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Minerals
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Natural and Induced Diagenesis in Clastic Rock
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Natural and Induced Diagenesis in Clastic Rock

A special issue of Minerals (ISSN 2075-163X). This special issue belongs to the section "Mineral Geochemistry and Geochronology".

Deadline for manuscript submissions: 30 April 2026 | Viewed by 1983

Special Issue Editors

Dr. Meiyan Fu

E-Mail Website
Guest Editor
College of Energy, Chengdu University of Technology, Chengdu 610059, China
Interests: diagenesis; water–rock reaction simulation; reservoir evaluation
Prof. Dr. Jon Gluyas

E-Mail Website
Guest Editor
Department of Earth Sciences, Durham University, Durham DH1 3LE, UK
Interests: sediment diagenesis and reservoir quality prediction; carbon capture and geostorage; geothermal energy; natural hydrogen and helium exploration; human-induced seismicity
Dr. Dong Wu

E-Mail Website
Guest Editor
College of Energy, Chengdu University of Technology, Chengdu 610059, China
Interests: sedimentology; sequence stratigraphy; reservoir geology

Special Issue Information

Dear Colleagues,

The process whereby unconsolidated sediment becomes indurated rock is called diagenesis. It includes compaction, resulting from burial loading along with precipitation of new mineral species from the connate water and, in many instances, dissolution of deposited grains and/or earlier precipitated cements. Diagenesis may begin immediately after deposition and continue episodically until throughout its geological history. The process of near-surface weathering is commonly treated separately.

Although diagenesis is a natural process, subsurface interventions by humans can accidentally or intentionally induce reactions leading to compaction, mineral precipitation, and/or mineral dissolution. Such induced processes have been known about for decades, but only now, as humanity increases its exploitation of the subsurface for geoenergy and storage or disposal of fluids, is interest growing.

The fluid/rock and fluid/fluid reactions that characterize diagenesis most commonly involve water but can also include petroleum, carbon dioxide, and other non-aqueous fluids, such as nitrogen, hydrogen sulfide, and hydrogen.

Diagenesis changes the properties of the rock in which it acts. The changes include but are not limited to the rock’s acoustic impedance, strength, unit thickness, porosity, permeability, grain surfaces, wettability, and bound water. These changes in turn affect rocks response to seismic signals, measurements made during well logging and quality of the reservoir in terms of its storage capacity, producibility and injectivity. Together and separately, these property changes will affect the technical and commercial viability of exploiting the sandstone for its contained fluids and fluid storage potential.

The Special Issue invites submissions, including original scientific research on clastic diagenesis and water–rock reaction mechanisms from well-known and/or new regions around the world. This Special Issue focuses on the following: (1) mineral–fluid reaction mechanism of clastic rocks (including sandstone and shale); (2) geochemistry and chronology of diagenetic minerals in clastic rocks (including sandstone and shale); and (3) the application of comprehensive diagenesis on the reservoir prediction for clastic rock.

Dr. Meiyan Fu
Prof. Dr. Jon Gluyas
Dr. Dong Wu
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Minerals is an international peer-reviewed open access monthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2400 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • diagenetic fluid
  • multi-mineral phase interaction
  • dissolution mechanism
  • organic–inorganic interaction
  • diagenetic facies

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Published Papers (4 papers)

