Heterogeneity characteristics and its controlling factors of marine shale reservoirs from the Wufeng−Longmaxi Formation in the Northern Guizhou area
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摘要:
研究目的 页岩非均质性是其自身固有属性，研究页岩的微观非均质性特征对明确页岩气富集机制研究及优质储层段优选具有重要的指导意义。
研究方法 本文以黔北地区五峰组—龙马溪组海相页岩为研究对象，通过XRD、低温N2吸附、高压压汞等实验方法，重点分析了研究区海相页岩的宏观与微观孔隙结构非均质性特征。
研究结果 黔北地区五峰组—龙马溪组页岩主要发育硅质页岩岩相，其次为混合质页岩、黏质页岩岩相；不同岩相页岩在总有机碳含量、矿物组分、微观孔隙结构特征等方面具有较强的非均质性。采用N2吸附曲线FHH分形模型，及高压压汞岩石多孔结构分形理论，计算得到N2吸附低压分形维数D1（0<P/P0<0.45）为2.5351~2.6722，高压分形维数D2（0.45<P/P0<1）为2.8311~2.9113，另外，高压压汞分形维数DHg为2.0904~2.3736，表明黔北地区五峰组—龙马溪组不同孔径范围内孔隙结构均具有较强的非均质性，分形维数越大，则页岩储层孔隙结构越复杂，对页岩气的吸附作用越强。同时，不同类型孔隙分形维数与TOC、矿物组分、孔隙结构参数等影响因素之间的相关性存在明显差异。分形维数DHg与矿物含量之间相关性较强，表明宏孔孔隙分形特征主要受矿物组分的控制；分形维数D1、D2与页岩TOC含量及孔隙比表面积参数之间呈现良好相关性，表明微孔和中孔孔隙非均质性的主要影响因素为有机碳的富集程度与有机质孔的发育规模。
结论 综合分析发现，硅质页岩具有高TOC含量、高脆性矿物含量、高分形维数的特征，证明硅质页岩为黔北地区五峰组—龙马溪组优质页岩岩相，其次为混合质页岩岩相；同时有机质含量越高，则该岩相在具备优质生烃条件的同时，也具备良好的开发开采条件。该研究可为指导黔北地区海相页岩储层有利开发层段的优选提供理论和实践支撑。
Abstract:This paper is the result of oil and gas exploration engineering.
Objective The heterogeneity is the inherent nature of shale. Study of the microheterogeneity of shale is of great significance for determining the enrichment mechanism of shale gas and the selection of high−quality reservoirs.
Methods This study investigated the marine shale of the Wufeng−Longmaxi Formation in the northern Guizhou area. Through XRD mineralogy, low−temperature N2 adsorption and high−pressure mercury intrusion (HPMI) analyses, we explored the macro and micro heterogeneity characteristics of pore structures of this formation.
Results The Wufeng−Longmaxi Formation shales in the northern Guizhou area are mainly of siliceous lithofacies, followed by mixed lithofacies and clayish lithofacies. The shales of different lithofacies exhibit large differences in total organic carbon (TOC) contents, mineral compositions, and pore structure characteristics. The FHH fractal model of N2 adsorption curves, and the porous fractal theory of HPMI methods, were utilized to calculate the low pressure fractal dimension D1 (0<P/P0<0.45) of N2 adsorption as 2.5351−2.6722, and the high pressure fractal dimension D2 (0.45<P/P0<1) as 2.8311−2.9113. Additionally, the fractal dimension DHg of HPMI was determined to be 2.0904−2.3736, indicating strong heterogeneity within the Wufeng−Longmaxi Formation shale pore structures. A larger fractal dimension corresponds to a more complex pore structure within the shale reservoir and stronger adsorption capacity for shale gas. Furthermore, there are notable differences between various types of pore fractal dimensions and TOC content, mineral composition, pore structure parameters, and other influencing factors. Specifically, it has been found that the fractal dimension DHg exhibits a strong correlation with different mineral contents, suggesting that macropore fractal characteristics are primarily influenced by mineral components. Moreover, there is a clear correlation between fractal dimensions D1 and D2 with TOC content and pore specific surface area parameters within the shale, indicating that micropore and mesopore heterogeneity are mainly influenced by organic carbon contents and development of organic pores.
Conclusions Generally, siliceous shale exhibits relatively high total organic carbon (TOC) contents, high proportions of brittle minerals, and high fractal dimensions. This confirms the siliceous shales are the primary high−quality lithofacies within the Wufeng−Longmaxi Formation in the northern Guizhou area, followed by the mixed lithofacies. Meanwhile, higher organic matter contents indicate not only more favorable conditions for hydrocarbon generation, but also better conditions for shale gas exploration and extraction. Our study offers theoretical and practical support for guiding the optimal selection of favorable reservoirs in marine shales in the northern Guizhou area.
