In the development of deep high-temperature and high-salinity reservoirs, there exists the problem of water channeling caused by casing damage and large fractures in the reservoirs. The commonly used cement channeling and plugging agents and particulate plugging agents have been difficult to meet the water plugging requirements. The resin channeling and plugging agents using bisphenol A unsaturated polyester resin as the core material have the characteristics of high temperature resistance, corrosion resistance and high strength. By using the resin channeling and plugging agent with bisphenol A unsaturated polyester as the core material with the characteristics of high-temperature resistance, corrosion resistance, high strength, we develop a new channeling & plugging agent suitable for deep high-temperature reservoirs with the optimal raw material ratio and the dosage of crosslinking monomer, polymerization inhibitor, initiator and silane coupling agent by optimizing the raw material ratio and the dosage of crosslinking monomer, polymerization inhibitor, initiator and silane coupling agent. The results show that when the molar ratio of D-33 (propoxylated bisphenol A), maleic anhydride and phthalic anhydride is 1.20∶1.00∶0.04, and when the mass fraction of crosslinking monomer, initiator and polymerization inhibitor is 30.00%, 0.08% and 0.10% respectively, the curing time of channeling blocking agent is the longest and the compressive strength is the largest. At 130 ℃, the curing time can reach 1 h, and the compressive strength is more than 20 MPa. The optimal construction temperature of the channeling blocking agent system is from 35℃ to 40 ℃, The viscosity is about 1 000 mPa·s. It can be stable at 260 ℃ and below, and can be used in deep high-temperature reservoir. Adding silane coupling agent can effectively enhance the channeling sealing performance of channeling sealing and plugging agent system. When the mass fraction of silane coupling agent is 3.00%, the maximum displacement breakthrough pressure can reach 11.9 MPa. By fitting the relationship between gel time and formation temperature, the prediction of channeling blocking agent gel time can be realized, which can effectively guide the field construction.

针对塔河油田油藏储层深且高温、高盐的储藏条件,目前无机硅酸盐水玻璃凝胶易高温老化脱水,使得封堵效果变差.鉴于此,亟需研发一种在高温、高矿化度条件下具有老化稳定性好、强度高和封堵性能好的凝胶堵剂.制备了有机-无机复合凝胶,采用成本低廉的工业腐植酸与水玻璃复合,尿素做延迟交联剂,制备了腐植酸-水玻璃复合凝胶,以基液粘度、pH、成胶时间、成胶强度和高温老化稳定性为依据优选最优配方,以注入性能和封堵性能评价凝胶封堵效果.结果表明,最佳配方3％腐植酸+3％尿素+20％水玻璃,基液粘度14.2 mPa·s,pH为11.68,在130℃条件下,成胶时间90-120 min,成胶强度为0.07 MPa,30 d内不脱水,具有较好的注入性和封堵性.在单管填砂管中注入0.5 PV该体系后,1 100 mD渗透率填砂管的封堵率大于90％.

针对塔河高温高盐油藏普通冻胶或泡沫体系的油水选择性差,且难以长期改善吸水剖面的问题,将泡沫驱油和冻胶调剖技术相结合,研制一种适应于塔河高温高盐油藏深井调驱的冻胶泡沫体系.考察了起泡剂的耐温耐盐性、与抗稀释冻胶配伍性,耐温耐盐冻胶泡沫体系最优配方为0.5％SLSF-4起泡剂+0.5％P-71+1％P-9聚合物+0.5％对苯二酚+0.5％六亚甲基四胺+0.5％海藻酸钠,评价了冻胶泡沫体系的油水选择性和采收率.结果表明,在相同渗透率下,冻胶泡沫体系对含水填砂管的残余阻力系数为36.21,而含油填砂管为14.32,说明对含水层调流能力强,将含油层转变为优势通道,说明其具有较好的油水选择性.双管驱油实验表明,冻胶泡沫优先进入高渗通道,洗出注入水驱不出的残余油,其含量为3.75％,选择性地堵高不堵低,很好地改善吸水剖面,提高水驱波及系数,采收率总体提高39.41％.

为解决常规聚丙烯酰胺冻胶在高温高盐条件下易降解、脱水等问题,选用魔芋葡甘聚糖KGM、丙烯酰胺(AM)/2-丙烯酰胺-2-甲基丙磺酸(AMPS)二元聚合物P(AM/AMPS)为主剂,黄原胶为增强剂、乌洛托品、对苯二酚为交联剂制备了一种复合冻胶,通过基液黏度、成胶时间和成胶强度考察冻胶中各物质最优添加量,通过傅里叶红外变化光谱(FT-IR)、热重(TGA)对其进行表征,考察了该复合冻胶的成胶强度、耐温性能和封堵效果.研究结果表明,所制备的复合冻胶具有较强的耐温耐盐性能,成胶时间在120～180 min可调,能够满足温度为130℃、矿化度为210 g/L的苛刻油藏环境,并且能够保持长期稳定性.当P(AM/AMPS)加量为0.5％、KGM加量为0.5％、黄原胶加量为0.3％、乌洛托品加量为0.5％、对苯二酚加量为0.6％时,复合冻胶的成胶强度最大,成胶后的弹性模量达35.233 Pa,老化7 d后弹性模量逐渐增至71.377 Pa.该冻胶对岩心具有较强的封堵性能,注入量为1 PV时,该冻胶体系对渗透率约为800×10-3μm2岩心的封堵率可以达到99.11％.