深层页岩层理缝成因、预测及对压力的影响

寇冬琴; 尹帅; 梁晨; 王濡岳

doi:10.19509/j.cnki.dzkq.tb202607014

深层页岩层理缝成因、预测及对压力的影响

doi: 10.19509/j.cnki.dzkq.tb202607014

寇冬琴^{1a, 1b,},
尹帅^{1a, 1b, 1c, 2, ,},
梁晨³,
王濡岳⁴

1a.
西安石油大学：地球科学与工程学院
1b.
西安石油大学：陕西省油气成藏地质学重点实验室
1c.
西安石油大学：复杂难动用油气勘探开发教育部重点实验室，西安 710065
2.
成都理工大学油气藏地质及开发工程全国重点实验室，成都 610059
3.
中国石油长庆油田分公司勘探开发研究院，西安 710018
4.
中国石化石油勘探开发研究院，北京 102206

基金项目: 国家自然科学基金(42302167）；油气藏地质及开发工程全国重点实验室（成都理工大学）开放基金资助项目(CDUT-PLC2025004)；中国石油科技创新基金项目(2024DQ02-0109)

详细信息

作者简介:
寇冬琴：E-mail：1760617753@qq.com

通讯作者:
E-mail：speedysys@163.com

计量
- 文章访问数: 78
- PDF下载量: 4
- 被引次数: 0
出版历程
- 收稿日期: 2026-07-06
- 录用日期: 2026-08-26
- 修回日期: 2026-08-24
- 网络出版日期: 2026-08-28

Genesis, prediction, and pressure influence of bedding fractures in deep shale

KOU Dongqin^{1a, 1b
,},
YIN Shuai^{1a, 1b, 1c, 2
, ,},
LIANG Chen³,
WANG Ruyue⁴

1a.
School of Earth Science and Engineering
1b.
Shaanxi Key Laboratory of Petroleum Accumulation Geology
1c.
Key Laboratory of Exploration and Development of Complex and Difficult-to-Produce Oil & Gas Reservoirs, Ministry of Education, Xi'an Petroleum University, Xi’an 710065, China
2.
State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Chengdu University of Technology, Chengdu 610059, China
3.
Research Institute of Exploration & Development, PetroChina Changqing Oilfield Company, Xi’an 710018, China
4.
Sinopec Petroleum Exploration and Production Research Institute, Beijing 102206, China

