一种耐温抗盐预交联凝胶颗粒及其应用

A High Temperature and High Salinity Resistant Particulated Precrosslinked Gel and Its Use for Reservoir Permeability Adjustment

由2-丙烯酰胺基2-甲基丙磺酸（AMPS）、含Si-Si和Si-C键的无机物、有机硅类偶联剂在引发剂存在下反应,制得凝胶状物,经剪切、造粒得到预交联凝胶颗粒。详细考察了该凝胶颗粒的吸水膨胀性能。在矿化度158.5g/L的濮三联现场回注污水中,凝胶颗粒吸水膨胀达到平衡的时间,粒径为0.5、1-33、-5 mm时在80℃下分别为2.5、6、9小时;粒径为1-3 mm时,室温下超过24小时,80℃和90℃下为6-8小时,吸水膨胀倍数〉10;在70-135℃水中老化15天后膨胀倍数显著下降,此后直到60天维持不变,在135℃下为5-12;在350 g/L高矿化水中于135℃老化时膨胀倍数值较低但随老化时间的变化趋势相似;在135℃、45 MPa压力下老化时膨胀倍数比常压下老化时降低2.5-3.5。在高温高盐的濮城东区沙二下油藏使用该凝胶颗粒进行深部调剖,注入粒径、段塞浓度（2-6 kg/m^3,在注入水中）及段塞结构根据注入压力确定,施工井为注水井濮5-112和濮4-581,分别注入颗粒悬浮液6360和4250 m^3（0.05和0.10 PV,含颗粒剂21.5和14.5 t）及无机调剖剂140和20 m^3。4口对应油井中有3口在深部调剖后产液量减少,产油量增加,含水下降,有效期为6-10个月。图5参4。

A high temperature and high salinity resistant particulated precrosslinked gel （PPG） is prepared by reacting 2-acrylamido-2- methyl propane sttlfonic acid, AMPS, inorganic material containing Si-Si and Si-C bonds, silicon coupling agent at the presence of an initiator and cutting and granulating the gelled reaction product. The swelling and expanding behavior of PPG is investigated extensively. In recycled oilfield produced water （RPW） of TSD = 158.5 g/L for reservoir flooding taken from the P-3 gathering/treating plant, the time needed for PPG swelling to reach equilibrium is of 2.5,6, and 9 has at 80℃ for particle size 0.5,1-3, and 3- 5 mm, respectively, and of 〉24 hrs at room temperature and 6-8 hrs at 80℃ and 90℃ for particle size 1-3 mm; in all the above cases the PPG swelling factor is 〉 10; the swelling factor of PPG in RPW notably decreases in 15 days of ageing in the RPW at 70- 135℃ and keeps unchanged up to 60 days of agdng, being in range 5-12 at ageing temperature 135℃ ; the PPG swelling factor at ageing temperature 135℃ in 350 g/L highly mineralized water is less and its changes with ageing time is similar; when being aged in the RPW at 135℃ and 45 MPa pressure, the PPG swelling factor is by 2.5-3.5 less in comparison with that in normal pressure ageing. In indepth profile modification （IDPM） operations performed in HTHS oil reservoir in strata S2L of east Pucheng district, the particle size, the slug concentration （2-6 kg/m^3 in RPW）, and the slug structure were designed and determined according to the changes in injection pressure. 6360 m^3, or 0.05 PV, of PPG suspensin in RPW containing 21.5 t PPG followed by 140 m^3 of inorganic profiling agent were injected into injection well P5-112 and 4250 m^3, or 0.10 PV, of PPG suspension in RPW containing 14.5 t PPG followed by 20 m^3 of inorganic profiling agent-into well P4-581. As a result of the IDPM, art increase in oil production and a decrease in fluid production and water cut were observed in 3 of 4 connected production well in 6-10 months.