Conclusions
Chert facies exhibit porosities ranging from 25-50% and permeabilities ɱ md
Cherty dolomite mudstones, argillaceous dolomite mudstones, and bioclastic wacke-packestones exhibit non-reservoir properties
Reservoir production, simulation, and whole core data indicate fracturing can be present in chat reservoirs and can enhance permeability by up to an order of magnitude
Capillary pressure data indicate the presence of microporosity and can explain high water saturations and low resistivity observed in wireline logs
Relative permeabilities decrease rapidly for saturations > 60% and may be influenced by dual pore systems
Detailed modified Pickett plot analysis of logs reveals some of the chat character and can provide reliable indications of reservoir properties
Models developed provide some additional insight into the chat of south-central Kansas and understanding the nature of controls on shallow shelf chert reservoir properties