Among the shale gas fields in the Sichuan Basin, the
Fuling, Changning,
and Weiyuan fields with Wufeng Formation-Longmaxi Formation as the
target formation have made significant contributions to the shale
gas industry in China. However, several other areas in the basin which
have witnessed gas flow from wildcat wells have not realized commercial
development. In this study, we analyzed the Wufeng Formation–Longmaxi
Formation shale gas reservoirs from the perspective of a coupling
mechanism of source and seal, by considering three aspects, including
the characteristics of source and cap rocks, evolution history of
the source rock–reservoir caprock, and the differential enrichment
of shale gas. The results indicate the following: (1) The occurrence
of the regional caprock (Triassic gypsum-salt) determines the distribution
of overpressured and normally pressured shale gas reservoirs. In addition,
the erosion of the caprock and its integrity control the gas content
and cost-efficiency of the normally pressured shale gas reservoirs.
(2) For the overpressured reservoirs, the thickness of the siliceous
and carbonate-bearing siliceous shales in the WF2-LM4 graptolite zone
determines the gas content and producibility of the lower shale gas
layer. In terms of the upper layers, the structural form plays a critical
role. Generally, gas reservoirs in the upper layers that occupy the
higher part of an anticline are more favorable, whereas those in a
syncline or monocline exhibit poor productivity. (3) For the normally
pressured shale gas reservoirs with poor caprock integrity, the enrichment
and the commercial value of the gas depend mostly on the thickness
of the WF2-LM4 graptolite zone. Therefore, we conclude that the areas
near the core of synclines are more favorable and structurally stable,
with relatively high formation pressure and moderate burial depths.
Our findings can improve sweet spot prediction and offer valuable
guidance for shale gas development in China and globally.