四川盆地嘉陵江组天然气成藏主控因素与勘探方向

李龙龙; 陶国亮; 杜崇娇; 彭金宁; 罗开平; 陈拥锋; 左宗鑫; 蒋小琼; 汪远征; 陆永德

doi:10.11781/sysydz2024051050

四川盆地嘉陵江组天然气成藏主控因素与勘探方向

doi: 10.11781/sysydz2024051050

李龙龙^{1, 2,},
陶国亮^{1, 2},
杜崇娇^{1, 2},
彭金宁^{1, 2},
罗开平^{1, 2},
陈拥锋^{1, 2},
左宗鑫^{1, 2},
蒋小琼^{1, 2},
汪远征^{1, 2},
陆永德^{1, 2}

1.
中国石化石油勘探开发研究院无锡石油地质研究所, 江苏无锡 214126
2.
中国石化油气成藏重点实验室, 江苏无锡 214126

基金项目:

中国石化重大项目 P23229

中国石化科技部项目 P21042-5

详细信息

作者简介:
李龙龙(1994—)，男，硕士，助理研究员，从事油气地质研究。E-mail: lilongl.syky@sinopec.com

中图分类号: TE122.3
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出版历程
- 收稿日期: 2024-03-16
- 修回日期: 2024-08-30
- 刊出日期: 2024-09-28

Main controlling factors and exploration direction of gas reservoir in Jialingjiang Formation, Sichuan Basin

LI Longlong^{1, 2
,},
TAO Guoliang^{1, 2},
DU Chongjiao^{1, 2},
PENG Jinning^{1, 2},
LUO Kaiping^{1, 2},
CHEN Yongfeng^{1, 2},
ZUO Zongxin^{1, 2},
JIANG Xiaoqiong^{1, 2},
WANG Yuanzheng^{1, 2},
LU Yongde^{1, 2}

1.
Wuxi Research Institute of Petroleum Geology, SINOPEC, Wuxi, Jiangsu 214126, China
2.
Key Laboratory of Petroleum Accumulation Mechanisms, SINOPEC, Wuxi, Jiangsu 214126, China

摘要

摘要: 嘉陵江组是四川盆地天然气勘探的传统层系，近年来在川北、川西南等地区连续获得发现，但盆地内仍有大面积的勘探空白区，亟需深化对该层系天然气成藏规律的认识，明确成藏主控因素，进而指出未来的勘探方向。利用天然气地球化学等分析测试，结合构造恢复、盆地模拟等技术，以气源分析为基础，以典型气藏解剖为核心，结合对嘉陵江组成藏条件认识，通过对成藏过程的分析探讨了成藏主控因素，并建立了成藏模式。四川盆地嘉陵江组天然气主要来自下部的原油裂解气，嘉陵江组具有多套优质烃源岩供烃、发育多类型碳酸盐岩储层、通源断裂有效沟通气源的良好成藏条件，主生油期古构造、调整期构造及通源断裂、有利储层类型是嘉陵江组天然气成藏的主控因素；嘉陵江组具有“多源形成古油藏—古油藏裂解供气—通源断裂输导—晚期调整成藏”的成藏模式。基于此指出，分布于川西、川北等地区山前带，主生油期、气藏调整成藏期均处于相对高部位，发育通源断裂、保存条件较好的构造—岩性复合气藏是勘探的首选方向；分布于川东高陡构造带构造稳定区及向斜区的孔隙型岩性气藏是未来的主要勘探方向。
- 碳酸盐岩气藏 /
- 成藏模式 /
- 天然气勘探方向 /
- 嘉陵江组 /
- 三叠系 /
- 四川盆地
Abstract: The Jialingjiang Formation is a traditional stratum for natural gas exploration in the Sichuan Basin, and in recent years it has been continuously discovered in northern and southwestern Sichuan, but there are still large areas of exploration blanks in the basin, which urgently needs to deepen the understanding of the natural gas accumulation law of this formation, clarify the main controlling factors of the accumulation, and then point out the exploration direction in the future. By using natural gas geochemistry and other analytical tests, combined with structural restoration, basin simulation and other technologies, based on gas source analysis, with typical gas reservoir anatomy as the core, combined with the understanding of the reservoir conditions of the Jialingjiang Formation, the main controlling factors of reservoir formation were discussed through the analysis of reservoir formation process, and the reservoir formation model was established. The results show that the natural gas of the Jialingjiang Formation is mainly cracked gas from crude oil in the lower part. The Jialingjiang Formation has good reservoir formation conditions such as multiple sets of high-quality source rocks supplying hydrocarbons, developing multiple types of carbonate reservoirs, and source-connected faults that effectively communicate gas sources. The paleostructures of the main oil generation period, the structures of the adjustment period, the source-connected faults, and the favorable reservoir types are the main controlling factors of the natural gas accumulation in the Jialingjiang Formation in the Sichuan Basin. The Jialingjiang Formation has an accumulation model of "multi-source charging to form ancient oil reservoirs, ancient oil reservoir cracking and supply gas, source-connected faults transport, and late adjustment accumulation". Based on this, it is proposed that the structural and litholo-gical composite gas reservoirs distributed in the piedmont belts of western and northern Sichuan, which are at relatively high positions during the main oil generation period and gas reservoir adjustment and accumulation period, have developed source-connecting faults, and have good preservation conditions, are the preferred exploration directions. The porous lithological gas reservoirs distributed in the structurally stable areas and syncline areas of the high and steep structural belts in eastern Sichuan are the main exploration directions in the future.
- carbonate reservoir /
- accumulation pattern /
- exploration direction for natural gas /
- Jialingjiang Formation /
- Triassic /
- Sichuan Basin
注释:

