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microseismic methods
Prediction of Overburden Failure on the Working Face Using Self-Formed Roadway Mining Technology without Coal Pillars Based on Microseismic Monitoring: A Case Study
Seismic Monitoring near Ithaca, New York, Reveals Nonuniform Distribution of Microseismicity in an Intraplate Region
Integrated Simulation for Microseismic Fracture Networks with Automatic History Matching in Tight Oil Development: A Field Case from Block Y2 in Ordos Basin, China
Change of Natural Oscillation Frequencies of Buildings and Structures Depending on External Factors
P – S Travel‐Time Detection and Hypocenter Location of Low‐SNR Events Using Polarization in the Time–Frequency Domain
Integration of deep-learning fault segmentation, horizontal transverse isotropy analysis, and ambient microseismic methods to enhance fracture prediction in the Crisol Anticline, Colombia
Distributed acoustic sensing microseismic reflection imaging for hydraulic fracture and fault lineament characterization
Mechanisms for Microseismicity Occurrence Due to CO 2 Injection at Decatur, Illinois: A Coupled Multiphase Flow and Geomechanics Perspective
Seismic Magnitude Estimation Using Low‐Frequency Strain Amplitudes Recorded by DAS Arrays at Far‐Field Distances
Data-Driven Dynamic Inversion Method for Complex Fractures in Unconventional Reservoirs
Real-time passive seismic monitoring using DAS — Today's solutions and remaining challenges
Detection of microseismic events in continuous DAS data using convolutional neural networks
Advances in hydraulic fracture characterization via borehole microseismic and strain monitoring
Introduction to this special section: Microseismic monitoring
Abstract Improved understanding of hydraulic fractures is needed to optimize petroleum well drilling and completion strategies. Yet direct observations of hydraulic fractures are rarely made, and reliance is placed on indirect methods such as microseismic monitoring, interference tests, fibre optic detection of fracturing in adjacent wells and numerical modelling. While these techniques provide useful insights, verification of such studies is commonly lacking; core taken through stimulated intervals offers a robust option for verification. We make the case that core can provide complementary information at a different scale from other data types. Core from a slant well adjacent to two stimulated wells at the Hydraulic Fracture Test Site (HFTS1) in West Texas revealed 375 hydraulic fractures, striking 090°±20°, subparallel to present-day S Hmax . There are more hydraulic fractures than expected, and clustering across a range of scales from approximately 1 cm to 50 m. The largest cluster correlates with high microseismic event density. Diversion, bifurcation, and segmentation structures may account for the large number of fractures observed and the orientation spread. Reactivation of sealed natural fractures and bedding planes is relatively uncommon. Proppant sand packs and patches occur in a few locations, particularly where hydraulic fractures are complex.