【摘要】 由分子量4×106～7×106、水解度17.6%的聚丙烯酰胺(5～6g/L)、氧化还原体系交联剂Na2Cr2O7+NH4Cl、加入乙二醇的乳酸/丙酸/乙酸复配有机酸延缓剂组成的STP强凝胶调剖剂,其最佳成胶条件为pH值5.2,温度55℃,矿化度<7g/L,调节延缓剂用量可控制成胶时间(12～144h),适用温度为35～80℃。在3支串联高渗透率岩心和3支串联低渗透率岩心并联而成的非均质模型上,在水驱饱和油之后(合层采收率24.3%),依次用STP调剖剂封堵第一、第二、第三高渗岩心后水驱,合层采收率分别达到46.8%、62.2%和69.1%,由此得出结论:封堵深度越大,采收率提高幅度越大。讨论了有关的驱油机理。简介了2000～2001年大庆萨中开发区48井次处理半径10～20m的STP深部调剖作业的结果(成功率91.2%)。图5参5。更多还原

【Abstract】 The strong gel forming fluid STP is composed of an HPAM of M 4×10⁶—7×10⁶ and HD=17.6%（5—6 g/L）, redox crosslinker Na₂Cr₂O₇+NH₄Cl （1—1.5 g/L）, and mixed lactic/propionic/acetic acid with a little amount of ethyleneglycol added as retarder. The optimal gelation conditions are established as: pH 5.2, temperature 55℃, and salinity <7 g/L, the gelation time can be controlled in range 12—144 hrs through retarder dosage variation and the gelling fluid can be used in reservoirs of temperature 35—80℃. A heterogeneous physical model comprising 2 parallel series of 3 oil-saturated cores each, a high and a low permeable, is water flooded to water cut 98% and oil recovery 24.3% and then the 1st, the 2nd, and the 3rd high permeable cores are plugged by using gel STP and after every gel treatment the model is water flooded to water cut 98%. In result enhancement in oil recovery of 46.8%, 62.2%, and 69.1% is observed, respectively. It is concluded that the deeper the gel placed the higher the oil recovery. The oil displacing mechanisms involved are discussed. 48 STP gel treatments with action radius 10—20 m for indepth permeability adjusting in Central Saertu, Daqing, performed in 2000—2001 with successfulness 91.2% are described in brief.更多还原