利益冲突声明/Conflict of Interests

作者陶国亮是本刊编委会成员、编辑部成员及主办单位员工，未参与本文的编审流程或决策；作者李龙龙、杜崇娇、彭金宁、罗开平、陈拥锋、左宗鑫、蒋小琼、汪远征、陆永德是本刊主办单位员工，均未参与本文的同行评审或决策。

Author TAO Guoliang is a member of the editorial office, an Editorial Board Member and an employee of the sponsor of this journal. He did not take part in editorial/review procedures or decision making of this article. Authors LI Longlong, DU Chongjiao, PENG Jinning, LUO Kaiping, CHEN Yongfeng, ZUO Zongxin, JIANG Xiaoqiong, WANG Yuanzheng, and LU Yongde are employees of the sponsor of this journal. They did not take part in peer review or decision making of this article.

作者贡献/Authors’Contributions

李龙龙负责论文编写和修改；陶国亮参与论文设计与写作；杜崇娇负责沉积相编图与图件校对；彭金宁参与论文设计与成藏研究；罗开平负责论文指导与修改；陈拥锋参与论文写作与文字校对；左宗鑫参与断裂控藏作用研究；蒋小琼、汪远征参与储层研究；陆永德参与图件编制与样品采集。所有作者均阅读并同意最终稿件的提交。

The manuscript was drafted and revised by LI Longlong. TAO Guoliang participated in paper design and writing. DU Chongjiao was responsible for sedimentary facies mapping and map proofreading. PENG Jinning participated in paper design and reservoir formation research. LUO Kaiping guided and revised the manuscript. CHEN Yongfeng participated in paper writing and text proofreading. ZUO Zongxin participated in fault reservoir control research. JIANG Xiaoqiong and WANG Yuanzheng were involved in reservoir research. LU Yongde participated in map compilation and sample collection. All authors have read the last version of the paper and consented to its submission.

