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Study on the Non-Equilibrium Dynamic Phase Transition Model for Oil–Gas Systems.

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Title: Study on the Non-Equilibrium Dynamic Phase Transition Model for Oil–Gas Systems.
Authors: Tu, Hanmin1 (AUTHOR) t.hanmin@swpu.edu.cn, Peng, Yi1 (AUTHOR), Guo, Ping1 (AUTHOR), Wang, Zhouhua1 (AUTHOR), Wang, Shuoshi1 (AUTHOR), Li, Yu1 (AUTHOR), Chen, Wei1 (AUTHOR), Wang, Lidong1 (AUTHOR), Deng, Xiang1 (AUTHOR)
Source: Energies (19961073). Jun2026, Vol. 19 Issue 12, p2902. 28p.
Subject Terms: *Gas condensate reservoirs, *Phase transitions, *Oil-gas mixtures, *Simulation methods & models, *Chemical relaxation, *Hydrocarbon manufacturing
Abstract: In gas-condensate reservoirs, the phase behavior of reservoir fluids is inherently dynamic during pressure depletion. When the rate of external pressure decline exceeds the intrinsic relaxation rate governing phase equilibrium, the system deviates from thermodynamic equilibrium and exhibits pronounced non-equilibrium effects. These transient behaviors significantly influence fluid properties; meanwhile, conventional equilibrium models neglect phase transition lag, resulting in inaccurate phase behavior and biased production predictions. In this study, a non-equilibrium dynamic phase transition model is developed to quantitatively couple the pressure depletion rate with the relaxation kinetics of the system. This model, established based on controlled non-equilibrium phase transition experiments performed on the condensate-gas fluid investigated in this work, provides an analytical framework for describing the temporal evolution of phase behavior under dynamic conditions. Model validation through integrated experimental measurements and numerical simulations shows good agreement between calculated and measured results for the studied condensate-gas system, with average relative errors below 5%. Results reveal that accelerated pressure depletion strengthens non-equilibrium effects. At a rate of 15 MPa/h, the relative volume and retrograde condensate saturation decrease by 9.09% and 5.38%, respectively, while condensate recovery improves by 13.85%. Moreover, the characteristic relaxation time toward equilibrium exhibits a strong dependence on the depletion rate, increasing as the depletion rate rises. This work provides an experimentally constrained analytical framework for describing rate-dependent non-equilibrium phase behavior during pressure depletion and for interpreting its impact on condensate recovery in the specific condensate-gas system studied. Although the governing framework may be transferable to other rate-sensitive hydrocarbon systems after fluid-specific recalibration, the parameterized analytical model and validation presented in this study are limited to the investigated condensate-gas fluid, and its applicability to other hydrocarbon fluid types remains to be evaluated in future studies. [ABSTRACT FROM AUTHOR]
Database: Energy & Power Source
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Header DbId: enr
DbLabel: Energy & Power Source
An: 194909351
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  Label: Title
  Group: Ti
  Data: Study on the Non-Equilibrium Dynamic Phase Transition Model for Oil–Gas Systems.
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  Data: <searchLink fieldCode="AR" term="%22Tu%2C+Hanmin%22">Tu, Hanmin</searchLink><relatesTo>1</relatesTo> (AUTHOR)<i> t.hanmin@swpu.edu.cn</i><br /><searchLink fieldCode="AR" term="%22Peng%2C+Yi%22">Peng, Yi</searchLink><relatesTo>1</relatesTo> (AUTHOR)<br /><searchLink fieldCode="AR" term="%22Guo%2C+Ping%22">Guo, Ping</searchLink><relatesTo>1</relatesTo> (AUTHOR)<br /><searchLink fieldCode="AR" term="%22Wang%2C+Zhouhua%22">Wang, Zhouhua</searchLink><relatesTo>1</relatesTo> (AUTHOR)<br /><searchLink fieldCode="AR" term="%22Wang%2C+Shuoshi%22">Wang, Shuoshi</searchLink><relatesTo>1</relatesTo> (AUTHOR)<br /><searchLink fieldCode="AR" term="%22Li%2C+Yu%22">Li, Yu</searchLink><relatesTo>1</relatesTo> (AUTHOR)<br /><searchLink fieldCode="AR" term="%22Chen%2C+Wei%22">Chen, Wei</searchLink><relatesTo>1</relatesTo> (AUTHOR)<br /><searchLink fieldCode="AR" term="%22Wang%2C+Lidong%22">Wang, Lidong</searchLink><relatesTo>1</relatesTo> (AUTHOR)<br /><searchLink fieldCode="AR" term="%22Deng%2C+Xiang%22">Deng, Xiang</searchLink><relatesTo>1</relatesTo> (AUTHOR)
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  Data: <searchLink fieldCode="JN" term="%22Energies+%2819961073%29%22">Energies (19961073)</searchLink>. Jun2026, Vol. 19 Issue 12, p2902. 28p.
