 Completed slim-tube tests for MMP measurement.  Completed swelling tests.  Completed phase behavior model.  Completed preliminary geological model.

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Presentation transcript:

 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

 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

DescriptionArbuckle Berea SS Core sampleC1 A1 Epoxy Temperature ( °F ) Pressure (psia) Length (cm) Diameter (cm) PV (cc) Porosity Permeability (md) Swc Ko Sor Kw 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

CO psia, 110°F

Recovery of Remaining oil with CO °F

 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

Arbuckle Reagan Granite

 Oil Field: Ogallah Unit, Trego County, Kansas  Formation depth: 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

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