Tight condensate gas reservoirs have excellent prospects for exploration and development but suffer from liquid-lock damage due to their reservoir conditions.To solve the fluid-lock damage that seriously affects the production effect of gas wells in low-permeability tight condensate reservoirs,the optimal selection principle of fluid blocking system is determined according to the target reservoir and fluid characteristics.Using the reservoir core,the main agent of plugging is evaluated from the aspects of surface tension measurement,oil-water interfacial tension measurement,contact angle measurement,change of rock wettability,and oil-water self-imbibition test before and after the treatment of the plugging agent,and the carrying liquid is evaluated from the phase characteristics analysis and solution composition analysis.The final optimal system is composed of 0.1%FT+99.9%carrying liquid(ethylene glycol monobutyl ether:ethanol=3∶7),the surface tension of the system is as low as 20 mN/m,and the oil-water interfacial tension is as low as 1 mN/m.The oil-water contact angle after capillary treatment is greater than 80°,and the formation cores all show obvious oil-water double hydrophobicity after treatment.The research results provide a reference for developing and stimulating similar low-permeability tight gas reservoirs.
condensate gas reservoirtight gas reservoirliquid lockremoval liquidpharmaceutical systemoptimization and evaluation
NETL
NSTL
万方数据
