Geochemical Characteristics and Hydrocarbon Generation Potential of Source Rocks in the Shanxi and Taiyuan Formations, Qingyang Gas Field

To clarify the hydrocarbon-generation potential of deep source rocks in the Qingyang Gas Field, this study focuses on the Shanxi and Taiyuan Formation source rocks at burial depths of 4000–5000 m. Integrated organic geochemical analyses were conducted to investigate organic matter abundance, kerogen type, thermal maturity, hydrocarbon-generation conditions, and their significance for natural gas accumulation. The TOC values of the 12 valid mudstone samples range from 0.07% to 2.53%, with an average of 0.77%, indicating generally poor to fair organic matter abundance. Rock-Eval results show that S2 values range from 0.0681 to 6.2797 mg/g, with an average of 1.5946 mg/g, whereas S1 + S2 values range from 0.0948 to 6.9066 mg/g, with an average of 1.8582 mg/g, indicating generally limited Rock-Eval hydrocarbon-generating capacity, with local improvement. The kerogen assemblage is heterogeneous and is generally dominated by Type III humic kerogen, with subordinate Type II components and minor Type I components in some samples, indicating mixed organic-matter input but an overall gas-prone character. Tmax values range from 420 to 482 °C; however, because Tmax may be unreliable in samples with very low S2 values, thermal maturity was evaluated mainly using vitrinite reflectance and natural gas geochemical evidence. Ro values range from 2.03% to 2.22%, with an average of 2.11%, indicating that the source rocks have reached a high- to overmature stage. The natural gas is methane-rich, with an average methane content of 91.73% and an average heavy hydrocarbon content of only 0.16%, indicating a typical dry-gas composition. The carbon isotope values of methane and ethane are both negative, with δ13C1 values ranging from −35.59‰ to −20.65‰ and δ13C2 values ranging from −37.82‰ to −28.44‰, consistent with high-maturity coal-derived gas generated from humic organic matter. The formation water is mainly medium- to high-salinity CaCl2 type, indicating a relatively closed hydrologic environment favorable for natural gas preservation. Clay mineral assemblages dominated by kaolinite and illite provide supplementary evidence for depositional conditions, burial diagenesis, and fluid–rock interaction. Overall, although the Rock-Eval hydrocarbon-generating capacity of the Shanxi and Taiyuan Formation source rocks is generally limited, the Type III-dominated mixed kerogen, high- to overmature Ro values, methane-rich dry-gas composition, and carbon isotope characteristics collectively indicate that these source rocks experienced effective natural gas generation during geological evolution and are genetically related to the present deep natural gas accumulation. This study provides fundamental geochemical constraints for further integrated exploration and evaluation of the deep coal-measure gas system in the Qingyang Gas Field.