Assessment of shale gas enrichment factors and delineation of favorable exploration zones in the first submember of the first member of the Longmaxi Formation, Tiangongtang area, southwestern Sichuan
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摘要: 川西南天宫堂地区龙马溪组一段页岩气储层具有显著的非均质性特征。为了探明影响川西南页岩气富集条件的因素，文章基于钻井岩芯、地球化学测试、矿物组分分析及测井资料，综合地质学、地球化学与测井解释等多学科研究方法，系统分析了该区页岩气富集条件及勘探潜力。结果表明，龙一段1亚段发育一套厚度25~60 m的连续稳定富有机质页岩，TOC含量1.0%~4.0%（平均3.19%），纵向上下部龙一段1亚段①~③小层TOC含量显著高于上部层段；Ro值2.58%~3.16%，表明处于过成熟阶段。矿物组成以石英（35%~45%）、黏土矿物（25%~35%）和碳酸盐矿物（15%~25%）为主，脆性指数大于60%，具备良好可压性。储集空间包括有机孔（孔径0.02~0.9 μm）、无机孔（粒内溶蚀孔、粒间孔等）及多尺度裂缝系统（构造缝、非构造缝和微裂缝），孔隙度3.0%~6.0%（平均4.2%），渗透率0.0003~0.2352 mD（2.96×10−7~2.32×10−4 μm2），纵向呈“顶底低渗、中部高渗”特征。构造保存条件分析表明，宽缓背斜和单斜构造区保存条件较好，而高陡断裂带附近气体散失严重；地层压力系数与产量呈正相关，当压力系数>1.4时单井日产量普遍突破20×104 m3/d（如Y203井36.26×104 m3/d）。通过建立综合评价指标体系，将天宫堂地区划分为Ⅰ类（TOC>2.4%、脆性指数>65%、孔隙度>4.5%、优质页岩厚度>35 m、埋深3000~4000 m、压力系数>1.4）和Ⅱ类有利区，为天宫堂地区页岩气勘探开发提供了科学依据。研究成果揭示了复杂构造背景下页岩气富集的主控因素，对川西南地区页岩气高效开发具有指导意义。Abstract:
Objective The shale gas reservoir in the First Member of the Longmaxi Formation in the Tiangongtang area of southwestern Sichuan exhibits significant heterogeneity. To investigate the factors influencing shale gas enrichment, this study systematically analyzed the enrichment conditions and exploration potential in southwestern Sichuan. Methods This was achieved through an interdisciplinary approach incorporating core analysis, geochemical analysis, mineralogical characterization, and well-logging interpretation. Results The first sub-member (Long 1-1) contains continuous organic-rich shale with a thickness of 25–60 m, featuring a TOC content of 1.0%–4.0% (average 3.19%). The lower intervals (Long 1-1-1 to Long 1-1-3) show significantly higher TOC values than the upper intervals. With Ro values ranging from 2.58% to 3.16%, the shale is in an overmature stage. The mineral composition is dominated by quartz (35%–45%),clay minerals (25%–35%), and carbonate minerals (15%–25%). Brittle mineral content exceeding 59% and brittleness indices of 60.3%–71% indicate favorable fracability. The reservoir space comprises organic pores (0.02–0.9 μm in diameter), inorganic pores (including intragranular dissolution pores and intergranular pores), and a multi-scale fracture system (including structural fractures, non-structural fractures, and microfractures). The porosity ranges from 3.0% to 6.0% (average 4.2%), while the permeability varies between 0.0003 and 0.2352 mD(2.96×10−7–2.32×10−4μm2), exhibiting a vertical permeability profile with low values at the top and bottom and high values in the middle. Analysis of structural preservation conditions reveals that gentle anticlines and monoclinal structures provide better preservation conditions, whereas areas near steep fault zones experience significant gas dissipation. Formation pressure coefficients show a positive correlation with production, and wells with a pressure coefficient exceeding 1.4 typically achieve daily production rates above 2.0×104 m3/d (e.g., Well Y203 at 3.626×104 m3/d). Conclusion Through establishing a comprehensive evaluation index system, the study area was subdivided into favorable zones of Class I (TOC > 2.4%, brittleness index > 65%, porosity > 4.5%, high-quality shale thickness > 35 m, burial depth 3000–4000 m, pressure coefficient > 1.4) and Class II, providing a scientific basis for shale gas exploration and development in the Tiangongtang area. [Significance] The research findings elucidate the key factors that control shale gas enrichment in complex structural settings and offer guidance for efficient shale gas development in southwestern Sichuan. -
图 1 天宫堂地区构造地质图及典型井龙一段1亚段地层柱状图
GR—自然伽马，TOC—总有机碳含量a—天宫堂地区构造地质图；b—典型井龙一段1亚段地层柱状图
Figure 1. Structural geological map of the Tiangongtang area and shale gas exploration-oriented stratigraphic column of the Long 1-1 submember of the Longmaxi Formation in typical wells
(a) Structural geological map of the Tiangongtang area; (b) Shale gas exploration-oriented stratigraphic column of the Long 1-1 submember of the Longmaxi Formation in typical wellsGR stands for natural gamma ray, and TOC stands for total organic carbon content.
