Reservoir Genesis and Quality Evolution in Hydrocarbon Systems

Topic Information

Dear Colleagues,

Reservoir rocks are the foundational units for hydrocarbon storage and flow, and their effectiveness is governed by their original depositional character and subsequent diagenetic modification. The porosity and permeability of these units, essential for economic viability, are products of their source material, the depositional system that formed them, and their post-depositional geological journey. Deciphering this evolution is a central challenge in geoscience with direct applications to reducing exploration risk and enhancing recovery.

We invite you to contribute to this Topic, which aims to showcase innovative research on the formation and quality evolution of clastic and carbonate reservoirs in petroleum basins.

This Topic aims bring together a collection of articles that advance the understanding of reservoir genesis, heterogeneity, and quality prediction. This subject is core to the journal's scope in petroleum geology, reservoir engineering, and subsurface characterization, focusing on the geological processes that create and modify hydrocarbon pore space. By highlighting studies that bridge fundamental research and applied practices, this issue will provide valuable insights and predictive models for characterizing complex reservoir systems, ultimately supporting more effective hydrocarbon resource development.

We welcome the submission of original research articles and reviews. Research areas may include (but are not limited to) the following:

• The genesis of reservoir sedimentary bodies and provenance analysis;
• Diagenetic sequences and their impact on porosity-permeability evolution;
• Fractal characterization of reservoir heterogeneity;
• Advanced techniques in reservoir rock petrophysics and imaging (e.g., digital rock physics, micro-CT);
• Geochemical proxies for reconstructing reservoir quality evolution;
• Mechanical and chemical processes in fracture formation and sealing;
• Reservoir architecture and stratigraphic framework analysis;
• Integrated reservoir modeling and quality prediction;
• Case studies of reservoir evolution in conventional and unconventional plays.

We look forward to receiving your contributions.

Dr. Lei Chen
Prof. Dr. Bojiang Fan
Dr. Hexin Huang
Dr. Liangwei Xu
Dr. Zhikai Liang
Topic Editors

Keywords

Participating Journals

Journal Name	Impact Factor	CiteScore	Launched Year	First Decision (median)	APC
Minerals minerals	2.2	4.4	2011	17.7 Days	CHF 2400	Submit
Geosciences geosciences	2.1	5.1	2011	23.6 Days	CHF 1800	Submit
Fractal and Fractional fractalfract	3.3	6.0	2017	19.3 Days	CHF 2700	Submit
Energies energies	3.2	7.3	2008	16.8 Days	CHF 2600	Submit
Journal of Marine Science and Engineering jmse	2.8	5.0	2013	16.5 Days	CHF 2600	Submit
Processes processes	2.8	5.5	2013	14.9 Days	CHF 2400	Submit

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Published Papers (6 papers)

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All Minerals Geosciences Fractal Fract Energies JMSE Processes

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20 pages, 3621 KB  

Open AccessArticle

Pyrolysis Kinetics of Lacustrine Shales from the Yanchang Formation: Revealing the Role of Kerogen Type in Shaping Hydrocarbon Generation and Expulsion Pattern

by Lingling Liao, Yifei Zhang, Yan Li and Yinhua Pan

Geosciences 2026, 16(3), 96; https://doi.org/10.3390/geosciences16030096 - 26 Feb 2026

Viewed by 196

Abstract

The Yanchang Formation in the Ordos Basin is a key target for continental shale oil exploration in China. Due to its complex geological background and diversified organic inputs, the hydrocarbon generation and accumulation in the lacustrine basin remain to be fully understood. Unlike [...] Read more.

