoing a CO2 flood. Porosity and permeability are controlled by calcite cement, mainly concentrated in layers ranging from 5 to 40 cm in thickness. In a new infill well, initial production was of a high gas volume that contained a high concentration of CO2 from the interval beneath several low-permeability, calcite-cemented layers. The CO2 was most likely from an injector well and was trapped below the calcite layers. Geophysical log correlations support the interpretation that some calcite layers are laterally continuous over a distance of at least 300 m, causing vertical compartmentalization in the reservoir.