– Name: Subject
  Label: Subject Terms
  Group: Su
  Data: *<searchLink fieldCode="DE" term="%22Gas+condensate+reservoirs%22">Gas condensate reservoirs</searchLink><br />*<searchLink fieldCode="DE" term="%22Phase+transitions%22">Phase transitions</searchLink><br />*<searchLink fieldCode="DE" term="%22Oil-gas+mixtures%22">Oil-gas mixtures</searchLink><br />*<searchLink fieldCode="DE" term="%22Simulation+methods+%26+models%22">Simulation methods & models</searchLink><br />*<searchLink fieldCode="DE" term="%22Chemical+relaxation%22">Chemical relaxation</searchLink><br />*<searchLink fieldCode="DE" term="%22Hydrocarbon+manufacturing%22">Hydrocarbon manufacturing</searchLink>
– Name: Abstract
  Label: Abstract
  Group: Ab
  Data: In gas-condensate reservoirs, the phase behavior of reservoir fluids is inherently dynamic during pressure depletion. When the rate of external pressure decline exceeds the intrinsic relaxation rate governing phase equilibrium, the system deviates from thermodynamic equilibrium and exhibits pronounced non-equilibrium effects. These transient behaviors significantly influence fluid properties; meanwhile, conventional equilibrium models neglect phase transition lag, resulting in inaccurate phase behavior and biased production predictions. In this study, a non-equilibrium dynamic phase transition model is developed to quantitatively couple the pressure depletion rate with the relaxation kinetics of the system. This model, established based on controlled non-equilibrium phase transition experiments performed on the condensate-gas fluid investigated in this work, provides an analytical framework for describing the temporal evolution of phase behavior under dynamic conditions. Model validation through integrated experimental measurements and numerical simulations shows good agreement between calculated and measured results for the studied condensate-gas system, with average relative errors below 5%. Results reveal that accelerated pressure depletion strengthens non-equilibrium effects. At a rate of 15 MPa/h, the relative volume and retrograde condensate saturation decrease by 9.09% and 5.38%, respectively, while condensate recovery improves by 13.85%. Moreover, the characteristic relaxation time toward equilibrium exhibits a strong dependence on the depletion rate, increasing as the depletion rate rises. This work provides an experimentally constrained analytical framework for describing rate-dependent non-equilibrium phase behavior during pressure depletion and for interpreting its impact on condensate recovery in the specific condensate-gas system studied. Although the governing framework may be transferable to other rate-sensitive hydrocarbon systems after fluid-specific recalibration, the parameterized analytical model and validation presented in this study are limited to the investigated condensate-gas fluid, and its applicability to other hydrocarbon fluid types remains to be evaluated in future studies. [ABSTRACT FROM AUTHOR]
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        Value: 10.3390/en19122902
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      – Code: eng
        Text: English
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        PageCount: 28
        StartPage: 2902
    Subjects:
      – SubjectFull: Gas condensate reservoirs
        Type: general
      – SubjectFull: Phase transitions
        Type: general
      – SubjectFull: Oil-gas mixtures
        Type: general
      – SubjectFull: Simulation methods & models
        Type: general
      – SubjectFull: Chemical relaxation
        Type: general
      – SubjectFull: Hydrocarbon manufacturing
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      – TitleFull: Study on the Non-Equilibrium Dynamic Phase Transition Model for Oil–Gas Systems.
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            – D: 15
              M: 06
              Text: Jun2026
              Type: published
              Y: 2026
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              Value: 12
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            – TitleFull: Energies (19961073)
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