The influence of polymer on stability and shear rate on droplet size of emulsion is evaluated in the laboratory, microstructure of the emulsion is observed under a microscope, and the pore distribution of the cores is analyzed through mercury injection experiments. In the process of surfactant-polymer (SP) flooding, the thickness of polymer absorbed on the surface of the rock is calculated by a mathematical model. The experiments show that the polymer is good for the stability of emulsion, with the increase of shear rate, stability becomes better, and droplet size gets smaller. Due to the adsorption of polymer, the pore throat turns narrow, seepage velocity is increasing, and also the emulsion becomes more stable with the smaller-size droplets. During the single emulsifier flooding, the emulsion is easy to coalescence for its instability, and the seepage channel can be easily blocked, which leads to the high injection pressure. Consequently, the polymer plays an important role on emulsion stability in SP flooding. V C 2015 Wiley Periodicals, Inc. J. Appl. Polym. Sci. 2015, 132, 42171.

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Hydrate control research is of great significance to the efficient development of deepwater gas wells. A deepwater gas well intervention wellbore hydrate suppression experimental device was built to simulate the field intervention operation and monitor the hydrate generation in the kettle in real time. The physical simulation experiments were conducted for the injection concentration, injection volume, and injection rate of the glycol inhibitor for different working conditions of the intervention operation. The results show that the hydrate inhibition effect is good when the injection concentration of glycol solution is 40%, the hydrate plugging in the wellbore is slow when the injection volume is 20 mL, and the hydrate inhibition is effective when the injection rate is 4 mL/min. The injection of glycol inhibitor can effectively delay the time required for wellbore hydrate plugging and ensure the intervention operation. The above research results provide ideas for in-wellbore hydrate control in deepwater gas well intervention operations in the field.

In order to solve the problem of water intrusion seriously affecting the development of each production well in TY gas field, a numerical model was established with reference to well X in TY gas field to study the characteristics of water intrusion in TY gas field, and four sets of water control and production increase experiments were completed, including elastic extraction experiment, water plugging experiment, side drilling experiment and combined water plugging and side drilling process experiment, which were verified by physical experiments on this basis. The results show that different water control and production enhancement measures have different effects, among which the combination of water plugging and lateral drilling process has the best effect, which can increase the gas production by 84.1%, and the error between the physical experiment results and the numerical simulation results is 7.7%.