The Yanchang Formation in the Ordos Basin is a key target for continental shale oil exploration in China. Due to its complex geological background and diversified organic inputs, the hydrocarbon generation and accumulation in the lacustrine basin remain to be fully understood. Unlike marine shales rich in Type I kerogen, this lacustrine system is dominated by Type II and III kerogens. In this study, Rock-Eval pyrolysis was performed on lacustrine shales with Type IIa, IIb, and III kerogens to investigate the effect of kerogen type on their hydrocarbon generation and expulsion characteristics. The results reveal that the hydrocarbon generation potential of the Yangchang Formation shale generally follows the order of Type IIa > Type IIb > Type III. Pyrolysis kinetic calculations of the kerogens demonstrate a clear hierarchy of hydrocarbon generation and expulsion among the kerogen types, of which Type II kerogen has better hydrocarbon generation potential, earlier generation timing, and narrower generation window than Type III kerogen. The discrepancy in hydrocarbon generation potential and pyrolysis kinetic behavior is largely attributed to the kerogen components and types, which manifests as a kerogen-type constraint on the hydrocarbon generation and expulsion of shale. Based on the geological mapping of the lacustrine shales in the study area, we propose a “kerogen type-specific” exploration strategy that prioritizes Type IIa-rich intervals in moderate-maturity areas for shale oil exploration, Type IIb as secondary prospects, and Type III in high-maturity areas for shale gas exploration. This study provides a systematic investigation of pyrolysis simulation and hydrocarbon generation and expulsion kinetics on the Yanchang Formation shale, as well as a practical framework for optimizing exploration in analogous lacustrine basins. Full article

(This article belongs to the Topic Reservoir Genesis and Quality Evolution in Hydrocarbon Systems)

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22 pages, 7946 KB  

Open AccessArticle

Control of Sedimentary Environment on Pore Structure and Its Evolution of the Lower Carboniferous Shale in the Yaziluo Rift Trough, Dianqiangui Basin

by Xianglin Chen, Luchuan Zhang, Qiuchen Xu, Dishi Shi, Ruihan Ma, Yibo Li, Haichuan Ma and Zhiyuan Li

Minerals 2026, 16(2), 214; https://doi.org/10.3390/min16020214 - 19 Feb 2026

Viewed by 145

Abstract

A breakthrough has been achieved in shale gas exploration of the Lower Carboniferous Shale in the Yaziluo Rift Trough, Dianqiangui Basin, with Well SY-1 yielding a daily gas production of 1.1 × 10⁴ m³. To clarify the main controls and [...] Read more.

A breakthrough has been achieved in shale gas exploration of the Lower Carboniferous Shale in the Yaziluo Rift Trough, Dianqiangui Basin, with Well SY-1 yielding a daily gas production of 1.1 × 10⁴ m³. To clarify the main controls and evolutionary patterns of shale pore structure, shale samples from different sedimentary environments were analyzed using TOC content, X-ray diffraction (XRD), low-pressure gas adsorption (CO₂ and N₂), and field emission-scanning electron microscopy (FE-SEM). The results show that shale from the basin sedimentary environment (BSE) exhibits the highest TOC, is dominated by siliceous minerals (quartz + feldspar), and contains minor carbonate minerals (calcite + dolomite). Shale from the upper slope sedimentary environment (USSE) has the lowest TOC and is rich in carbonate minerals. The lower slope sedimentary environment (LSSE) shows intermediate compositions. From BSE to USSE, pore volume and specific surface area decrease, while fracture development increases. A quantitative model for volumes of organic pores, clay mineral-associated pores, and brittle mineral-associated pores was established. Organic pores dominate in BSE shale (65.42%), followed by clay mineral-associated and brittle mineral-associated pores, while inorganic pores dominate in USSE shale (63%). Pore structure in BSE and LSSE is primarily controlled by TOC content, with pore volume and surface area increasing with TOC content, while mesopore development is influenced by organic matter type and mineral compositions. In USSE, pore structure is mainly governed by inorganic minerals, with clay minerals promoting pore volume and surface area development, whereas brittle minerals facilitate the preservation of macropores. Evolutionary models of pore development were established for these distinct sedimentary environments. Full article

