四川盆地东北部上三叠统须家河组致密砂岩气来源与运移特征

黄彦庆; 卢晓林; 刘君龙; 马健飞; 李吉通; 杨俊; 张磊; 乔大伟

doi:10.19509/j.cnki.dzkq.tb20250391

四川盆地东北部上三叠统须家河组致密砂岩气来源与运移特征

doi: 10.19509/j.cnki.dzkq.tb20250391

中国石化石油勘探开发研究院，北京 100083

基金项目: 中国石油化工股份有限公司科技开发部项目（P23130；P23201）

详细信息

通讯作者:
E-mail：huangyq.syky@sinopec.con

中图分类号: P593；P629
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- 文章访问数: 274
- PDF下载量: 16
- 被引次数: 0
出版历程
- 收稿日期: 2025-08-27
- 录用日期: 2025-12-15
- 修回日期: 2025-10-23
- 网络出版日期: 2025-12-15

Source and migration characteristics of tight sandstone gas in Upper Triassic Xujiahe Formation, northeastern Sichuan Basin

Petroleum Exploration and Production Research Institute, SINOPEC, Beijing 100083, China

More Information

Corresponding author: E-mail：huangyq.syky@sinopec.con

摘要

摘要:
目的
川东北须家河组已发现多个致密砂岩气藏，但目前对天然气的成因、混源端元贡献比例尚存争议，天然气横向、垂向运移机制尚不明确。本文旨在厘清该区须家河组致密砂岩天然气的来源与混源特征，解析天然气差异运移机制，深化该区成藏机理认识，为川东北须家河组致密砂岩气高效勘探提供理论支撑。
方法
基于研究区构造断裂、沉积等地质背景，依托 508 件烃源岩样品、2244 组储层物性以及大量天然气地球化学分析数据，综合利用天然气组分、碳-氢稳定同位素、地层压力等测试资料，借助多套气源鉴别图版开展气源判识，并采用二元混源模型定量计算混源比例，结合储层致密演化史剖析天然气运移规律。
结果
元坝须三、须四段以及阆中、巴中须四段天然气以须家河组自生煤型气为主，烃源岩厚度≥30 m 是致密砂岩天然气富集的关键条件；元坝须二段为自生煤型气与雷口坡组油型气的混合气，海相油型气混入比例介于 3%～22%。通南巴背斜、通江凹陷须家河组天然气为吴家坪组油型气与陆相煤型气的混合气，通南巴背斜油型气混入比例 50%～60%，较通江凹陷（20%～30%）高出约 20 个百分点，重烃碳同位素更轻，碳同位素倒转更为显著。混源差异受控于须家河组内部煤系烃源岩厚度差异。
结论
受砂体分隔、储层先期致密化制约，天然气不存在远距离横向运移；垂向上存在两类运移模式：断层欠发育且须三段泥岩盖层厚度较大时，天然气难以发生大规模垂向穿层运移；断裂系统发育时，断缝体作为高效输导通道，促使不同层位天然气发生混合，断裂-隔层配置关系是控制该区海相油气向上混充陆相储层的核心要素。
- 天然气来源 /
- 油气运移 /
- 地球化学指标 /
- 致密砂岩 /
- 须家河组 /
- 川东北
Abstract:
Objective
Multiple large- and medium-sized tight sandstone gas reservoirs have been discovered in the Upper Triassic Xujiahe Formation of the northeastern Sichuan Basin. Nevertheless, existing studies remain controversial regarding gas-source types, quantitative contributions of mixed-gas end-members, and lateral and vertical hydrocarbon migration mechanisms in this area. This study aims to clarify the sources and mixing characteristics of tight sandstone gases within the Xujiahe Formation, elucidate the differential migration mechanisms of natural gas, deepen the understanding of hydrocarbon accumulation mechanisms, and provide theoretical support for the efficient exploration of tight sandstone gas in the Xujiahe Formation of the northeastern Sichuan Basin.
Methods
On the basis of regional tectonic-fault frameworks and sedimentary evolutionary backgrounds, this study integrated analytical datasets including 508 source-rock samples, 2 244 groups of reservoir physical-property measurements, and abundant natural-gas geochemical tests. It comprehensively utilized multiple geochemical proxies such as natural gas compositions, stable carbon and hydrogen isotopes, and formation pressure data, and used multiple gas-source discrimination diagrams to identify gas sources. Additionally, a two-end-member mixing model was employed to quantitatively calculate the mixing proportions of mixed-source gases, and the natural gas migration patterns were analyzed in combination with reservoir densification evolutionary history.
Results
Natural gases from the third and fourth members of Xujiahe Formation (T₃x³ and T₃x⁴ members) in the Yuanba area and the T₃x⁴ member in Langzhong and Bazhong were predominantly in-situ coal-derived gases generated by coal-bearing source rocks of the Xujiahe Formation. A source rock thickness threshold of ≥30 m for high-quality source rocks was a critical prerequisite for natural gas enrichment in tight sandstone intervals. Gases within the T₃x² member of Yuanba represented mixtures of in-situ coal-derived gas and oil-derived gas from the Middle Triassic Leikoupo Formation, with the proportion of marine-sourced oil-type gas ranging from 3% to 22%. Gases accumulated in the Tongnanba Anticline and Tongjiang Depression were mixtures of oil-derived gas from the Upper Permian Wujiaping Formation and in-situ coal-derived gas. The contribution of oil-derived gas reached 50%-60% in the Tongnanba Anticline and 20%-30% in the Tongjiang Depression, showing a difference of approximately 20 percentage points. Consequently, the carbon-isotope values of heavy hydrocarbons were lower, and carbon-isotope inversion phenomena were more prominent in the Tongnanba Anticline. Such discrepancy in mixing proportions was mainly governed by thickness variations of in-situ coal-bearing source rocks of the Xujiahe Formation.
Conclusion
Restricted by sand-body compartmentalization and the early densification of reservoir sandstones prior to major hydrocarbon expulsion, natural gas has experienced no long-distance lateral migration in the study area. Two distinct vertical-migration models are summarized. When faults are poorly developed and the mudstone caprock in the T₃x³ member is sufficiently thick, large-scale cross-strata vertical migration of natural gas is inhibited. In contrast, when fault systems are well-developed, fault-fracture zones serve as efficient migration conduits and facilitate natural gas mixing across different stratigraphic members. This study highlights that the fault–barrier assemblage serves as the dominant controlling factor for upward cross-formational charging of marine-sourced hydrocarbons into continental tight reservoirs.
- source of natural gas /
- petroleum migration /
- geochemical indicators /
- tight sandstone /
- Xujiahe Formation /
- northeastern Sichuan Basin