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图 1 四川盆地嘉陵江组地质概况

a.嘉嘉陵江组二段沉积相平面分布及主要气田、钻井；b.嘉陵江组地层综合柱状图(川西南J1井)。

Figure 1. Geological settings of Jialingjiang Formation, Sichuan Basin

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图 2 四川盆地嘉陵江组天然气成因类型与气源判识图

a.ln(C₁/C₂)与ln(C₂/C₃)相关图；b.碳同位素分布序列图；c.天然气成因类型划分(图版据文献[17])；d.天然气烃源分区

Figure 2. Genetic types and source identification of natural gas in Jialingjiang Formation, Sichuan Basin

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图 3 四川盆地主要烃源岩层热演化史(以川北为例)

Figure 3. Thermal evolution history of major hydrocarbon source rock layers, Sichuan Basin (taking northern Sichuan as an example)

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图 4 四川盆地三叠纪末期二叠系顶古构造及流体运移方向

Figure 4. Paleotectonics and direction of fluid transport at the top of Permian at the end of Triassic, Sichuan Basin

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图 5 四川盆地现今嘉陵江组顶面构造与气田分布

Figure 5. Present day top surface structure and gas field distribution, Jialingjiang Formation, Sichuan Basin

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图 6 四川盆地通南巴构造特征及主要钻井

底图为嘉陵江组底部现今构造。

Figure 6. Characteristics of Tongnanba structure and main drilling wells in Sichuan Basin

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图 7 四川盆地嘉陵江组气藏动态成藏过程对比

Figure 7. Comparison of dynamic reservoir-forming process of Jialingjiang Formation, Sichuan Basin

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图 8 四川盆地嘉陵江组天然气成藏模式

剖面位置为图 1a中AB线。
图件据郭旭升等2023年“全国油气系统理论学术研讨会”报告修改。

Figure 8. Accumulation pattern of natural gas of Jialingjiang Formation, Sichuan Basin

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表 1 四川盆地嘉陵江组天然气组成对比

Table 1. Comparison of natural gas composition of Jialingjiang Formation, Sichuan Basin

地区	气田	烃类气体含量/%				干燥系数	非烃气体含量/%				组分碳同位素δ¹³C/‰
地区	气田	CH₄	C₂H₆	C₃H₈	C₄₊	干燥系数	H₂	N₂	CO₂	H₂S	CH₄	C₂H₆	C₃H₈
川北	河坝场	97.379	0.212	0.019	0	0.998	0.010	2.700	0.719	0.742	-27.500	-26.400	-24.300
川东	大池干井	98.168	0.256	0.008	0.037	0.997	0.033	0.914	0.113	0.483	-30.528	-35.036	-34.000
川东	东溪	97.970	0.448	0.063	0.513	0.990	0	0.845	0.055	0.583	-30.430	-31.930
川东	福成寨	97.877	0.675	0.156	0.400	0.988	0.001	0.734	0.018	0.234	-33.485	-34.348	-28.854
川东	高峰场	96.978	0.245	0	0	0.997	0.004	0.524	0.412	1.817	-29.900	-34.200	-34.900
川东	黄草峡	98.015	0.684	0.132	0.218	0.989	0.155	0.611	0.096	0.265	-32.653	-36.051	-33.134
川东	建南	98.150	0.210	0.010	0.001	0.998	0	0.430	1.150	0.020	-32.400	-36.400
川东	石油沟	97.480	0.550	0.073	0.649	0.987	0.010	1.153	0.287	0.377	-31.460	-30.615
川东	双龙	98.488	0.476	0.089	0.036	0.994	0.011	0.585	0.068	0.217	-32.200	-30.700	-23.200
川东	双庙	97.970	0.350	0.010	0	0.996	0	1.500	0.120	0	-31.800	-31.700
川东	铁山	98.130	0.200	0.010	0.214	0.996	0	0.460	0	0.610	-31.670	-33.190
川东	卧龙河	94.558	1.002	0.399	0.213	0.985	0.161	0.811	0.396	3.576	-33.154	-29.326	-24.662
川东	五百梯	98.189	0.403	0.066	0.114	0.994	0	0.986	0	0.211	-32.400	-33.200	-27.700
川东	云安场	96.789	0.175	0	0	0.998	0.006	1.376	0.257	1.360	-28.400	-32.733	-30.700
川东	寨沟	95.828	0.313	0.017	0	0.997	0	0.654	0	3.162	-32.100	-32.100	-34.500
川东	张家场	98.738	0.358	0.038	0.219	0.994	0.017	0.545	0.160	0.096	-32.725	-34.680	-37.200
川南	二里场	96.340	0.660	0.135	0.010	0.992	0	2.550	0.080	0.035	-31.400	-33.550	-27.400
川南	合江	98.073	0.440	0.053	0	0.995	0	0.947	0.063	0.393	-29.833	-34.033	-29.500
川南	井研	93.770	2.460	0.763	0.830	0.959	0.020	1.607	0.493	0
川南	庙高寺	97.074	0.768	0.170	0.044	0.990	0	1.472	0.114	0.352	-31.300	-33.660	-29.825
川南	纳溪	93.743	2.533	0.903	0.623	0.958	0	1.203	0.110	0.010	-34.800	-32.767	-29.433
川南	威远	55.833	0.157	0	0.023	0.997	0	3.580	9.593	30.743	0
川中	磨溪	97.585	0.387	0.115	0	0.995	0.002	1.340	0.487	0.029	-33.400	-32.200
注：川北河坝场气田为自测数据，其他数据来自参考文献[4-5, 8, 12-16]；表中数据均为平均值。

