Understanding the hydrate deposition law can provide ideas for the optimization of intervention operation plans and the prevention and control of hydrate in the wellbore of deepwater gas wells. On the basis of the gas?liquid two?phase flow model, a wellbore pressure and temperature prediction model was developed based on the heat exchange and frictional gradient changes caused by the lowering of the intervention tool, and the temperature and pressure models were coupled to solve by the iterative method. Based on the hydrate growth kinetic model, combined with the wellbore temperature and pressure prediction results, a hydrate deposition model was established, and the hydrate deposition law in the wellbore under intervention operations was analyzed. The results showed that the increase of production led to the increase of pressure difference in the wellbore and the higher wellbore temperature at the mudline under high production. With the release of the intervention tool, the pressure in the wellbore increases, but the pressure increase gradually decreases, and the maximum pressure increase at the wellhead is about 3.0 MPa. When the proportion of the intervention tool diameter is less than 50%, the larger the tool diameter, the higher the wellbore pressure. The location of the wellbore mudline is a high?risk area for hydrate deposition plugging, and the rate of hydrate deposition in low?producing wells is faster than that in high?producing wells. The wellbore hydrate deposition rate is the fastest when the intervention tool is placed near the mudline, and the wellbore hydrate deposition rate is faster when the intervention tool diameter accounts for 50%.