30 DECEMBER 2025 WorldWide Drilling Resource® This Method Could Boost Oil Output Adapted from Information by the Pennsylvania State University (Penn State) Over the last ten years, oil extracted from shale formations has significantly boosted crude production in the United States. However, according to the federal Energy Information Administration, traditional extraction methods can leave up to 90% of oil trapped within these formations. To enhance the efficiency of oil recovery from dense shale rock, researchers at Penn State have developed an innovative extraction process increasing shale oil yield by as much as 15%, while also enabling long-term carbon dioxide (CO2) storage. This new methodology has been successfully tested in the Eagle Ford Shale region of Texas, where it showed promising improvements in oil recovery. Researchers noted this approach could potentially be adapted for use in various other shale reservoirs. The core of this innovation lies in refining the cyclic CO2 injection technique, which involves pumping CO2 into the reservoir to boost oil production. Commonly referred to as “CO2 huffn-puff,” this established method enhances extraction from rock formations containing minute voids known as nanopores, where significant amounts of hydrocarbons - the primary components of oil - are stored. Hamid Emami-Meybodi, an Associate Professor in petroleum and natural gas engineering and lead author of the study, compared the shale environment to a sponge. Just as a sponge’s tiny holes absorb water, these nanopores capture and hold hydrocarbons until the surrounding conditions change. In practice, CO2 is introduced into the reservoir through a well, which is then sealed, allowing the gas to permeate and interact with the oil for a designated period. This interaction alters the oil’s characteristics, enhancing its flow and facilitating its extraction. Researchers pointed out that varying pressures during CO2 injection can significantly influence the effectiveness of hydrocarbon extraction from nanopores, which is affected by operational condition, depths, and oil types. The research team worked in collaboration with industry partners to identify ways to boost extraction efficiency, recognizing even minor increases in hydrocarbon recovery could translate into substantial gains in oil production. Major shale formations, like Eagle Ford, are believed to contain billions of gallons of oil. Additionally, researchers highlighted the potential to repurpose shale wells as long-term storage sites for CO2, which could be sourced as a byproduct from other industrial processes. This approach would prevent gas from entering the atmosphere, while allowing energy companies to securely store it underground for extended periods. Focusing on the 400-mile-long Eagle Ford Shale, one of five significant shales plays in the U.S., the research indicated existing extraction techniques, including hydraulic fracturing, typically recover less than 10% of the oil present. To improve this, the team refined the CO2 injection method by increasing the hydrocarbons’ exposure to CO2. The optimized workflow involved expanding the CO2 coverage area and adjusting various parameters, including the number of cycles, pressure, volume of CO2 injected, and duration of the injection process. A coring and geophysical well-logging operation targets sedimentary rock formation. G&O See us at Booth 2448 Groundwater Week 2025 in New Orleans
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