应用多尺度微地震识别沙溪庙组致密砂岩水力压裂裂缝特征

丁嘉铭; 龚浩林; 赵学钦; 何雨江; 安钰洁; 何大祥; 杨荣义

doi:10.19509/j.cnki.dzkq.tb20250345

应用多尺度微地震识别沙溪庙组致密砂岩水力压裂裂缝特征

doi: 10.19509/j.cnki.dzkq.tb20250345

丁嘉铭^{1, 2,},
龚浩林^{2, 3},
赵学钦^1, ,,
何雨江²,
安钰洁¹,
何大祥¹,
杨荣义¹

西南科技大学环境与资源学院，四川绵阳 621010
中国地质科学院水文地质环境地质研究所，石家庄 050061
华北水利水电大学地球科学与工程学院，郑州 450045

基金项目: 国家重点研发计划（2021YFB1507302）

详细信息

作者简介:
丁嘉铭：E-mail：1556961217@qq.com

通讯作者:
E-mail：zxqch@sina.com

中图分类号: P631.4；TE357.1
计量
- 文章访问数: 158
- PDF下载量: 1
- 被引次数: 0
出版历程
- 收稿日期: 2025-07-23
- 录用日期: 2026-03-09
- 修回日期: 2026-01-07
- 网络出版日期: 2026-03-10

Characterization of hydraulic-fracturing-induced fractures in tight sandstone of Shaximiao Formation using multi-scale microseismic monitoring

DING Jiaming^{1, 2
,},
GONG Haolin^{2, 3},
ZHAO Xueqin^{1
, ,},
HE Yujiang²,
AN Yujie¹,
HE Daxiang¹,
YANG Rongyi¹

School of Environment and Resource, Southwest University of Science and Technology, Mianyang Sichuan 621010, China
Institute of Hydrogeology and Environmental Geology, Chinese Academy of Geological Sciences, Shijiazhuang 050061, China
School of Geosciences and Engineering, North China University of Water Resources and Electric Power, Zhengzhou 450045, China