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表 2 四川盆地北部主要烃源岩层热演化关键时期

Table 2. Critical moments of thermal evolution of major hydrocarbon rock layers, Sichuan Basin

烃源层	热演化关键时期/Ma
烃源层	R_o=0.5%	R_o=1.2%	R_o=2.0%	R_o=3.0%
筇竹寺组	435	228	181	165
五峰组—龙马溪组	245	182	165	154
上二叠统	234	167	158	134

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表 3 四川盆地嘉陵江组主要储层类型特征

Table 3. Characteristics of major reservoir types in Jialingjiang Formation, Sichuan Basin

储层类型	储层岩性	主要发育层段	沉积相带	储集空间类型	储层物性特征	储层厚度特征	典型代表气田	主要分布区域
孔隙型	粒屑白云岩、鲕粒灰岩、细晶白云岩	嘉二段	台内浅滩	晶间、晶内溶孔	孔隙度1%~8%，孔渗具有相关性	层状分布，但横向非均质性强	磨溪	川中地区
裂缝—孔隙复合型	细晶白云岩、鲕粒灰岩、生屑(砂屑) 灰岩及白云岩	嘉一、二、四、五段	云坪、台内浅滩	晶间溶孔及微裂缝	孔隙度1%~5%，渗透率受裂缝控制	层状分布，非均质性强，受断裂控制	井研、麻柳场、河坝场、宝元	川西南、川东南、川北等地区
裂缝型	砂屑灰岩、微粉晶白云岩	嘉二—五段	云坪、台内浅滩、灰坪等	裂缝、少量溶孔	孔隙度与渗透率相关性较差	受断裂控制明显	石油沟、卧龙河	川东、川南等构造较为复杂区域的背斜核部

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表 4 四川盆地通南巴构造嘉陵江组二段主要钻井基本情况对比

Table 4. Comparison of basic conditions of major drilling wells in second member of Jialingjiang Formation in Tongnanba tectonic zone, Sichuan Basin

井号	钻探位置	嘉二段沉积环境	储层发育情况	通源断裂是否发育	解释结论	嘉二段测试情况
仁和1	仁和场构造	蒸发膏云坪	基本不发育储层	发育NW向通源断裂	干层	无
河坝1	河坝场构造	台内浅滩	发育裂缝—孔隙型储层	发育NW向通源断裂	气层	6.06×10⁴ m³/d
母家1	母家梁构造	台内浅滩—膏云坪	孔隙—裂缝型储层，孔隙度0.58%~1.77%	发育NW向通源断裂	差气层	0.417 5×10⁴ m³/d
马2	马路背构造	台内浅滩—膏云坪	储层较发育，孔隙度2%~8%	发育NWW向通源断裂	二类气层	微量气，高压水层
新黑池1	黑池梁高点	台内浅滩—膏云坪	发育砂屑白云岩储层	发育近EW向断裂	水层	微量气

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