Abstract: Based on shale core, logging, and seismic data from the Cambrian Qiongzhusi Formation in the Sichuan Basin, the study used methods including thin-section analysis, scanning electron microscopy, organic and inorganic geochemistry, and adsorption–desorption tests. Combined with a comparative analysis of the Mancos shale in the San Juan Basin, North America, it systematically investigated the formation conditions and main enrichment controlling factors of new-type shale gas reservoirs. The results showed that: (1) The Qiongzhusi Formation in the Jingyan area was dominated by organic-bearing shale with total organic carbon (TOC) content < 1%. It developed sedimentary facies at the shallow-water gentle slope zone, which was favorable for the development of carrier beds. (2) The new-type shale gas reservoir exhibited the characteristics of "two lows, one large, and four highs": low TOC content, low Poisson's ratio, large pore size, high felsic content, high inorganic poro-sity, high gas content, and high Young's modulus. (3) Driven by source-reservoir pressure differences, natural gas generated from deep-water source rocks migrated and accumulated in the shallow-water organic-bearing shale carrier beds with more favorable pore structures. (4) The new-type carrier bed shale gas reservoir was different from the organic-rich continuous shale gas reservoir of the Longmaxi Formation, and exhibited a dual enrichment mechanism of source and reservoir controlled by sedimentation and diagenesis, and enrichment controlled by migration and preservation. The research results clarify the enrichment mechanism of new-type shale gas and provide a geological basis for the selection optimization of favorable exploration targets.