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Completed slim-tube tests for MMP measurement. Completed swelling tests.

Near Miscible CO 2 Application to Improve Oil Recovery for Small Producers RPSEA Small Producer Program. Completed slim-tube tests for MMP measurement. Completed swelling tests. Completed phase behavior model. Completed preliminary geological model.

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Completed slim-tube tests for MMP measurement. Completed swelling tests.

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  1. Near Miscible CO2 Application to Improve Oil Recovery for Small ProducersRPSEA Small Producer Program • 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 CO2.

  2. In Progress • Core flooding test with CO2 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 CO2 injection at near miscible conditions.

  3. Characterization of core sample 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

  4. CO2 Displacement @ 1320 psia, 110°F

  5. Recovery of Remaining oil with CO2 Injection @ 110 °F

  6. Geological model • 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).

  7. Arbuckle Reagan Granite

  8. Reservoir model • 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

  9. Paper to be Presented • "Laboratory Investigations of CO2 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.

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