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Research

22 pages, 24589 KB  
Article
Genesis of Conventional Reservoirs in Braided Fluvial Tight Sandstones: Evidence from the He 1 Member, Upper Paleozoic, Southern Ordos Basin, China
by Xiaoqi Ding, Yi Wang, Jingyun Gao, Feilan Lin, Xiang Zhang, Shujie Han and Ying Zhu
Minerals 2025, 15(11), 1104; https://doi.org/10.3390/min15111104 - 23 Oct 2025
Viewed by 153
Abstract
The He 1 Member of the Xiashihezi Formation (Upper Paleozoic) in the Ordos Basin represents typical tight sandstones (Φ < 10%, k < 0.5 mD). However, against the extensive tight sandstone background of the He 1 Member in the southern basin, conventional reservoirs [...] Read more.
The He 1 Member of the Xiashihezi Formation (Upper Paleozoic) in the Ordos Basin represents typical tight sandstones (Φ < 10%, k < 0.5 mD). However, against the extensive tight sandstone background of the He 1 Member in the southern basin, conventional reservoirs (Φ > 12%, K > 1 mD) occur locally. Elucidating the genetic mechanism of these conventional reservoirs is critical for evaluating gas reservoirs in this region. Based on core descriptions and systematic sampling from cored wells, reservoir types are classified according to pore types and porosity in sandstones. Depositional microfacies, petrology, and diagenesis of each reservoir type are then investigated to ultimately elucidate the genetic mechanism of conventional reservoirs. Results demonstrate that intense compaction and quartz overgrowths are the primary controls on the development of the He 1 Member tight sandstones. Alteration of volcanic lithic fragments and volcanic ash matrix generated abundant intragranular dissolution pores and micropores within the matrix, while simultaneously producing substantial illite–smectite mixed-layer clays and chlorite clays. Additionally, this process supplied silica for quartz overgrowths. Moderate amounts of chlorite coatings can inhibit quartz overgrowths, thereby preserving residual intergranular porosity. Conventional reservoirs exhibit low lithic fragment content (<20 vol.%) and are characterized by a porosity assemblage of both intergranular (avg. 2.3%) and intragranular dissolution pores (avg. 6.5%). Their formation requires weak compaction, intense dissolution, and weak quartz overgrowths. These reservoirs develop within high-energy transverse bars that are sealed by overlying and underlying mudstones. Such transverse bars constitute closed intrastratal-diagenetic systems with restricted mass transfer during burial. This study provides a compelling example of diagenetic heterogeneity induced by variations in sandstone architecture within fluvial successions. Full article
(This article belongs to the Special Issue Natural and Induced Diagenesis in Clastic Rock)
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18 pages, 11049 KB  
Article
Pore Diagenetic Evolution and Its Coupling Relationship with Natural Gas Accumulation in Tight Sandstone Reservoirs of the Second Member of the Xujiahe Formation, Xinchang Area, Western Sichuan
by Zongze Li, Sibing Liu, Youyi Bi, Junqi Li, Meizhou Deng, Jinxi Wang and Hengyi Gao
Minerals 2025, 15(10), 1052; https://doi.org/10.3390/min15101052 - 3 Oct 2025
Viewed by 331
Abstract
By employing thin section analysis, scanning electron microscopy (SEM), homogenization temperatures of fluid inclusions, and carbon–oxygen isotope analysis of carbonate cements, this study conducted a temporal-quantitative investigation into the porosity evolution of relatively high-quality reservoirs in the Second Member of the Xujiahe Formation [...] Read more.
By employing thin section analysis, scanning electron microscopy (SEM), homogenization temperatures of fluid inclusions, and carbon–oxygen isotope analysis of carbonate cements, this study conducted a temporal-quantitative investigation into the porosity evolution of relatively high-quality reservoirs in the Second Member of the Xujiahe Formation (Xu-2 Member) in the Xinchang area of western Sichuan. The analysis focused on quantifying porosity loss due to compaction, cementation, and porosity enhancement from dissolution. Results indicate that compaction exerted the most significant impact on reservoir quality in the Xu-2 Member, causing over 70% of total porosity loss. Cementation processes, including carbonate cements, silica cements, and authigenic chlorite, further degraded reservoir properties. Authigenic chlorite precipitated earliest at burial depths of 600–800 m, while authigenic quartz and carbonate cements persistently affected the reservoir at depths of 2000–5000 m, reducing porosity by at least 10% (up to 21%). Dissolution processes initiated at approximately 3500 m burial depth, generating secondary porosity of ≥2%, with a maximum increase of 16%. Integrating these findings with the natural gas accumulation history, the coupling relationship between pore evolution and gas accumulation was elucidated. The study reveals that reservoir tightness in the Xu-2 Member developed at burial depths of 4050–5300 m, with large-scale gas accumulation predominantly occurring prior to reservoir densification. The findings provide critical guidance for identifying high-quality tight sandstone reservoirs and optimizing exploration targets in the Xu-2 Member of the Xinchang area, Western Sichuan Basin, thereby supporting efficient development of regional tight gas resources. Full article
(This article belongs to the Special Issue Natural and Induced Diagenesis in Clastic Rock)