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表 1 黔北五峰组—龙马溪组页岩有机地化与物性参数
Table 1. The organic geochemistry and physical property parameters of the Wufeng−Longmaxi Formation shales in the northern Guizhou area
井号有机地化参数 物性参数 TOC/% Ro 有机质类型 Φ/% K/mD AY−1 $ \frac{2.92 \sim 5.97}{4.67} $ $ \frac{2.00 \sim 2.07}{2.02} $ I $ \frac{0.13 \sim 1.46}{0.66} $ $ \frac{0.0004 \sim 0.3034}{0.0350} $ SD−1 $ \frac{0.33 \sim 6.14}{2.33} $ $ \frac{2.10 \sim 2.43}{2.32} $ I $ \frac{0.29 \sim 2.00}{1.05} $ $ \frac{0.0008 \sim 0.0697}{0.0204} $ BZ−1 $ \frac{0.29 \sim 4.95}{1.85} $ $ \frac{2.51 \sim 2.75}{2.65} $ I/II1 $ \frac{0.15 \sim 3.23}{1.29} $ $ \frac{0.0006 \sim 1.6900}{0.2400} $ 注： $ \frac{\mathrm{最}\mathrm{小}\mathrm{值} \sim \mathrm{最}\mathrm{大}\mathrm{值}}{\mathrm{平}\mathrm{均}\mathrm{值}} $ 。
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表 2 页岩实验样品基础信息
Table 2. Information of analyzed shale samples
编号 井号 深度/m 层位 岩相 USS−17 AY−1 2323.80 龙马溪组 极富有机质硅质页岩 RSS−11 BZ−1 1113.00 龙马溪组 富有机质硅质页岩 RMS−1 AY−1 2331.20 五峰组 富有机质混合质页岩 MSS−1 BZ−1 1118.25 五峰组 中等有机质硅质页岩 MMS−13 BZ−1 1112.80 龙马溪组 中等有机质混合质页岩 LSS−15 BZ−1 1112.00 龙马溪组 贫有机质硅质页岩 LMS−1 SD−1 1140.80 五峰组 贫有机质混合质页岩 LCS−25 BZ−1 1089.75 龙马溪组 贫有机质黏土质页岩
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表 3 黔北地区五峰组—龙马溪组不同岩相页岩N2吸附分形维数
Table 3. N2 adsorption fractal dimension of different lithofacies shales from the Wufeng−Longmaxi Formation in the northern Guizhou area
岩相不同孔径范围累积
孔体积/(cm3/g)不同孔径范围累积
比表面积/(m2/g)P/P0<0.5 P/P0>0.5 0~2 nm 2~50 nm >50 nm 0~2 nm 2~50 nm >50 nm 拟合系数R2 分形维数D1 拟合系数R2 分形维数D2 USS−17 0.0052 0.0170 0.0184 16.134 25.261 25.323 0.9931 2.6722 0.8987 2.9113 RSS−11 0.0050 0.1070 0.0191 15.888 24.910 24.995 0.9944 2.6488 0.9243 2.8884 RMS−1 0.0046 0.0146 0.0167 14.285 21.834 21.920 0.9936 2.6478 0.9482 2.8892 MSS−1 0.0031 0.0115 0.0133 9.4016 16.064 16.136 0.9981 2.6101 0.9523 2.8864 MMS−13 0.0016 0.0078 0.0095 4.7206 9.2929 9.3620 0.9988 2.6104 0.9640 2.8622 LSS−15 0.0012 0.0063 0.0078 3.3643 7.0746 7.1357 0.9992 2.5351 0.9705 2.8422 LMS−1 0.0015 0.0083 0.0106 4.2739 8.9615 9.0539 0.9995 2.5922 0.9761 2.8311 LCS−25 0.0034 0.0151 0.0181 10.196 18.794 18.920 0.9991 2.5968 0.9717 2.8539
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表 4 黔北地区五峰组—龙马溪组不同岩相页岩高压压汞分形维数
Table 4. High pressure mercury injection fractal dimensions of different lithofacies shales from the Wufeng Formation−Longmaxi Formation in the northern Guizhou area
岩相 孔隙度
/%渗透率
/mD孔体积
/(cm3/g)比表面积
/(m2/g)平均孔径
/nm最大进汞饱和度/% 拟合系数
/R2分形维数
/DHgUSS−17 1.6256 2.1975 0.0065 2.735 9.51 16.00 0.9942 2.2198 RSS−11 2.1780 0.1582 0.0087 3.133 11.10 15.95 0.9006 2.2978 RMS−1 1.6459 2.1254 0.0063 1.773 14.11 14.55 0.9196 2.1404 MSS−1 1.0814 1.2244 0.0041 1.112 14.59 14.22 0.9753 2.1230 MMS−13 2.7113 6.0540 0.0107 2.964 14.45 15.59 0.9656 2.0904 LSS−15 1.7096 0.5540 0.0064 0.768 33.27 13.99 0.9811 2.3736 LMS−1 3.1702 15.4231 0.0118 1.513 31.12 13.82 0.9966 2.1320 LCS−25 3.0875 2.8005 0.0115 4.249 10.78 13.81 0.9786 2.1037
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