1.  Completed slim-tube tests for MMP measurement.  Completed swelling tests.  Completed phase behavior model.  Completed preliminary geological model.  At 110 °F, MMP determined from slim-tube test is 1,350 psig.  At 110 °F, near-miscible pressure range defined from this study is between 1,150 and 1,350 psig.  At pressure near miscible, extraction or vaporization is a primary mechanism for mass transfer.  Oil viscosity reduction factor of five is achieved in the near miscible region with injection of CO 2. Near Miscible CO 2 Application to Improve Oil Recovery for Small Producers RPSEA Small Producer Program

2.  Core flooding test with CO 2 displacement to  determine incremental oil recovery from residual oil after waterflooding (Sorw) with Berea core.  repeat same tests with Arbuckle cores.  Construction of reservoir model to history match the field operation and predict the recovery from the field by CO 2 injection at near miscible conditions. In Progress

4. DescriptionArbuckle Berea SS Core sampleC1 A1 Epoxy Temperature ( °F ) 86 110 Pressure (psia)14.7 138013201200 Length (cm)4.82 5.86 Diameter (cm)2.48 2.52 PV (cc)3.26 5.80 Porosity0.15 0.2 Permeability (md)58 332239212252 Swc0.380.370.330.380.320.34 Ko5658228119.1112.2134.6 Kro@Swc0.971.000.690.500.53 Sor0.370.40.260.620.500.47 Kw11.810.923.516.115.316.7 Krw@Sor0.200.190.07 Brine solution: 0.5 wt% Calcium chloride and 0.5 wt% Magnesium chloride Crude oil: Ogallah oil Arbuckle core: Hadley L#4 well, depth 3605 ft, Bemis-shutts, Ellis County, Kansas Characterization of core sample

6. CO 2 Displacement @ 1320 psia, 110°F

7. Recovery of Remaining oil with CO 2 Injection @ 110 °F

8.  Structure top and flow unit were constructed from log stratification study  Porosity was estimated from log analysis and an in-house developed correlation between micro log and density neutron log.  Permeability was derived from a correlation based on published petrophysical properties by Franseen, E. K. and Byrnes, A.P. (1999 AAPG, A18). Geological model

9. Arbuckle Reagan Granite

10.  Oil Field: Ogallah Unit, Trego County, Kansas  Formation depth: 3950-4060 ft  Formation temperature: 110 °F  Reservoir pressure: ~1150 psia  Total number of wells: 133  Active producers: 18  Average thickness: 22 ft  Average porosity: 0.10  Average permeability: 12 md  Original oil in place: 9.1 MMSTB  Original water in place: 16.1 MMSTB  Mobile oil: 3.2 MMSTB Reservoir model

11. Paper to be Presented "Laboratory Investigations of CO 2 Near Miscible Application in Arbuckle Reservoir" paper SPE-129710 to be presented at 2010 SPE Improved Oil Recovery Symposium, Tulsa, April 24-28. "Swelling/Extraction Test of a small sample size for Phase Behavior Study" paper SPE-129728 to be presented at 2010 SPE Improved Oil Recovery Symposium, Tulsa, April 24-28.