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21 pages, 62661 KB  
Article
Petrography, Fluid Inclusions and Isotopic Analysis of Ordovician Carbonate Reservoirs in the Central Ordos Basin, NW China
by Xiaoli Wu, Ping Wang, Haijian Jiang, Hexin Huang, Tong Chen, Lei Chen, Dongxing Wang and Junnian Chen
Minerals 2025, 15(8), 860; https://doi.org/10.3390/min15080860 - 15 Aug 2025
Viewed by 588
Abstract
Deep carbonate reservoirs have garnered significant attention and demonstrated great potential for oil and gas exploration in recent years. The Majiagou Formation in the Ordos Basin has received much attention for its deep oil and gas deposits recently. However, the issue of fluid [...] Read more.
Deep carbonate reservoirs have garnered significant attention and demonstrated great potential for oil and gas exploration in recent years. The Majiagou Formation in the Ordos Basin has received much attention for its deep oil and gas deposits recently. However, the issue of fluid evolution within the great depth has been overlooked, and the relationship between fluid flow and the gas accumulation process remains unclear. This paper aims to explore the fluid evolution and its relationship with the gas accumulation, which poses a challenge for further petroleum exploration. To achieve this, petrological studies on dolomite samples were carried out and four types of secondary cements were identified: early gypsum-moldic pore-filling calcite, late gypsum-moldic pore-filling calcite, dissolution pore-filling calcite and fracture-filling calcite. Subsequently, an interdisciplinary approach that integrates petrography observation, microthermometry, laser Raman analysis of fluid inclusions, and carbon and oxygen isotope tests on these types of cements is employed to elucidate the fluid flow evolution. These investigations revealed that four different stages of inorganic fluid activity were coeval with two stages of organic fluid activity. The two stages of organic fluid flows were significantly important for petroleum accumulation. In the late Triassic to early Jurassic, there was small-scale liquid oil accumulation, which was associated with the second stage of fluids. In the early Cretaceous, there was large-scale gas accumulation, which was associated with the fourth stage of fluids. This research is crucial for understanding the fluid flow process and its relationship with hydrocarbon accumulation in deeply buried carbonate formations. Full article
(This article belongs to the Special Issue Natural and Induced Diagenesis in Clastic Rock)
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24 pages, 9668 KB  
Article
Study on Reservoir Characteristics, the Tightening Process and Reservoir Quality in Source-to-Sink Systems in the Xu-2 Member of the Xujiahe Formation in the Western Sichuan Basin, Western China
by Dong Wu, Yu Yu, Liangbiao Lin, Sibing Liu, Binjiang Li and Xiaolong Ye
Minerals 2025, 15(6), 625; https://doi.org/10.3390/min15060625 - 9 Jun 2025
Cited by 1 | Viewed by 437
Abstract
The Upper Triassic Xujiahe Formation in the western Sichuan Basin is rich in natural gas resources and is one of the main tight sandstone gas-producing layers in the Sichuan Basin. Taking the tight sandstone of the second member of the Xujiahe Formation (Xu-2 [...] Read more.
The Upper Triassic Xujiahe Formation in the western Sichuan Basin is rich in natural gas resources and is one of the main tight sandstone gas-producing layers in the Sichuan Basin. Taking the tight sandstone of the second member of the Xujiahe Formation (Xu-2 Member) in the western Sichuan Basin as the study target, based on the analysis of the rock sample, a thin section, scanning electron microscopy, inclusion, the carbon and oxygen isotope, the petrological characteristics, the reservoir properties, the diagenetic sequences, and the pore evolution processes were revealed. The tight sandstones are composed of litharenite, sublitharenite, and feldspathic litharenite with an average porosity of 3.81% and a permeability mainly ranging from 0.01 to 0.5 mD. The early to late diagenetic stages were revealed, and the diagenetic evolution sequence with five stages was constructed. The Xu-2 sandstones were subdivided into three different types, and each type has its own tightening factors and processes. In the quartz-rich sandstone, the compaction and pressure solution were the primary causes of reservoir tightening, while late fracturing and dissolution along fractures were the main factors improving reservoir properties. In the feldspar-rich sandstone, early dissolution was a primary factor in improving porosity, while carbonate and quartz cements generated by dissolution contributed to a decrease in porosity. In the rock-fragment-rich sandstone, chlorites formed in the early stage and dissolution were the main factors of reservoir quality improvement, while the authigenic quartz formed in the middle diagenetic stage was the primary cause of reservoir tightening. Four major source-to-sink systems were identified in the western Sichuan Basin and they have different reservoir characteristics and reservoir quality controlling factors. This study will contribute to a deeper understanding of the characteristics, diagenetic evolution, and tightening process of tight sandstone reservoirs, effectively promoting scientific research and the industrial development of tight sandstone gas in the Xu-2 Member of the Sichuan Basin. Full article
(This article belongs to the Special Issue Natural and Induced Diagenesis in Clastic Rock)
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