水力压裂页岩岩盐溶蚀数值模型的建立(一)

Maxian Seales , Robert M. Dilmore , Turgay Ertekin , John Y. Wang
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引用次数: 17

摘要

页岩气是含气的富有机质泥岩,具有广泛的天然裂缝。基质渗透率通常在10−4 mD或更小,孔喉尺寸在100-1000 nm附近。因此,为了达到经济的天然气采收率,需要进行增产。水平井与成功的多级水力压裂相结合是目前最成熟的有效增产方法。注入的压裂液通常含有1-7%的KCL,用于稳定粘土。然而,对返排水的化学分析表明,其溶解固体含量是注入液的10-20倍;总溶解固体(TDS)可高达197,000 mg/L,仅氯化物含量就高达1,510,000 mg/L (Haluszczak等人,2013)。本文概述了一个完全隐式流体输运和岩盐溶解数值模型的开发和验证,该模型用于预测和分析水力压裂页岩地层返排水的离子组成。该模拟器用于预测反排水中两种最主要的离子Na+和Cl−的浓度。本文提出了一种以双孔双渗模式(DPDP)作为裂缝性储层流体运移基础的岩盐溶蚀数值模拟方法。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Development of a halite dissolution numerical model for hydraulically fractured shale formations (Part I)

Gas-shales are gas bearing organic-rich mudstone with extensive natural fractures. Matrix permeability is typically in the region of 10−4 mD or less, and pore throat sizes are in the vicinity of 100–1000 nm. Consequently, stimulation is required to achieve economic gas recovery rates. Horizontal wells combined with successful multi-stage hydraulic fracture treatments are currently the most established method for effectively stimulating such formations.

The injected fracture fluid typically contains 1–7% KCL for the purpose of clay stabilization. However chemical analysis of the flowback water shows that it contains 10–20 times more dissolved solids than the injected fluid; total dissolve solids (TDS) can be as high as 197,000 mg/L with chloride levels alone being as much as 1,510,000 mg/L (Haluszczak et al., 2013).

This paper outlines the development and validation of a fully implicit fluid transport and halite dissolution numerical model that is used to predict and analyze the ionic compositions of flowback water from hydraulically fractured shale formations. The simulator is designed to predict the concentration of Na+ and Cl, which are the two most predominant ionic species in flowback water. The paper presents a method for numerically simulating halite dissolution using the dual porosity dual permeability paradigm (DPDP) as the foundation for fluid transport in fractured reservoir.

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