A Research Of Deep Heavy Oil Thickening Water Flooding Technology On Lukeqin

The potential of heavy oil and bitumen sand resources is very great in the world and the production of Heavy oil has been got more and more attention. Our country has the abundant heavy oil resources, accounting for about30%of the total oil reserves. Because of its high viscosity, the mining and transportation process have many difficulties. Therefore, speeding up the development of heavy oil resources and making up for crude oil shortage has important meaning for the national economic development.Based on the characteristics of heavy oil in Lukeqin reservoir of Tuba oilfield, this paper has researched the thickened water Flooding technology for heavy oil in deep layer.Through a large number of experimental research and field tests, the results have been got as followed:(1)The viscosity of polymer solution increases with the polymer concentration. If the polymer concentrations are same, the viscosity order is as followed. The viscosity of HJPAM solution is largest. The SXPAM solution takes second place. The AKPAM solution is the minimum. The temperature has great influence on viscosity. The viscosity at80℃are as half as the viscosity at about30℃.(2)The Core experimental results show that the performance of oil flooding agent is good. The average remaining concentration of HJPAM solution is above90%after its adsorption in quartz. The average dynamic saturated stranded quantity is28.8ug/g. The average resistance coefficient and residual resistance coefficient in three experiments are18.0and3.7, which shows that the agent has the ideal oil displacement effect.(3) The results of oil displacement experimental parameters optimization show that the oil displacement agent formula is1500mg/L HJPAM+0.2%cross linking agent and the slug size is0.4PV. The recommend formula for T2K section of Keluqin oilfield is0.05PV (2000mg/L HJPAM+0.2%cross linking agent)+0.33PV (1500mg/LHJPAM+0.2%cross linking agent). The polymer flooding recovery can improve the recovery by10.98%.(4)Indoor studies and field application have shown that the profile modification can improve the gelled water flooding effect. The formula for profile control agent is0.2%HJPAM+0.4%cross linking agent. The gelling time of system is34h and the apparent viscosity is7976mPa s. The final recovery is increased by17.5%after the composed flooding and is6.5%more than the single agent drive recovery.