降低松散砂岩地层高粘度油井的出水量

Hamad Al-Rashidi, M. Hussein, Abdulaziz Erhamah, Satinder Malik, A. Al-Hajri, Dwane Almeida, N. Salehi, G. Omonte, A. Zaitoun
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引用次数: 0

摘要

科威特储量巨大的高稠油要求提高采收率。在科威特的松散砂岩地层中,砂岩层段代表了广泛的砂岩储层,由横向广泛的非储层段隔开,非储层段包括细粒砂岩、泥质砂岩、粉砂和泥浆。储层浅,渗透率高(1000 mD以上),受底层含水层压力支撑。由于油水粘度对比强,突破后含水率迅速上升,生产效率损失较大。因此,减少水产量是改善生产条件的强制性措施。候选井在不同的岩相中有2到3个开放层段,产量单一。射孔总长度在38 ~ 48英尺之间。通过PCP的产量约为300桶/天,BS&W在71% ~ 87%之间。该技术采用了具有RPM特性的预胶化粒径控制产品(SMG微凝胶),即在不影响油的相对渗透率的情况下,诱导水的相对渗透率大幅下降。选择该尺寸是为了选择性地处理高渗透产水层,同时保留低渗透含油层。该化学品还可以承受井下的恶劣条件,例如约170,000ppm的盐度和2% H2S的存在。处理方法包括通过油管向井口注入300球预凝胶化化学品。最初的结果似乎非常令人满意,因为两口井的含水率从80%下降到40%,总产量几乎相同。石油增量超过100桶。第三口井经WSO处理后无明显变化。目前正在对这些井进行持续监测,以评估其长期性能。如果这一结果得到证实,将很有可能通过简单的化学井口注入来减少含水,从而提高含水层支撑下稠油油藏的产量。
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Mitigating Water Production from High Viscosity Oil Wells in Unconsolidated Sandstone Formations
Large reserves of High-Viscous Oil in Kuwait calls for Improved Oil Recovery scenarios. In Kuwait unconsolidated sandstone formations, the sandstone intervals represent extensive reservoir intervals of sand separated by laterally extensive non-reservoir intervals that comprise finer-grained, argillaceous sands, silts and muds. The reservoir is shallow with high permeability (above 1000 mD) and under bottom aquifer pressure support. Due to strong viscosity contrast between oil and water, after breakthrough, the water cut rises quickly resulting in strong loss of production efficiency. Mitigating water production is thus mandatory to improve production conditions. The candidate wells have 2 to 3 open intervals in different rock facies with comingle production. The total perforated length is between 38 and 48 ft. Production is through PCP at a rate of around 300 bpd and BS&W is between 71 and 87%. The technology applied utilizes pre-gelled size-controlled product (SMG Microgels) having RPM properties, i.e. inducing a strong drop of relative permeability to water without affecting oil relative permeability. The size is chosen to selectively treat the high-permeability water producing zones while preserving the lower-permeability oil zones. The chemical can also withstand downhole harsh conditions such as salinity of around 170,000ppm and presence of 2% H2S. The treatment consisted of bullhead injection of 300 bbls of pre-gelled chemical through tubing. The first results seem very favourable, sincefor two wells, the water cut has dropped from 80 to 40% with almost same gross production rate. The incremental oil is more than 100 bopd. The third well did not show marked change after WSO treatment. The wells are under continuous monitoring to assess long-term performance. Such result, if confirmed, may lead to high possibilities for the improvement of heavy-oil reservoir production under aquifer support by mitigating water production with simple chemical bullhead injection.
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