More Information

Author Bio:
E-mail：1556961217@qq.com

Corresponding author: E-mail：zxqch@sina.com

摘要

摘要:
四川盆地沙溪庙组为重要致密砂岩气及地热潜力储层，储层强非均质性造成水力压裂裂缝演化识别困难。针对该套致密砂岩，识别水力压裂条件下裂缝发育特征，揭示岩体破裂机制，为储层压裂改造与增产提供理论支撑。开展致密砂岩真三轴大型水力压裂物理模拟实验，采集岩样声发射信号；结合研究区 6 个钻井平台共 12 口井的工程尺度水力压裂微地震监测资料，综合利用室内声发射、现场多尺度微地震事件时空分布开展裂缝特征解析。结果表明：①天然裂缝的复杂程度显著影响破裂特征。三轴应力作用下，天然裂缝形成应力薄弱面及尖端应力集中区；水力压裂产生的孔隙压力使裂缝面正应力衰减，诱发裂缝活动；同时，依托裂缝面的应力传导效应，孔隙压力在裂缝尖端持续累积并不断升高，当突破破裂阈值时驱动裂缝扩展，激发声发射信号。②裂缝分布特征由天然裂缝与人工缝网共同决定。天然裂缝较弱时，人工裂缝主导，呈现多尺度耦合的复杂破裂；水下分流河道砂体的走向和分布决定了裂缝初始扩展方向，裂缝倾向于沿砂体延展方向延伸，在砂体厚度大、物性好的区域更易形成和扩展，使破裂在平面上呈现与沉积相带相关的特征。③孔隙度对破裂特征具有重要影响。研究区沙溪庙组均为低孔低渗储层，低渗性增大微地震事件发生难度，且岩石各向异性对微裂纹网络的起裂压力、声发射特性和几何形态均有显著影响。脆性指数较低的层段微地震事件较少，压裂改造效果差；而测井解释显示好的压裂段事件密集，改造效果好。孔隙度升高会消耗更多压裂流体；孔隙度、脆性指数、地应力差异系数三者相互耦合，共同制约裂缝复杂程度与改造体积（SRV）。致密砂岩裂缝发育受多因素耦合机制控制：天然裂缝与人工缝网相互作用、沉积相带（砂体展布）的空间约束、地应力条件以及储层物性（低孔低渗、脆性指数、各向异性）的内在约束，共同形成了非均质、多尺度的网状破裂特征，其破裂机制为地质因素（脆性矿物、层理各向异性）与力学因素（应力差异、孔隙压力累积）共同作用下的张−剪复合破裂模式。
- 水力压裂 /
- 裂缝 /
- 非均质性 /
- 致密砂岩 /
- 地热储层 /
- 微地震
Abstract:
Objective
The Jurassic Shaximiao Formation in the Sichuan Basin represents a critical tight sandstone target for both tight gas production and enhanced geothermal system (EGS) exploitation. Strong reservoir heterogeneity complicates the characterization of hydraulic fracture evolution, restricting the optimization of fracturing treatments and the joint development of tight gas and geothermal energy. This study aims to characterize multi-scale fracture behaviors and reveal the underlying rock-rupture mechanisms of tight sandstone during hydraulic stimulation, providing theoretical support for reservoir stimulation and production enhancement in heterogeneous tight reservoirs.
Methods
Large-scale true-triaxial hydraulic fracturing experiments were performed on two groups of tight sandstone specimens (samples α and β). Acoustic emission (AE) signals were recorded to capture microcrack activity at laboratory scale. Field monitoring data collected from six drilling platforms and 12 wells within the study area were analyzed. Laboratory AE responses were integrated with the spatiotemporal distributions of field multi-scale microseismic events to characterize fracture propagation under coupled geological and mechanical controls.
Results
① The complexity of pre-existing natural fractures exerted a dominant control on rock-rupture behaviors. Under true-triaxial confining stress conditions, natural fractures acted as mechanical weak planes and produced localized stress concentrations at fracture tips. Pore pressure generated by hydraulic fracturing reduced the normal stress on fracture planes and activated natural fractures. Pore pressure was transmitted along the fracture planes and continuously accumulated at fracture tips. Once the local pressure exceeded the critical rupture threshold, the fractures propagated forward and generated detectable AE signals. ② Final fracture geometry was jointly governed by the interactions between pre-existing natural fractures and artificially induced hydraulic fracture networks. Where natural fractures were poorly developed, induced hydraulic fractures prevailed and formed complex multi-scale coupled fracture systems. The strike and distribution of subaqueous distributary-channel sand bodies determined the initial orientation of fracture propagation. Fractures preferentially extended along the orientation of sand-body deposition. Thick sand bodies with favorable reservoir properties promoted fracture initiation and propagation, yielding planar fracture patterns closely associated with sedimentary facies distributions. ③ Porosity was a vital parameter controlling fracturing responses. The Shaximiao Formation comprised typical low-porosity and low-permeability reservoirs. Its low matrix permeability increased the difficulty of triggering microseismic events. Rock anisotropy significantly influenced the initiation pressure, AE responses, and the geometric configuration of hydraulic microfracture networks. Intervals with low brittleness index produced sparse microseismic events and poor stimulation performance. By contrast, intervals with favorable logging interpretations showed dense microseismic clusters and effective reservoir stimulation. Reservoirs with higher porosity required larger volumes of fracturing fluid. Porosity, brittleness index, and in-situ stress-difference coefficient were mutually coupled and jointly controlled fracture complexity and stimulated reservoir volume (SRV).
Conclusion
Fracture development within the Shaximiao Formation tight sandstone is governed by a multi-factor coupling mechanism. The interactions among natural and hydraulic fractures, spatial restrictions imposed by sedimentary facies (sand-body distribution), geostress conditions, and intrinsic reservoir properties (low porosity and permeability, brittleness index, rock anisotropy) collectively generate heterogeneous multi-scale fracture networks. Fracture generation follows a mixed tension-shear rupture mode, jointly controlled by geological factors (brittle-mineral fraction, bedding-induced anisotropy) and mechanical factors (in-situ stress contrast and pore-pressure accumulation). The integration of laboratory physical simulation and field microseismic monitoring provides an effective approach for elucidating fracture evolution in highly heterogeneous tight sandstone reservoirs.
- hydraulic fracturing /
- fracture /
- heterogeneity /
- tight sandstone /
- geothermal reservoir /
- microseismic

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图 1 研究区沙溪庙组砂体预测分布图(a)及区域构造位置图(b)

Figure 1. Predicted sand-body distribution map (a) and regional structural location map (b) of Shaximiao Formation in study area

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图 2 真三轴水力压裂实验模型示意图（图 c 中井孔为观测探头外部引线）

Figure 2. Schematic diagrams of true-triaxial hydraulic fracturing experimental model

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图 3 致密砂岩样品 α (a1～d1)、β (a2～d2)声发射事件空间分布

