Construction and Application of a Coupled Temperature and Pressure Model for CO 2 Injection Wells Considering Gas Composition

Hang Lai, Peng Chen (), Lingang Lv and Song Lu
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Hang Lai: School of Geosciences, Yangtze University, Wuhan 430100, China
Peng Chen: School of Geosciences, Yangtze University, Wuhan 430100, China
Lingang Lv: School of Geosciences, Yangtze University, Wuhan 430100, China
Song Lu: Geological Research Institute, China Petroleum Logging Co., Ltd., Xi’an 710077, China

Energies, 2025, vol. 18, issue 5, 1-19

Abstract: Accurate prediction of the temperature and pressure fields in carbon dioxide (CO 2 ) injection wells is critical for enhancing oil recovery efficiency and ensuring safe carbon sequestration. At present, the prediction model generally assumes that CO 2 is pure and does not consider the influence of impurities in CO 2 components. This study takes into account the common impurities, such as air and various alkanes in CO 2 , and uses Refprop 9.0 software to calculate the physical parameters of the mixture. A comprehensive coupling model was developed to account for axial heat conduction, convective heat transfer, frictional heat generation, the soup coke effect, pressure work, and gas composition. The model was solved iteratively using numerical methods. We validated the accuracy of the calculated results by comparing our model with the Ramey model using measured injection well data. Compared with the measured bottom hole temperature and pressure data, the error percentage of our model to predict the bottom hole temperature and pressure is less than 1%, while the error percentage of Ramey model to predict the bottom hole temperature and pressure is 5.15% and 1.33%, respectively. Our model has higher bottom hole temperature and pressure prediction accuracy than the Ramey model. In addition, we use the model to simulate the influence of different injection parameters on wellbore temperature and pressure and consider the influence of different gas components. Each injection parameter uses three components. Based on the temperature and pressure data calculated by the model simulation, the phase state of CO 2 was analyzed. The results show that the impurities in CO 2 have a great influence on the predicted wellbore pressure, critical temperature, and critical pressure. In the process of CO 2 injection, increasing the injection pressure can significantly increase the bottom hole pressure, and changing the injection rate can adjust the bottom hole temperature. The research provides valuable insights for CO 2 sequestration and enhanced oil recovery (EOR).

Keywords: CCUS; wellbore temperature; wellbore pressure; mathematical model; injection parameters; gas components (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2025
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