How organic matter types in source rocks influence reservoir diagenesis: Evidence recorded in carbonate cements

Abstract

Fluids generated from the source rocks containing various kerogen types at different thermal maturity stages control diagenetic processes and reservoir quality in adjacent sandstone reservoirs. This study focuses on the carbonate cements in the sandstones of the Lower Jurassic Yangxia Formation and the Ahe Formation in the Tarim Basin. The δ¹⁸O, δ¹³C, and ⁸⁷Sr/⁸⁶Sr data indicate that low temperature ferroan calcite and manganoan calcite-characterized by strongly negative δ¹³C values and enrichment in light rare earth elements (LREEs)-record CO₂ released during the thermal degradation of organic matter predominantly composed of Type III kerogen in coal bearing source rocks and of Type II kerogen in mudstone source rocks, respectively. High temperature ferroan calcite and manganoan calcite, which exhibit similarly strongly negative δ¹³C values and enrichment in middle rare earth elements (MREEs), record organic acids and CO₂ produced during the thermal decarboxylation of these same source rocks. The diagenetic fluid evolution sequence comprises early stage CO₂ from thermal degradation of both coal bearing and mudstone source rocks; mid stage organic acids and CO₂ from thermal decarboxylation of coal bearing source rocks; and late stage organic acids and CO₂ from thermal decarboxylation of mudstone source rocks. Fluids generated during the thermal degradation of mudstone and coal bearing source rocks precipitated extensive calcite cements, leading to reservoir densification. Clumped isotope thermometry indicates that the primary generation periods of late stage mudstone derived fluids coincided with the formation of effective fractures. Feldspar dissolution along these fractures produced an interconnected network of fractures and dissolution pores, significantly enhancing reservoir quality in the Ahe Formation.

Keywords

Coal bearing source rocks / Mudstone source rocks / Diagenetic fluid evolution / Different organic matter types / Jurassic / Triam Basin

CRediT authorship contribution statement

Nianmin Zan: Writing - original draft, Methodology, Investiga-tion, Conceptualization. Kelai Xi: Investigation, Project administra-tion, Writing - review & editing. Yingchang Cao: Supervision, Project administration. Haijun Yang: Validation, Supervision. Wenfang Yuan: Supervision. Tian Yang: Writing - review & edit-ing, Validation, Investigation. Guoding Yu: Supervision, Methodol-ogy, Investigation. Hao Wang: Investigation, Formal analysis, Data curation, Methodology. Yifan Zhang: Investigation. Zhicheng Cui: Methodology, Investigation. Guanghui Yuan: Data curation, Investigation.

Declaration of competing interest

The authors declare that they have no known competing finan-cial interests or personal relationships that could have appeared to influence the work reported in this paper.

Acknowledgements

This work was supported by the National Natural Science Foun-dation of China (Grant No. 42488101), the Taishan Scholars Pro-gram (Grant No. tsqn202306125), the Open Research Fund of the State Key Laboratory of Deep Oil and Gas (Grant No. SKLDOG2024-KFZD-02), and the PetroChina Major Research Pro-gram on Deep Petroleum Systems in the Tarim Basin (Grant No. ZD2019-183-01-003). We thank the Tarim Oilfield Company, Pet-roChina, for providing the fundamental data used in this study. We are also grateful to the editors and anonymous reviewers for their constructive comments and insightful suggestions, which greatly improved the quality of the manuscript.

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