Abstract

A project to review previous work, perform additional laboratory tests, and identify pay from well logs in the Teague-Blinebry field was performed. Laboratory tests included:

• mineralogy, fracture systems, and oil stains described for 251 ft of recovered core;
• slabbed core scanning minipermeametry on 79 samples, air perms on both ends of 12 plugs, brine perms on 2 samples, and water and CO₂ floods on 2 samples;
• minimum miscibility pressure higher than 1,000 psig or the system bubble point pressure; and
• wettability index of -0.608.

Core permeability measurements identified very low matrix permeability in the Blinebry dolomite. Regions of conductive vugs and fractures were detected. Tests indicate that even apparently filled fractures play a significant role in fluid movement. This observation is supported by effective permeability results derived from step rate tests to be 1.15 md¯well above the average matrix permeability. Density/neutron and induction or laterologs were used to identify pay in 18 wells with modern log suites. In order to include a greater number of wells, a procedure was adopted in which field average parameters were used with 57 sonic porosity logs from the older wells lacking density/neutron data. Net pay and original oil in place were calculated for 65 wells. Targets for potential water or CO₂ flood development are identified as the upper one-third of the Blinebry.