图 2 天宫堂地区龙一段1亚段TOC垂向分布特征、镜质体反射率实验结果图
a—龙一段1亚段TOC垂向分布特征；b—镜质体反射率实验结果图
Figure 2. Experimental results of the vertical TOC distribution and vitrinite reflectance in the Long 1-1 submember of the Longmaxi Formation in the Tiangongtang area
(a) Experimental results of TOC vertical distribution; (b) Vitrinite reflectance histogram
图 3 天宫堂地区龙一段1亚段矿物组分含量分析图
a—Y202井龙一段1亚段全岩矿物组分含量；b—龙一段1亚段TOC含量与脆性矿物含量相关图（其中y代表脆性矿物含量，x代表TOC，R2代表决定系数）
Figure 3. Mineral abundance distribution in the Long 1-1 submember of the Longmaxi Formation, Tiangongtang area
(a) Whole-rock mineral composition of the Long 1-1 submember of Longmaxi Formation in Well Y202; (b) Correlation between TOC content and brittle mineral content in the Long 1-1 submember of the Longmaxi Formation (where the y-axis represents brittle minerals, the x-axis represents TOC，and the R² represents the coefficient of determination)
图 4 天宫堂地区龙一段1亚段脆性指数平面分布图
Figure 4. Spatial distribution of brittleness index in the Long 1-1 submember of the Longmaxi Formation, Tiangongtang region
图 5 天宫堂地区龙一段1亚段页岩孔隙扫描电镜图片
a—Y203井，3777.7 m，有机孔发育；b—Y206井，3874.2 m，椭圆状有机孔发育；c—Y206井，③小层，有机孔溶蚀发育；dY206井，3887.5 m，长石粒间孔发育；e—Y206井，3886.6 m，黏土矿物层间晶间孔发育；f—Y206井，3887.6 m，黄铁矿晶间孔发育；g—Y206井，④小层，粒间溶蚀孔发育；h—Y206井，3887.1 m，粒内溶蚀孔；i—Y206井，②小层，粒内溶蚀孔发育
Figure 5. Scanning electron microscope images of pore networks in the Long 1-1 submember of the Longmaxi Formation shales
(a) Well Y203, 3777.7 m, well-developed organic pores; (b) Well Y206, 3874.2 m, well-developed elliptical organic pores; (c) Well Y206, Long 1-1-3, dissolved organic pores; (d) Well Y206, 3887.5 m, intergranular pores in feldspar; (e) Well Y206, 3886.6 m, intercrystalline pores between clay mineral layers; (f) Well Y206, 3887.6 m, intercrystalline pores in pyrite; (g) Well Y206, Long 1-1-4, intergranular dissolution pores; (h) Well Y206, 3887.1 m, intragranular dissolution pores; (i) Well Y206, Long 1-1-2, intragranular dissolution pores
图 6 天宫堂地区龙马溪组龙一段1亚段页岩岩芯裂缝发育特征照片
a—Y208井，3830.88 m，直立剪切缝；b—Y207井，3830.81m，高角度剪切缝；c— Y208井，3830.17m，多条直立剪切缝；d—Y203井，3771.73m，直立剪切缝与高角度剪切缝相交；e—Y207井，3049.63m，滑脱缝；f—Y207井，3070.66m，滑脱缝；g—Y203井，3786.00m，压溶缝；h—Y209井，4453.2m，张性缝；i—Y207井，3038.23m，页理缝；j—Y209井，4452.98m，异常高压缝；k—Y206井，龙一段1亚段③小层，成岩收缩缝；l—Y206井，龙一段1亚段①小层，粒缘缝；m—Y206井，龙一段1亚段①小层，构造缝；n— Y207井，3049.62m，构造缝；o—Y207井，3069.69m，构造缝；p—Y207井，3049.62m，页理缝、方解石脉体
Figure 6. Photographs showing fracture characteristics in the Long 1-1 submember of the Longmaxi Formation, Tiangongtang Area