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图 1 四川盆地东北部须家河组地质特征和气藏分布图

a. 一级构造单元（蓝色字体）和气藏分布（地图为须二段沉积相图）；b. 须家河组地层柱状图；c. 过元坝−巴中−通南巴背斜地质剖面。GR为自然伽马；AC为声波时差；CNL为补偿中子；DEM为密度；∈-O₂为寒武系-中奥陶统；O₃-S为上奥陶统-志留系；P-T₁为二叠系−下三叠统；T₂为中三叠统；T₃为上三叠统；J₁z+J₂q为下侏罗统自流井组+中侏罗统凉高山组；J₂s为中侏罗统沙溪庙组；J₃为上侏罗统；K为白垩系；下同

Figure 1. Geological characteristics and distribution of gas reservoirs in Xujiahe Formation, northeastern Sichuan Basin

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图 2 四川盆地东北部须家河组烷烃气甲烷、乙烷和丙烷碳同位素特征

Figure 2. δ¹³C characteristics of CH₄, C₂H₆, and C₃H₈ of alkane gases in Xujiahe Formation, northeastern Sichuan Basin

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图 3 四川盆地东北部须家河组天然气δD_CH4-δ¹³ C₁相关关系

Figure 3. Correlation between δD_CH4 and δ¹³ C₁ of natural gases in Xujiahe Formation, northeastern Sichuan Basin

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图 4 四川盆地东北部须家河组天然气成因“Bernard”图版(a)和 δ ¹³C₁- δ ¹³C₂- δ ¹³C₃烷烃气鉴别图版(b)

①. 煤成气区；②. 油型气区；③. 混合气引起的同位素倒转；④煤成气和（或）油型气区

Figure 4. Bernard diagram (a) and δ¹³C₁–δ¹³C₂–δ¹³C₃ alkane gas identification diagram (b) of natural gas genesis in Xujiahe Formation, northeastern Sichuan Basin

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图 5 四川盆地东北部须家河组天然气δ¹³C₃-δ¹³C₂交会图(a)和δ¹³C₂-δ¹³C₁交会图(b)

①a. 成熟油型气；①b. 成熟油型气−煤成气混合气；①c. 成熟煤成气；②a. 高成熟油型气；②b. 高成熟油型气−煤成气混合气；②c. 高成熟煤成气；③a. 过熟油型气；③b. 过熟油型气−煤成气混合气；③c. 过熟煤成气

Figure 5. Crossplots of δ¹³C₃–δ¹³C₂ (a) and δ¹³C₂–δ¹³C₁ (b) of natural gases in Xujiahe Formation, northeastern Sichuan Basin

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图 6 四川盆地东北部元坝地区天然气δ¹³C₂-δ¹³C₁交会图

Figure 6. Crossplot of δ¹³C₂–δ¹³C₁ of natural gases in Yuanba area, northeastern Sichuan Basin

