Vol. 337 No. 6 (2026)
DOI https://doi.org/10.18799/24131830/2026/6/5157
Modeling thermal field in two-phase oil-water filtration in a heterogeneous reservoir considering thermodynamic effects
Relevance. Assessing heterogeneity parameters in the near-wellbore zone, such as the radius and permeability of the altered zone, is crucial for optimizing oil production and the effectiveness of reservoir stimulation techniques. Traditional methods have limitations, while thermometry, successfully applied for single-phase filtration (Chekalyuk's method), requires validation for the widely encountered two-phase (oil-water) conditions in practice. It remains insufficiently studied whether the classical approach of analyzing temperature curves retains its diagnostic value for the separate assessment of the altered zone radius and permeability under two-phase filtration conditions. Object. Non-isothermal two-phase (oil-water) filtration in a porous medium (reservoir) with a radial zone of altered permeability during fluid production at a constant rate. Aim. To investigate the influence of the near-wellbore zone parameters on bottomhole temperature dynamics during two-phase filtration, considering thermodynamic effects (Joule–Thomson, adiabatic); and to evaluate the informativeness of analyzing temperature dynamics and its logarithmic derivative for the separate assessment of the altered zone radius and permeability distribution in the near-wellbore zone under two-phase conditions. Methods. Numerical modeling based on a developed mathematical model that includes phase mass conservation equations (incorporating Darcy's law) and heat transport equations, accounting for convection, thermal conduction, and thermodynamic effects. Sensitivity analysis of the temperature response to variations in the radius and permeability of the near-wellbore zone. Results. It is shown that the bottomhole temperature dynamics is sensitive to the radius of the altered zone and the permeability distribution within the near-wellbore zone. Analysis of the logarithmic temperature derivative revealed that the time τ, corresponding to the derivative maximum, is predominantly determined by the radius of the altered zone, whereas the magnitude of this maximum significantly depends on its permeability. Furthermore, it was established that both these indicators (time τ and the magnitude of the derivative maximum) depend as well on the reservoir water saturation, which determines the phase composition of the flow. This confirms that the classical thermal interpretation approach retains its informativeness and is potentially applicable for the separate assessment of the near-wellbore zone parameters during two-phase oil-water filtration, provided that the effect of the flow phase composition is correctly considered.
For citation: Islamov D.F., Ramazanov A.Sh., Davletshin F.F., Akchurin R.Z. Modeling thermal field in two-phase oil-water filtration in a heterogeneous reservoir considering thermodynamic effects. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 2026, vol. 337, no. 6, pp. 110-121. https://doi.org/10.18799/24131830/2026/6/5157
Keywords:
two-phase filtration, oil–water, near-wellbore zone, thermometry, thermal field modeling, thermodynamic effects, logarithmic derivative, permeability
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