This study used simulated formation water (15 g/L CaCl₂) from a certain area of Xinjiang Oilfield as the experimental medium., and employed a high-pressure sealed reaction vessel and a sapphire window to systematically investigate the effects of water content (30%–70%), initial pressure (2–14 MPa), and the intervention of CH₄ on the critical point of CO₂ hydrate formation. The differences between the ‘visual confirmation’ method and the temperature-pressure curve inflection point method for determining hydrate formation were also compared. The study found that in a single CO₂ system under a constant pressure of 5 MPa and a water content of 30%–70%, no visible hydrate was observed with the naked eye. However, the inflection point method showed that the theoretical critical temperature and pressure increased with the increase in water content. For a 50% water content system, there was a threshold pressure range of 8–11 MPa. Only when the initial pressure was higher than this threshold would visible hydrates form, and the critical point shifted upward with the increase in pressure. In the CO₂-CH₄ mixed system, the critical point under a constant pressure of 10 MPa showed a V-shaped trend with changes in gas ratio, with a minimum point at a 1:1 ratio; the constant ratio and variable pressure experiment indicated that the intervention of CH₄ significantly increased the critical temperature and pressure. Furthermore, the introduction of CH₄ changed the growth position of hydrates, shifting them from the gas-liquid interface to the liquid phase matrix. The study revealed the pressure threshold effect of CO₂ hydrate formation in high mineralization degree formation water systems and the gas component competition mechanism: when the ratio of the two components is balanced, the competitive effect is minimized, forming the optimal formation conditions; as the proportion of CH₄ increases, its competitive advantage strengthens, not only increasing the critical temperature and pressure, but also driving the shift of the hydrate growth position, demonstrating the decisive regulatory role of gas components on the equilibrium and formation kinetics of hydrates, providing experimental basis for the risk prevention of hydrates in the CO₂ flooding process.

During the implementation of CO₂ fracturing for oil and gas development, the force transfer effect caused by the unsteady flow of high-pressure CO₂ fluid can lead to forced vibration of the tubing and ensuing structural fatigue. In this study, a forced vibration analysis of tubing under CO₂ fracturing conditions is carried out by taking into account the fluid-structure coupling and related interaction forces by means of the method of characteristics (MOC). The results show that for every 1 m³/min increase in pumping displacement, the fluid flow rate increases up to 3.67 m/s. The flow pressure in the pipe tends to be consistent with the pumping pressure at the initial stage and then decreases with an increase in the pump starting time. When the pumping pressure increases by 10 MPa, the additional stress in the tubing increases by 11.8%, and the peak value of the additional stress at the bottom of the well is the largest. The temperature in the tubing grows with well depth, which causes a phase change in CO₂ due to heat absorption. At this time the pressure in the tubing decreases, the fluid flow rate increases by about 1.12 m/s, and the additional stress grows by about 1.5 MPa.