Study and Application of Precipitated Particle Profile Control andDisplacement Agent
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摘要:
针对注入水或地层水矿化度高油田聚合物驱驱油效果差的问题，开发了一种“硅酸钠+分散剂”的调驱体系。该调驱体系与注入水或地层水中的钙镁离子反应，可以迅速生成最小粒径小于100 nm的沉淀粒子。通过调节分散剂与硅酸钠质量浓度之比，可调控沉淀粒子的团聚程度，使初始粒径在 60.4 nm至3.85 μm可控，分散时间在2～144 h可控，可适配不同渗透率的油藏。沉淀粒子聚集后，聚集体的最终粒径超70 μm，可有效封堵高渗流通道，实现深部液流转向。该调驱体系在南海某油田的P8注采井组进行了现场试验，该井组注入水的矿化度为34 g/L，连续注入沉淀调驱体系192 d后，平均注水压力升高2.9 MPa，2口受效井的含水率分别降低了4.6和17.8百分点，累计增油量超6 200 m³，有效期在4月以上。研究和现场试验表明，设计的沉淀调驱体系可以解决注入水矿化度高油田聚合物调驱效果差的问题，为注入水高矿化度油田调驱提供技术支持。
Abstract:In the oilfield with a high salinity of injected water or formation water, the effect of polymer profile control and displacement agent is poor. To address this issue, a profile control and displacement system of “sodium silicate + dispersant” was designed. Together with calcium and magnesium ions in injected water or formation water, precipitated particles with a minimum particle size of less than 100 nm could be rapidly formed. Adjusting the concentration ratio of sodium silicate to dispersant could change the agglomeration degree of precipitated particles making the initial particle size controllable within 60.4 nm–3.85 μm, and controlling the dispersion time within 2–144 h which is feasible to accommodate reservoirs with different permeability. After the aggregation of precipitated particles, the final particle size of aggregates exceeded 70 μm, which could effectively block high-permeability channels and achieve deep fluid flow steering. The profile control and displacement system was tested in the P8 injection and production well group of an oilfield in the South China Sea. The salinity of injected water in this well group was 34 g/L, and the average injection pressure increased 2.9 MPa after 192 days of continuous injection of the precipitated particle profile control and displacement system. The water cut of the two affected wells was reduced by 4.6 and 17.8 percentage points, respectively, resulting in a cumulative oil gain of over 6 200 m3,with a valid period longer than 4 months. The research and field test show that the designed precipitated particle profile control and displacement system can solve the problem of poor profile control and displacement effects in oilfields with high salinity of injected water and provide technical support for oilfields with high salinity of injected water.
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图 3 不同配方沉淀粒子体系的初始粒径分布
Figure 3. Initial particle size distribution of precipitated particle system with different formulations
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图 5 不同配方沉淀粒子体系注入压力与注入量的关系
Figure 5. Relationship between injection pressure and injection rate of precipitated particle system with different formulations
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图 6 注入压力、含水率和最终采收率与注入量的关系
Figure 6. Relationship among injection pressure, water cut, final recovery, and injection rate
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图 7 P8井深部调驱注入曲线
Figure 7. Injection curve of deep profile control and displacement of Well P8
表 1 不同配方沉淀粒子体系的初始粒径与分散时间
Table 1 Initial particle size and dispersion time of precipitated particle system with different formulations
配方 试剂质量浓度/（mg·L−1） Ca2+、Mg2+质量浓度/
（mg·L−1）d50/nm 分散时间/h 硅酸钠 分散剂 初始状态 完全沉淀后 1 1 500 0 1 783 4 870.0 72 800 不稳定 2 100 3 850.0 70 980 1～2 3 300 529.0 74 700 12～24 4 500 464.0 72 200 12～24 5 1 000 88.7 71 200 72～96 6 1 500 73.9 74 200 96～120 7 2 500 60.8 71 400 120～144 8 3 000 60.4 76 100 120～144 
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表 2 不同配方沉淀粒子体系的Zeta 电位
Table 2 Zeta potential of precipitated particle system with different formulations
配方 硅酸钠质量
浓度/（mg·L−1）分散剂质量
浓度/（mg·L−1）pH值 Zeta电位/mV 9 300 20 7～8 −6.6 10 50 7～8 −10.8 11 100 8～9 −15.7 12 150 8～9 −26.3 13 200 8～9 −38.4 14 300 9～10 −44.5 15 500 9～10 −57.3 16 600 9～10 −58.8
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表 3 不同配方沉淀粒子体系的阻力系数和残余阻力系数
Table 3 Resistance coefficient and residual resistance coefficient of precipitated particle system with different formulations
配方 试剂质量浓度/（mg·L−1） Ca2+、Mg2+质量
浓度/（mg·L−1）初始粒径/nm 岩心渗透率/mD 阻力系数 残余阻力系数 硅酸钠 分散剂 1 1 500 0 1 783 4 870.0 260 500 1000 4 500 464.0 260 3.07 1.00 500 2.57 2.71 1 000 2.50 2.52 6 1 500 73.9 260 2.07 2.53 500 1.85 2.38 1 000 1.50 2.33 8 3 000 60.4 260 1.53 1.73 500 1.43 1.50 1 000 1.24 1.24
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表 4 不同配方沉淀粒子体系驱替试验结果
Table 4 Displacement experiment results of precipitated particle system with different formulations
配方 试剂质量浓度/
（mg·L−1）含油饱和度，% 采收率，% 硅酸钠 分散剂 水驱 沉淀粒子驱 后续水驱 5 1 500 1 000 88.7 21.9 6.2 15.1 8 3 000 60.4 22.6 4.7 18.3
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表 5 受效井措施前后的生产情况
Table 5 Production effects of affected wells before and after measure implementation
受益井 措施后见效时间/d 日产液量/m3 日产油量/m3 含水率，% 措施后累计增油量/m3 措施前 措施后 措施前 措施后 措施前 措施后 P1井 56 116.9 112.7 22.8 31.9 78.6 74.0 2 069.2 P2井 38 117.1 114.0 20.5 39.0 82.5 64.7 4 177.5
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