Experimental study on the effect of water activity of drilling fluid on shale wellbore stability—Taking Xiushan Longmaxi shale as an example
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摘要: 通过压力传递实验，对秀山龙马溪组页岩进行了不同浓度和不同类型盐溶液影响下的渗流试验，确定不同水活度盐溶液对页岩渗流规律和井壁稳定影响机理。结果表明：（1）在相同浓度的盐溶液中，阻缓秀山龙马溪组页岩孔隙压力传递能力最强的盐类为HCOONa。（2）对于相同类型的盐溶液，最高的浓度并不总能具有最好阻缓能力。阻缓秀山龙马溪组页岩孔隙压力传递效果较好的前5种盐溶液是20% HCOONa、5% HCOONa、20% KCl、20% HCOOK和5% NaCl。（3）相对于人工压制页岩，在粘土矿物含量（20%）一致时，盐溶液贯穿龙马溪组页岩孔隙时间平均长90.11%，平均渗透率低99.14%。（4）在粘土矿物成分一致时，盐溶液在人工页岩中的渗流规律与龙马溪组页岩的一致性较好，但对于实际渗透率和渗流时间、表征系数与真实页岩相差大于90%。（5）针对龙马溪组页岩，提出了基于水活度的单位距离渗流时间模型，以及不同盐溶液的水活度-渗透率规律。研究成果可为适用于龙马溪组页岩钻进的水基钻井液体系遴选提供较好的理论和技术基础。Abstract: A series of fluid flow tests on different concentrations and different types of salt solutions were conducted on the shale samples through the pressure transfer experiment device to study the influence mechanism of salt ions with different water activities on shale seepage. The experimental results show that the salt solution with the strongest ability to block the pore pressure transmission of Xiushan Shale in Longmaxi Formation is HCOONa among the same concentration of different brines. In addition， the five types and concentrations of salt solutions with better resistance to pore pressure transmission are 20% HCOONa， 5% HCOONa， 20% KCl， 20% HCOOK and 5% NaCl. The highest concentration does not always have the best ability to block shale pore fluid transfer for the same type of salt solution. When the mineral composition is almost the same， the time to penetrate the pores and average permeability of the Xiushan shale of the Longmaxi Formation is 90.11% higher and 99.14% lower than that of the artificially compressed shale. The seepage law of artificially suppressed shale with salt solution is consistent with the real shale. However， the difference between the characterization coefficient is more than 90% for the actual permeability and seepage time. Moreover， a unit distance seepage time model based on water activity and water activity-permeability formulas under different salt ions are proposed for the Xiushan shale of Longmaxi Formation. The research results can provide experimental and theoretical basis for maintaining shale wellbore stability of the Longmaxi Formation with brine drilling fluid.
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Key words:
- shale /
- wellbore stability /
- salt solution /
- water activity /
- water-based drilling fluid
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