图a1～c1，a2～c2中绿色线为注入井；蓝色三角形为观测探头；图d1中紫色、绿色区域为裂缝发育区域

Figure 3. Spatial distribution of acoustic emission events for tight sandstone samples α (a1-d1) and β (a2-d2)

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图 4 致密砂岩样品声发射实测波形(a, b)与褶积模型生成的波形(c)、频谱(d)

Figure 4. Measured acoustic emission waveforms of tight sandstone samples (a,b), and waveforms (c) and spectra (d) generated by convolutional model

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图 5 A 平台致密砂岩水力压裂微地震观测系统(a)及微地震事件定位整体效果图(b, c)

图5b，c中彩色散点代表微地震事件发生时序，对应图中色标；底图彩色云图表征砂体含气性，颜色越深含气性越好；绿色线条为井轨迹；图6b，7b，9b，9c含义相同

Figure 5. Microseismic monitoring system (a) and overall location effect maps of microseismic events (b, c) for hydraulic fracturing of tight sandstone at Platform A

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图 6 C平台致密砂岩水力压裂微地震观测系统(a)及微地震事件定位整体效果图(b)

Figure 6. Microseismic monitoring system (a) and overall location effect maps of microseismic events (b) for hydraulic fracturing of tight sandstone at Platform C

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图 7 F平台致密砂岩水力压裂微地震观测系统(a)及微地震事件定位整体效果图(b)

Figure 7. Microseismic monitoring system (a) and overall location effect maps of microseismic events (b) for hydraulic fracturing of tight sandstone at Platform F

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图 8 研究区多平台岩石孔隙度(a)、渗透率(b)、力学参数(c～f)与微地震事件数量关系图（B-1等为井编号）

Figure 8. Relationships among rock porosity (a), permeability (b), mechanical parameters (c～f), and numbers of microseismic event across multiple platforms in study area

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图 9 典型井 / 平台水力压裂微地震破裂特征（图a中不同颜色散点代表不同压裂井段）

Figure 9. Microseismic rupture characteristics of hydraulic fracturing for typical wells/platforms

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图 10 研究区沙溪庙组砂体储层孔隙度(a, c)、渗透率(b, d)频率直方图（N为样品数量）

Figure 10. Frequency histograms of porosity (a, c) and permeability (b, d) of sand-body reservoirs in Shaximiao Formation of study area

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表 1 各平台基础数据

Table 1. Basic data of each platform

平台	孔隙度Φ/%	最大主应力方向/(°)	平台	孔隙度Φ/%	最大主应力方向/(°)
A	9.3	80～90	E	9.8	130
B	8～11	100～120	F	10.4	100～110
C	11.5	132	G	9.6	108
D	13.2	110

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表 2 A平台井段水力压裂裂缝方位统计

Table 2. Statistics of fracture azimuths for hydraulic fracturing intervals of Platform A

A-1井			A-2 井
压裂井段编号	裂缝方向/(°)	事件数量/个	压裂井段编号	裂缝方向/(°)	事件数量/个
1	135	21	1	60	10
2	90	38	2	65	69
3	100	62	3	65	44
4	85	68	4	95	66
5	85	65	5	70	46
6	130	62	6	95	76
7	130	50	7	65	34
8	120	41	8	110	52
9	100	56	9	105	56
10	95	59	10	105	72
11	95	53	11	115	62
12	110	65	12	110	58
13	—	—	13	105	56
14	—	—	14	110	56
15	—	—	15	100	54
16	—	—	16	95	53
17	—	—	17	85	52
18	—	—	18	105	64
19	—	—	19	110	60

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表 3 C平台井段水力压裂裂缝方位统计

Table 3. Statistics of fracture azimuths for hydraulic fracturing intervals of Platform C

压裂井段编号	裂缝方向/(°)	事件数量/个	压裂井段编号	裂缝方向/(°)	事件数量/个
1	137	42	6	120	34
2	125	36	7	110	53
3	135	16	8	130	40
4	120	26	9	70	55
5	110	37

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表 4 F平台井段水力压裂裂缝方位统计

Table 4. Statistics of fracture azimuths for hydraulic fracturing intervals of Platform F

压裂井段编号	裂缝方向/(°)	事件数量/个	压裂井段编号	裂缝方向/(°)	事件数量/个
1	102	109	7	104	56
2	103	219	8	102	75
3	103	70	9	105	40
4	105	74	10	103	75
5	103	170	11	101	24
6	102	133

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