More Information

Author Bio:
E-mail：1760617753@qq.com

Corresponding author: E-mail：speedysys@163.com

摘要

摘要:
目的
页岩油储层中层理缝的发育程度直接影响储层的储集性能和渗流能力，然而层理缝的成因机制复杂，与地层压力的关系及生产过程中对压力降低的影响不明，制约了页岩甜点优选和开发方案优化。
方法
本文基于中国某东部断陷湖盆多口超压页岩水平井的测井资料与岩心观察，利用ΔlgR法预测总有机碳含量，采用R/S重标极差法计算测井参数二阶导数以指示裂缝响应，建立层理缝密度预测指标Q，并采用经有机质校正的Eaton法预测地层压力系数，进而研究了层理缝与地层压力及生产动态之间的关系。
结果
结果表明：①通过层理缝敏感性分析，优选自然伽马（GR）、声波时差（AC）、补偿中子（CNL）、密度（DEN）、电阻率（RT）及总有机碳含量（TOC）作为敏感参数；预测层理缝密度Q与岩心观察层理缝密度呈良好正相关，平均预测吻合率达80%；②层理缝形成成因复杂，受岩性、有机质含量及纹层结构共同控制，生烃增压为层间弱面开启提供重要动力，沿长英质向黏土质纹层过渡界面优先发育，而碳酸盐岩纹层因胶结致密和重结晶作用较强、结构相对致密，层理缝发育程度相对较低；③层理缝密度与地层压力系数呈显著但中等偏弱的正向统计趋势，当层理缝密度超过15条/m时，地层压力系数普遍高于1.4，且增幅趋于平缓；④在主要地质—工程条件总体相近的两口井对比下，层理缝发育程度与开发初期压力动态和产油表现出一定对应关系，层理缝较发育井的压力衰减相对较缓；⑤层理缝通过增加储集空间和流体通道、促进复杂裂缝网络形成以及改善裂缝系统抗闭合能力，影响地层能量释放与生产动态。
结论
本文揭示了层理缝发育的复杂成因机制，明确了层理缝发育程度对压力保存和页岩油动用具有一定影响，为陆相页岩油甜点优选和压裂设计优化提供了定量依据。
- 陆相页岩 /
- 层理缝密度 /
- 测井定量预测 /
- 压力维持水平
Abstract:
Objective
The degree of bedding fracture development in shale oil reservoirs directly affects reservoir storage capacity and fluid flow capability. However, the genetic mechanisms of these bedding fractures are complex, and their relationships with formation pressure and their effects on production-induced pressure drawdown remain unclear, hindering the optimization of sweet-spot identification and development strategies.
Methods
Using well-log data and core observations from multiple overpressured shale horizontal wells in a faulted lacustrine basin in eastern China, this study applied the ΔlgR method to estimate total organic carbon (TOC) content, employed rescaled range (R/S) analysis to compute second derivatives of logging parameters for indicating fracture responses, established a prediction indicator Q for bedding fracture density, and adopted the organic-matter-corrected Eaton method to derive the formation pressure coefficient. The relationships between bedding fractures, formation pressure, and production performance were then examined.
Results
The results showed that: (1) sensitivity analysis of bedding fractures identified gamma ray (GR), acoustic transit time (AC), compensated neutron (CNL), density (DEN), resistivity (RT), and TOC content as sensitive parameters. The predicted indicator Q showed a good positive correlation with core-observed bedding fracture density, yielding an average prediction agreement rate of 80%. (2) The development of bedding fractures was complex and governed by the interplay of lithology, organic matter content, and lamina texture. Hydrocarbon-generation overpressure provided an important driving force for opening weak interlayer planes. Bedding fractures preferentially developed along transitional interfaces from felsic to clay-rich laminae, while carbonate laminae exhibited relatively fewer fractures because of stronger cementation, more intense recrystallization, and a relatively compact structure. (3) A statistically significant but moderately weak positive correlation was observed between bedding fracture density and the formation pressure coefficient. When bedding fracture density exceeded 15 fractures/m, the formation pressure coefficient was typically above 1.4, and its rate of increase tended to level off. (4) In two wells with largely analogous geological and engineering settings, a discernible correspondence was observed between the degree of bedding fracture development and the early-stage pressure behavior and oil production. Wells with more abundant fractures exhibited a relatively slower decline in pressure. (5) By enhancing storage space and fluid pathways, facilitating the formation of complex fracture networks, and improving resistance to fracture closure under confining stress, bedding fractures played a role in modulating reservoir energy dissipation and production performance.
Conclusion
This study elucidates the complex genetic mechanisms of bedding fracture development, establishes the influence of bedding fracture intensity on pressure maintenance and shale oil recovery, and provides a quantitative basis for sweet-spot selection and fracturing design optimization in continental shale oil reservoirs.
- continental shale /
- bedding fracture density /
- quantitative prediction from well logs /
- pressure maintenance level

HTML全文

图 1 不同盆地页岩层理缝岩心及显微观察照片

a. 研究区B1井，3621.5～3622，3622.5～3623 m；b. 研究区L2井，3986～3986.5，3987～3987.5 m；c. 研究区L2井，3988.5～3989，3989.5～3990 m；d. 研究区L2井，3996.5～3997，3997.5～3998 m；e. 玛湖凹陷风城组，J174井，3354.09 m，层理缝发生弯曲和尖灭（据文献[5]）；f. 五峰山龙马溪组，X3井，2650.59 m处水平顺层裂缝组合（据文献[27]）；g. 五峰山龙马溪组，X2井，2847.47 m处沿矿物颗粒边缘绕行的层理缝（据文献[27]；h. 苏北盆地溱潼凹陷阜宁组，QY1井，3861.11 m（据文献[28]）

Figure 1. Core and microscopic observation photographs of bedding fractures in shales from different basins

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图 2 研究区F1井主力页岩层段测井曲线、岩相类型及层理缝密度分布

GR 为自然伽马；SP 为自然电位；DEN 为密度测井；AC 为声波时差；CNL 为补偿中子测井；RT 为地层真电阻率；下同

Figure 2. Well logs, lithofacies types, and bedding fracture density distribution in main shale interval of Well F1 in study area

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图 3 研究区不同岩性页岩对应的层理缝密度分布直方图

Figure 3. Histogram of bedding fracture density distribution for different shale lithologies in study area

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图 4 研究区主力页岩层段层理缝测井参数敏感性交汇分析图

