@Article{fdmp.2026.075360,
AUTHOR = {Maolei Cui, Zengmin Lun, Jie Zhang, Jun Niu, Pufu Xiao},
TITLE = {Multiscale Single-Phase Flow Mechanisms of Shale Oil Revealed by High-Pressure Nuclear Magnetic Resonance Experiments},
JOURNAL = {Fluid Dynamics \& Materials Processing},
VOLUME = {22},
YEAR = {2026},
NUMBER = {2},
PAGES = {--},
URL = {http://www.techscience.com/fdmp/v22n2/66510},
ISSN = {1555-2578},
ABSTRACT = {To clarify fluid flow mechanisms and establish effective development conditions in continental shale oil reservoirs, a high-temperature, high-pressure steady-state flow system integrated with nuclear magnetic resonance (NMR) technology has been developed. The apparatus combines sample evacuation, rapid pressurization and saturation, and controlled displacement, enabling systematic investigation of single-phase shale oil flow under representative reservoir conditions. Related experiments allow proper quantification of the activation thresholds and relative contributions of different pore types to flow. A movable fluid index (MFI), defined using dual T<sub>2</sub> cutoff values, is introduced accordingly and linked to key flow parameters. The results reveal distinct multi-scale characteristics of single-phase shale oil transport, namely micro-scale graded displacement and macro-scale segmented nonlinear behavior. As the injection–production pressure difference increases, flow pathways are activated progressively, beginning with fractures, followed by large and then smaller macropores, leading to a pronounced enhancement in apparent permeability. Although mesopores and micropores contribute little to direct flow, their indirect influence becomes increasingly important, and apparent permeability gradually approaches a stable limit at higher pressure difference. It is also shown that the MFI exhibits a strong negative correlation with the starting pressure gradient and a positive correlation with apparent permeability, providing a rapid and reliable indicator of shale oil flow capacity. Samples containing through-going fractures display consistently higher MFI values and superior flowability compared with those dominated by laminated fractures, highlighting the pivotal role of well-connected fracture networks generated by large-scale hydraulic fracturing in improving shale oil production.},
DOI = {10.32604/fdmp.2026.075360}
}