引用本文:张学平,刘友权,张鹏飞,周厚安. 大川中沙溪庙致密砂岩储层支撑裂缝导流能力的影响因素[J]. 石油与天然气化工, 2024, 53(3): 92-97.
【打印本页】   【HTML】   【下载PDF全文】   查看/发表评论  【EndNote】   【RefMan】   【BibTex】
←前一篇|后一篇→ 过刊浏览    高级检索
本文已被:浏览 294次   下载 53 本文二维码信息
码上扫一扫!
分享到: 微信 更多
大川中沙溪庙致密砂岩储层支撑裂缝导流能力的影响因素
张学平,刘友权,张鹏飞,周厚安
中国石油西南油气田公司天然气研究院
摘要:
目的增加裂缝导流能力,提高致密砂岩气的压裂增产稳产效果。 方法为了探究加砂压裂技术在大川中沙溪庙致密砂岩储层改造中的适应性,针对该储层的特点,采用API裂缝导流能力测试仪,考查了支撑剂类型及粒径、铺砂浓度、闭合压力及压裂液类型对支撑裂缝导流能力的影响。 结果相同粒径陶粒的支撑裂缝导流能力大于覆膜石英砂和石英砂,但覆膜石英砂的导流能力受闭合压力的影响最小;0.106~0.212 mm石英砂与0.212~0.425 mm覆膜石英砂的不同组合支撑剂粒径(质量比分别为1∶4、1∶1和4∶1)支撑剂导流能力下降幅度相比单一支撑剂更加平缓。支撑剂组合为4∶1的裂缝导流能力高于1∶4和1∶1组合,在高闭合压力条件下接近0.212~0.425 mm覆膜石英砂用作单一支撑剂时的裂缝导流能力。在低闭合压力条件下,增加铺砂浓度促使导流能力明显增大。而随着闭合压力的增加,这种影响程度逐渐减弱。支撑剂采用(0.106~0.212 mm石英砂)∶(0.212~0.425 mm覆膜石英砂)用量为4∶1的组合支撑剂,当闭合压力为41.4 MPa时,清水压裂破胶液处理后的液测导流能力较质量分数为3% 的KCl降低25.43%,返排压裂破胶液处理后的液测导流能力较质量分数为3% 的KCl降低58.34%。 结论实验结果指导了现场压裂支撑剂类型、粒径以及铺砂浓度等施工参数的选择,在四川盆地川中沙溪庙组致密气储层进行现场应用,获得了较好的压裂增产效果。 
关键词:  致密砂岩  支撑剂  导流能力  缝宽  增产效果 
DOI:10.3969/j.issn.1007-3426.2024.03.015
分类号:
基金项目:中国石油西南油气田分公司重大专项“四川盆地中西部地区致密气勘探开发理论及关键技术研究”(2022ZD01)
Influencing factors of the fracture conductivity of propped cracks in the Shaximiao tight sandstone reservoir in central Sichuan
ZHANG Xueping, LIU Youquan, ZHANG Pengfei, ZHOU Houan
Research Institute of Natural Gas Technology, PetroChina Southwest Oil & Gasfield Company, Chengdu, Sichuan, China
Abstract:
ObjectiveIncreasing the fracture conductivity of tight sandstone and thus improve the fracturing effect to increase and stabilize the production. Methods In order to investigate the adaptability of sand-added fracturing technology in the reforming of the Shaximiao tight sandstone reservoir in central Sichuan, the influence of proppant type and particle size, sand concentration and closure pressure, and fracturing fluid type on the fracture conductivity was investigated using the API fracture conductivity tester. ResultsThe results showed that the proppant fracture conductivity of ceramic grains with the same grain size was greater than that of coated quartz sand and quartz sand, but the conductivity of coated quartz sand was least affected by closed pressure. The decrease of proppant conductivity of different combinations of grain sizes (1∶4,1∶1 and 4∶1) of 0.106-0.212 mm quartz sand and 0.212-0.425 mm coated quartz sand was more moderate compared with that of single proppant. The fracture conductivity of proppant combination 4∶1 was higher than that of the 1∶4 and 1∶1 combinations and approached that of the single proppant for 0.212-0.425 mm coated quartz sand at high closed pressure conditions. The increase in sand laydown concentration resulted in a significant increase in the infiltration capacity at low closed pressure. At high closed pressure, this effect gradually decreases. With 4∶1 proppant combination of 0.106-0.212 mm quartz sand and 0.212-0.425 mm coated quartz sand, when the closing pressure was 41.4 MPa, the flow conductivity tested with breaker fluid (prepared from fracturing fluid prepared with clear water) was 25.43% lower than that of 3 wt% KCl, and the flow conductivity tested with breaker fluid (prepared from fracturing fluid prepared from backflow fluid) was 58.34% lower than that of 3 wt% KCl. ConclusionThe experimental results guided the selection of construction parameters such as fracturing proppant type, grain size, and sand spreading concentration in the field. They were applied in the field of tight gas reservoirs of the Shaximiao Formation in the central Sichuan Basin, obtaining better fracturing and production enhancement results.
Key words:  tight sandstone  proppant  conductivity  fracture width  incremental production effect