Abstract

During the past 38 years, CO2 flood technology for Enhanced Oil Recovery projects evolved from a partially understood process filled with uncertainties to a process based on proven technology and experience. Many questions involved with CO2 flooding have been thoroughly analyzed and answered. This knowledge is currently being used by a limited number of companies that actually know how to design, implement, and manage a CO2 flood for long term profit. Unfortunately, this knowledge has not been disseminated to operating companies interested in EOR flooding or to CO2 Sequestration Communities interested in storing CO2 in EOR projects.

The primary objective of this report is to target "Conventional WAG Techniques" which have been used in over 90% of all the Enhanced Oil Recovery projects implemented in the Permian Basin in Texas, Colorado, Oklahoma, and Wyoming. Over the years, oil companies have reported a wide range of values of Tertiary Oil Recovery, CO2 Utilization, and CO2 Retention, resulting in a wide range of variation and uncertainty. Many of the numbers reported to date are tied to a specific HCPV CO2 Injected based on some Economic Cut-off. This typically has been in the range of 30% to 80% HCPV Injected. The question becomes "What is life after 80% HCPV?" And "What effect does life after 80% HCPV have on Tertiary Oil Recovery, CO2 Utilization and CO2 Retention in different producing formations?" Results of this study show Tertiary Oil Recovery can be as high as 26% OOIP when slug sizes exceed 190% HCPV injected.

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