Simultaneous enhanced oil recovery, CCUS and UHUS in shale oil reservoirs

Bao, Xiaolin; Fragoso, Alfonso; Aguilera, Roberto F.

doi:10.1016/j.coal.2023.104301

Cited by 5 publications

(2 citation statements)

References 19 publications

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“…The difference in reservoir porosity refers to the ratio of the assumed porosity to the original value. , As the reservoir porosity increases, the CO 2 burial capacity, burial rate, cumulative oil production, and recovery rate all increase. The CO 2 oil change rate first increases and then decreases with increased porosity.…”

Section: Sensitivity Analysismentioning

confidence: 99%

Experimental and Numerical Simulation Analysis of Factors Affecting CO₂ Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Liu,

Shen,

Yue

et al. 2023

Energy Fuels

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Carbon neutrality has become the long-term development strategy of many countries worldwide, and the widespread implementation of CCUS (carbon capture, utilization, and storage) is critical for achieving this goal. Ultralow permeability reservoirs have good storage and shielding properties, making them ideal for CO2 geological storage. CO2 into these reservoirs has the dual purpose of improving crude oil recovery and protecting the environment. However, the physical properties of ultralow permeability reservoirs are poor. Furthermore, the distribution of fractures is often complex. The mechanism and influencing factors of the CO2 storage are still unclear. Here, the CO2 storage in ultralow permeability reservoirs is analyzed through core displacement experiments and numerical simulation. The main influencing factors of cumulative oil production and CO2 storage capacity were calculated through gray correlation theory, including CO2 injection rate, permeability, porosity, the solubility of CO2 in water, and the bottom hole flow pressure of production wells. The research results show that the geological storage of CO2 in ultralow permeability reservoirs mainly consists of structural trapping and dissolution into the residual fluids; in the short term, mineralization is relatively small and can be ignored. Within the 15 years predicted by numerical simulation, the injected CO2 into the Y28–102 well group in the Huang3 district was structurally trapped, with a total capacity of 6.59 × 104t. The burial ratio was 63.4%, of which structural burial accounted for 82%, oil dissolution accounted for 9%, water dissolution accounted for 8%, and mineral burial accounted for approximately 1%. The research results reference CO2 flooding and geological storage in ultralow permeability reservoirs.

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Section: Sensitivity Analysismentioning

confidence: 99%

Experimental and Numerical Simulation Analysis of Factors Affecting CO₂ Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Liu,

Shen,

Yue

et al. 2023

Energy Fuels

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“…Because of ultralow porosity (<5%) and permeability (<0.01 mD), shale oil cannot be extracted without horizontal wells and multistage hydraulic fracturing. − Despite the advantages of the two techniques, the primary recovery of shale oil is far lower than the conventional plays, normally no greater than 10%. , Such a low recovery factor has stimulated the application of enhanced oil recovery (EOR) techniques, e.g., CO 2 and natural gas injections . CO 2 injection of EOR (CO 2 -EOR) has become particularly attractive because of its efficiency of enhanced shale oil recovery and additional potential for CO 2 storage. − …”

Section: Introductionmentioning

confidence: 99%

Recovery of Adsorbed and Free Oil in Shale Formations by CO₂ Injection: An Experimental Study Using 1D- and 2D-NMR

Zou,

Hu,

Lun

et al. 2024

Energy Fuels

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Carbon dioxide (CO 2 ) injection has become particularly attractive for its effectiveness in shale oil recovery and additional potential for CO 2 sequestration. However, recovery mechanisms of shale oil in different occurrence states, such as adsorbed and free oil, are still unclear. In this study, we conducted CO 2 injection experiments on an oil-bearing shale sample collected from the Lucaogou Formation under several temperatures and injection pressures. The CO 2 injection experiment contained initial injection, soaking, and depressurization, which simulated one cycle of CO 2 huff-n-puff. The response of shale oil to CO 2 injection was captured by the combination of T 2 , T 1 −T 2 nuclear magnetic resonance (NMR) and mass balance analysis. Our results showed that free oil was easily recoverable by CO 2 injection. However, its recovery was not sensitive to the operating temperature since it increased slightly with elevated temperatures. As CO 2 injection pressure rose from 10 to 15 MPa under the operating temperature of 80 °C, the free oil recovery decreased by 6.7%. Adsorbed oil was only produced under a high temperature of 100 °C, and its content in shale increased by 9.9% when CO 2 was injected at 15 MPa. As residual water in the oil-bearing shale can be extracted by CO 2 , the shale oil recovery was overestimated by mass balance and T 2 NMR analysis. Our findings contribute to a better understanding of shale oil recovery by CO 2 injection.

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Conflicting Long-Term CO₂ Effects on Shale Oil Formations for Simultaneous CO₂ Sequestration and CO₂-EOR

Hu,

Lun,

Wang

et al. 2024

Energy Fuels

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Simultaneous enhanced oil recovery, CCUS and UHUS in shale oil reservoirs

Cited by 5 publications

References 19 publications

Experimental and Numerical Simulation Analysis of Factors Affecting CO₂ Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Experimental and Numerical Simulation Analysis of Factors Affecting CO₂ Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Recovery of Adsorbed and Free Oil in Shale Formations by CO₂ Injection: An Experimental Study Using 1D- and 2D-NMR

Conflicting Long-Term CO₂ Effects on Shale Oil Formations for Simultaneous CO₂ Sequestration and CO₂-EOR

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Simultaneous enhanced oil recovery, CCUS and UHUS in shale oil reservoirs

Cited by 5 publications

References 19 publications

Experimental and Numerical Simulation Analysis of Factors Affecting CO2 Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Experimental and Numerical Simulation Analysis of Factors Affecting CO2 Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Recovery of Adsorbed and Free Oil in Shale Formations by CO2 Injection: An Experimental Study Using 1D- and 2D-NMR

Conflicting Long-Term CO2 Effects on Shale Oil Formations for Simultaneous CO2 Sequestration and CO2-EOR

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Experimental and Numerical Simulation Analysis of Factors Affecting CO₂ Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Experimental and Numerical Simulation Analysis of Factors Affecting CO₂ Geological Storage and Enhanced Oil Recovery in Extra-Low Permeability

Recovery of Adsorbed and Free Oil in Shale Formations by CO₂ Injection: An Experimental Study Using 1D- and 2D-NMR

Conflicting Long-Term CO₂ Effects on Shale Oil Formations for Simultaneous CO₂ Sequestration and CO₂-EOR