The conglomerate reservoir is provided with strong heterogeneity and complex pore structure. To study the matching relationship between polymer flooding system and pore throat of the conglomerate reservoir and set up the flow matching relationship plate, this paper conducted natural core flow experiments at the true flow rate of the site formation based on constant pressure flooding method, considering the shear of the borehole and the formation. And several suitable polymers for different reservoirs permeability were given. The experimental results indicated that a positive correlation between the flow properties and the viscosity of the polymer solution, but a negative correlation between the mobility and the permeability of reservoir. Such as the natural core with the permeability = 30×10-3μm2 was suitable for the viscosity≤16.0 mPa.s of the polymer solution in the formation, the natural core with the permeability = 60×10-3μm2 was suitable for the viscosity≤35.2mPa.s of the polymer solution and the natural core with the permeability = 120×10-3μm2 was suitable for the viscosity≤102.4mPa.s of the polymer solution. Using compatibility relationship, quickly and easily choose the right injection parameters of the polymer based on the reservoir permeability, providing a theoretical basis for program preparation and parameters adjustment of the polymer flooding.

In the process of polymer flooding in porous media, polymer was detained due to interactions between surface adsorption and polymer molecules, and this could lead to negative effects on oil displacement. For polymer adsorption in Xinjiang conglomerate reservoir, HPLC analysis was adopted to study the static and dynamic laws. Results have showed that the adsorption process could be divided into 3 stages: rapid growth, slow growth and stable state. With the loss of polymer molecular weight, equilibrium adsorption quantity reduces gradually. The adsorption amount is different for the same polymer on four types of oil sands. For equilibrium adsorption, the maximum value is argillaceous sandstone, followed by conglomeratic sandstone.The third is argillaceous gravel, and the minimum is sand gravel. For polymer flooding in conglomerate cores, the dynamic retention amount of seriate conglomerate is much greater than that of fine particle conglomerate. These data have provided reference for project design of polymer flooding in conglomerate reservoir.