A clear knowledge of fluid flow at
the nanoscale will greatly contribute
to recovery of unconventional oil/gas reservoirs. The distinction
of nanoconfined fluid flow behavior with that of the bulk phase stems
from strong fluid–surface interactions, which favor the emergence
of slip phenomenon as well as spatial variation of viscosity and further
affects transport capacity. However, elaboration of the above essential
relationship remains challenging nowadays. Oil possesses a complex
molecular structure and therefore leads to fruitful technical content
regarding oil–surface interplay, posing a huge resistance to
gaining a good understanding. Furthermore, the physical properties
of tight oil reservoirs exhibit a wide variation range, including
rock wettability, pore dimensions, and temperature, and their influences
on oil transport are fascinating for in-depth investigation. The aim
of this research is to establish a physics fully coupled model for
nanoconfined oil transport behavior, which is capable of quantifying
the contribution of each influential factor. The excellent agreement
against the collected data from published literature claims the reliability
of the proposed model. Results indicate the following: (i) A wide
pore size can effectively suppress the nanoscale-induced influence
on the oil flow behavior, including slip boundary and spatial viscosity
variation features. (ii) The velocity distribution characteristic
exhibits a plug-like shape as a result of a relatively large slip
length by tuning surface wettability. (iii) Slip length shows a negative
correlation with increasing temperature, and the feasibility of thermal
recovery for tight oil reservoirs is not beneficial compared with
that applied in conventional heavy oil reservoirs.