(a) Well Y208, 3830.88 m, vertical shear fracture; (b) Well Y207, 3830.81 m, high-angle shear fracture; (c) Well Y208, 3830.17 m, multiple vertical shear fractures; (d) Well Y203, 3771.73 m, intersection of vertical shear fracture and high-angle shear fracture; (e) Well Y207, 3049.63 m, detachment fracture; (f) Well Y207, 3070.66 m, detachment fracture; (g) Well Y203, 3786.00 m, pressure dissolution fracture; (h) Well Y209, 4453.2 m, tension fracture; (i) Well Y207, 3038.23 m, cleavage fracture; (j) Well Y209, 4452.98 m, abnormally high-pressure fracture; (k) Well Y206, Long 1-1-3 submember, diagenetic contraction fracture; (l) Well Y206, Long 1-1-1 submember, grain-edge fracture; (m) Well Y206, Long 1-1-1 submember, structural fracture; (n) Well Y207, 3049.62 m, structural fracture; (o) Well Y207, 3069.69 m, structural fracture; (p) Well Y207, 3049.62 m, cleavage fracture and calcite vein
图 7 天宫堂地区龙一段1亚段物性特征统计图
a—天宫堂地区龙一段1亚段孔隙度平面等值线图；b—天宫堂地区典型井龙一段1亚段渗透率柱状图
Figure 7. Statistical characterization of reservoir properties in the Long 1-1 submember of the Longmaxi Formation
(a) Porosity contour map of the Long 1-1 submember of the Longmaxi Formation in the Tiangongtang area; (b) Permeability histogram of the Long 1-1 submember of the Longmaxi Formation in a representative well from the Tiangongtang area
图 8 天宫堂地区构造样式剖面示意图（剖面位置见图1 A—A1）
Figure 8. Cross-section of structural patterns across the Tiangongtang area (Location of the section is shown in Fig. 1, line A–A1.)
图 9 天宫堂地区断层分级及及单井产气量分布图
Figure 9. Map of fault classification and gas production distribution of individual wells in the Tiangongtang area
图 10 天宫堂地区裂缝发育分级、龙一段1亚段埋深及压力系数分布平面图
a—天宫堂地区裂缝发育分级；b—龙一段1亚段埋深及压力系数分布平面图
Figure 10. Fracture development classification and plan view of burial depth and pressure coefficient distribution in the Long 1-1 submember of Longmaxi Formation
(a) Fracture development classification in the Tiangongtang area; (b) Plan view of burial depth and pressure coefficient distribution in the Long 1-1 submember of Longmaxi Formation
图 11 四川盆地及周缘龙马溪组页岩地层压力系数与产量的关系（长宁地区数据引自蔡景顺等，2024；丁山地区数据引自卢志远等，2021；焦石坝地区数据引自郭彤楼和张汉荣，2014）
Figure 11. Relationship between formation pressure coefficient and gas production in the Longmaxi Shale, Sichuan Basin (Data for the Changning area from Cai et al., 2024; data for the Dingshan area from Lu et al. , 2021; data for the Jiaoshiba area from Guo et al., 2014）
图 12 天宫堂地区龙一段1亚段页岩气有利区评价图
Figure 12. Evaluation of shale gas enrichment conditions and favorable zone distribution in the Long 1-1 submember of Longmaxi Formation，Tiangongtang area
表 1 天宫堂地区页岩气富集评价指标表
Table 1. Evaluation criteria for shale gas enrichment in the Tiangongtang area
参数类型 参数名称 优选指标 Ⅰ类区（好） Ⅱ类区（较好） Ⅲ类区（差） 源储条件 TOC含量/% >2.4 2.0~2.4 <2.0 脆性指数/% >65 55~65 45~55 孔隙度/% >4.5 4.0~4.5 2.0~4.0 优质页岩厚度/m >35 30~35 <30 保存条件 构造样式 宽缓背斜部位 斜坡部位 高陡背斜+大尺度断裂或向斜部位 断层级别 Ⅲ、Ⅳ级 Ⅱ级 Ⅰ级 裂缝发育程度 Ⅱ级裂缝发育区 Ⅲ级裂缝发育区 Ⅰ级裂缝发育区、裂缝欠发育区 距断裂距离 >6 3~6 <3 页岩埋深/m 3000~4000 2500~3500 >4000或<2500 地层压力系数 >1.4 1.4~1.2 <1.2 
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