Figure 4. Crossplot analysis of logging parameter sensitivity for bedding fractures in main shale interval of study area

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图 5 研究区N5井页岩层段测井参数二阶导数计算结果

Figure 5. Second-derivative calculation results of logging parameters in shale interval of Well N5 in study area

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图 6 研究区页岩层段层理缝密度预测指标Q与实际观察层理缝密度关系

Figure 6. Relationship between bedding fracture density prediction indicator Q and observed bedding fracture density in shale interval of study area

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图 7 研究区F2井主力页岩层段层理缝密度预测结果

Figure 7. Prediction results of bedding fracture density in main shale interval of Well F2 in study area

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图 8 研究区页岩层段w（TOC）与层理缝密度相关图

Figure 8. Correlation between bedding fracture density and TOC in shale interval of study area

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图 9 页岩矿物组成对层理缝分布的3种控制模式图（据文献[18]）

Figure 9. Three control models of mineral composition on bedding fracture distribution in shales

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图 10 页岩层理缝成因演化模式图

Figure 10. Genetic evolution model of bedding fractures in shales

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图 11 研究区页岩层段有机质校正后Eaton指数h与AC相关图

Figure 11. Correlation between organic-matter-corrected Eaton exponent h and AC in shale interval of study area

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图 12 研究区N1井TOC及校正前后AC值的纵向分布特征图

Figure 12. Vertical distribution characteristics of TOC and AC values before and after correction in Well N1 in study area

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图 13 研究区页岩层段层理缝密度与压力系数关系图

Figure 13. Relationship between bedding fracture density and pressure coefficient in shale interval of study area

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图 14 研究区L1、B1井层理缝发育程度与生产压降的关系

Figure 14. Relationship between bedding fracture development degree and production pressure drawdown in Wells L1 and B1 in study area

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图 15 页岩层理缝支撑剂受力机制（据文献[41]）

Figure 15. Force mechanism of proppant in bedding fractures in shales

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图 16 页岩层理缝发育程度对生产压降影响的模式图

Figure 16. Schematic diagram of influence of bedding fracture development degree on production pressure drawdown in shales

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表 1 研究区不同纹层类型泥页岩矿物类型、结构及层理缝发育特征对比

Table 1. Comparison of mineral types, textures, and bedding fracture development characteristics of mudstones/shales with different lamina types in study area

特征参数	长英质纹层	黏土质纹层	碳酸盐纹层
主要矿物组成	石英、长石（φ_B 30%～45%）	黏土矿物（φ_B 60%～80%）	方解石、白云石
单层厚度/mm	0.01～8.00	0.01～5.00	0.01～3.00
主要孔隙类型	粒间孔、粒缘缝	晶间孔、晶间缝、有机质孔	溶蚀孔
孔隙孔径/μm	0.2～5	30.03～1	<0.3
层理缝密度/(条·m⁻¹)	约30（最高）	[12, 30)（较高）	<12（低）
孔缝连通性	优（有效连通率>80%）	中等（有效连通率～68%）	差（连通率<30%）
纹层连续性	连续−断续水平层状	连续薄层状	连续水平−波状

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表 2 研究区主力页岩层段各测井参数与层理缝密度的Pearson相关分析结果

Table 2. Pearson correlation analysis results between logging parameters and bedding fracture density in main shale interval of study area

测井参数	Pearson系数	检验概率	决定系数R²	置信区间
RT	0.238	0.124	0.057	[−0.067，0.503]
AC	0.223	0.151	0.05	[−0.083，0.490]
GR	−0.174	0.265	0.03	[−0.451，0.133]
w（TOC）	0.116	0.457	0.014	[−0.191，0.403]
CNL	−0.036	0.821	0.001	[−0.332，0.268]
DEN	−0.028	0.861	0.001	[−0.325，0.275]

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表 3 研究区主力页岩层段各测井参数与层理缝密度的灰色关联分析结果

Table 3. Grey relational analysis results between logging parameters and bedding fracture density in main shale interval of study area

排序	参数	最小绝对差	最大绝对差	平均绝对差	灰色关联度
1	AC	0.0068	0.5337	0.1918	0.7294
2	CNL	0.0050	0.6483	0.2174	0.7160
3	TOC	0.0057	0.7739	0.2251	0.7059
4	RT	0.0052	0.8846	0.2577	0.6810
5	DEN	0.0168	0.6708	0.2607	0.6685
6	GR	0.0002	0.8696	0.2803	0.6565

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