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图 7 四川盆地东北部通南巴地区须家河组优质烃源岩厚度等值线图

Figure 7. Thickness isopach maps of high-quality source rocks of Xujiahe Formation in Tongnanba area, northeastern Sichuan Basin

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图 8 四川盆地阆中、元坝和巴中须四段天然气甲烷和乙烷碳同位素对比

Figure 8. Comparison of δ¹³C₁ and δ¹³C₂ of natural gases from T₃x⁴ member in Langzhong, Yuanba, and Bazhong areas, Sichuan Basin

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图 9 过元坝−巴中−通江凹陷须家河组沉积微相连井剖面（位置见图1a；RD为深侧向电阻率）

Figure 9. Correlation profile of sedimentary microfacies of Xujiahe Formation in Yuanba, Bazhong, and Tongjiang Depression

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图 10 四川盆地东北部须四段主要砂岩类型致密化过程

T为三叠系；J为侏罗系；E为古近系；N-Q为新近系-第四系

Figure 10. Densification process of main sandstone types in T₃x⁴ member, northeastern Sichuan Basin

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图 11 四川盆地元坝地区相同钻井须二段和须三段−须四段天然气干燥系数C₁/C₁₊和湿度系数C₂/C₁₊对比

Figure 11. Dryness (C₁/C₁₊) and wetness (C₂/C₁₊) coefficients of natural gases of T₃x² and T₃x³-T₃x⁴ members from same wells in Yuanba area, Sichuan Basin

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图 12 四川盆地通南巴背斜相同钻井须二段和须四段天然气C₁/（C₁-C₅）和压力系数对比

Figure 12. Comparison of C₁/(C₁-C₅) and pressure coefficients of natural gases between T₃x² and T₃x⁴ members from same wells in Tongnanba Anticline, Sichuan Basin

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图 13 四川盆地元坝和巴中地区须家河组天然气纵向运移特征

Figure 13. Vertical migration characteristics of natural gases in Xujiahe Formation, Yuanba, and Bazhong areas, Sichuan Basin

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图 14 四川盆地通南巴背斜和通江凹陷须家河组天然气运移特征

Figure 14. Vertical migration characteristics of natural gases in Xujiahe Formation, Tongnanba Anticline and Tongjiang Depression, Sichuan Basin

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表 1 川东北地区主要烃源岩地球化学特征统计

Table 1. Statistics of geochemical characteristics of major source rocks in northeastern Sichuan Basin

层段	地区	w（TOC）/%			R_o/%
层段	地区	最小值	最大值	平均值	最小值	最大值	平均值
须五段	巴中	0.37	7.03	1.98	1.77	1.92	1.86
须五段	通南巴	0.43	61.43	14.86	1.6	2.48	2.33
须三段	阆中	0.8	7.78	4.22	1.28	1.4	1.33
	元坝	0.51	33.36	3.12	1.17	2	1.72
	巴中	0.75	8.76	2.7	1.82	2.08	1.93
	通南巴	0.49	39.67	5.1	1.65	2.46	2.25
须二段	阆中	0.32	4.33	1.14	1.39	1.68	1.54
	元坝	0.32	11.5	2.87	1.71	2.32	1.92
	通南巴	0.5	5.76	1.4	1.66	2.78	2.28
雷口坡组	元坝	0.5	0.8	0.65	1.72	2.2	2
吴家坪组	通南巴	0.14	5.4	2.19	1.6	2.8	2.42

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表 2 四川盆地东北部不同地区须家河组各层段烷烃气地球化学特征

Table 2. Geochemical characteristics of alkane gases in different members of Xujiahe Formation across different areas of northeastern Sichuan Basin

气藏名称	CH₄	C₂H₆	C₃H₈	C₄H₁₀	CO₂	N₂	干燥系数
气藏名称	组分含量/%						干燥系数
阆中须四段	88.63	6.69	1.36	0.25	1.7	1.14	0.914
元坝须四段	95.35	1.99	0.27	0.11	0.85	1.35	0.976
元坝须三段	95.81	0.99	0.09	0.01	1.8	1.19	0.988
元坝须二段	97.2	1.06	0.11	0.02	0.81	0.75	0.988
巴中须四段	97.37	1.29	0.14	0.03	0.49	0.57	0.985
通南巴背斜须四段	97.96	0.56	0.05	0.27	0.15	0.83	0.984
通南巴背斜须二段	97.64	0.75	0.08	0	0.34	1.07	0.992
通江凹陷须四段	96.41	0.39	0.01	0	1.28	1.83	0.996
通江凹陷须二段	98.18	0.37	0.03	0	0.39	1.04	0.996
普光及其东侧须四段	94.81	2	0.27	0.07	0.71	0.49	0.976
普光及其东侧须三段	97.2	1.2	0.06	0.01	0.45	0.94	0.987

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