(This article belongs to the Topic Reservoir Genesis and Quality Evolution in Hydrocarbon Systems)

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32 pages, 18294 KB  

Open AccessArticle

Influencing Factors of Hydrocarbon Migration and Adjustment at the Edge of a Stable Cratonic Basin: Implications from Fluid Inclusions, Quantitative Fluorescence Techniques, and Geochemical Tracing

by Zhengqi Yang, Xin Cheng, Siqi Ouyang, Zhe Liu, Yuting Cheng, Shuqi Lan, Lei Xue, Ting Zhang and Yiqian Qu

Energies 2026, 19(3), 638; https://doi.org/10.3390/en19030638 - 26 Jan 2026

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Abstract

Understanding the mechanisms of hydrocarbon migration, accumulation, and alteration, particularly how evolution controls these processes, is critical for exploring lithologic hydrocarbons in reservoirs. In the complex tectonic settings of the continental margin of the stable North China Craton, there is a significant presence [...] Read more.

Understanding the mechanisms of hydrocarbon migration, accumulation, and alteration, particularly how evolution controls these processes, is critical for exploring lithologic hydrocarbons in reservoirs. In the complex tectonic settings of the continental margin of the stable North China Craton, there is a significant presence of small yet highly prolific hydrocarbon reservoirs. The processes of hydrocarbon migration and accumulation are complex and thus represent an important research focus in geology. This study, based on core, logging, and seismic data and integrating fluid inclusion analysis, quantitative fluorescence techniques, and geochemical experiments, combines the shale smear factor and paleotectonic reconstructions to clarify the hydrocarbon accumulation episodes, migration pathways, and factors controlling reservoir adjustments in the Yanwu area of the Tianhuan Depression in the Ordos Basin, China. The results reveal three types of NE-trending left-lateral strike–slip faults: linear, left-stepping, and right-stepping. Shale Smear Factor (SSF) analysis confirms that these faults exhibit segmented opening behaviors, with SSF > 1.7 identified as the threshold for fault openness. Multiparameter geochemical tracing based on terpanes and steranes shows that lateral migration along fault zones dominates the preferential migration pathways for hydrocarbons. Fluid inclusion thermometry revealed homogenization temperatures within the 100–110 °C and 80–90 °C intervals, while the oil inclusions exhibit blue or blue-and-white fluorescence, reflecting early hydrocarbon charging and late-stage secondary migration. Integrated analysis indicates that during the late Early Cretaceous (105–90 Ma), hydrocarbons were charged upward through open segments of linear strike–slip fault zones in the northern study area, experiencing lateral migration and accumulation along high-permeability sand bodies and unconformities in the shallow strata. Since the Late Cretaceous (65 Ma-present), the regional tectonic framework has evolved from a west–high, east–low to a west–low, east–high configuration, inducing secondary hydrocarbon migration and leading to the remigration or even destruction of early-formed oil reservoirs. This study systematically demonstrates that fault activity and tectonic evolution control the accumulation and distribution of hydrocarbons in the region. These findings provide theoretical insights for hydrocarbon exploration in regions with complex tectonic evolution within stable cratonic basins. Full article

(This article belongs to the Topic Reservoir Genesis and Quality Evolution in Hydrocarbon Systems)

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23 pages, 13600 KB  

Open AccessArticle

Development of Braided River Delta–Shallow Lacustrine Siliciclastic–Carbonate Mixed Sedimentation in the Upper Ganchaigou Formation, Huatugou Oilfield, Qaidam Basin, China

by Yuxin Liang, Xinmin Song, Youjing Wang and Wenjie Feng

Minerals 2026, 16(1), 92; https://doi.org/10.3390/min16010092 - 17 Jan 2026

Viewed by 263

Abstract

This study systematically investigates the lithofacies, sedimentary microfacies, vertical evolution, and spatial distribution of the braided river delta–shallow lacustrine carbonate mixed sedimentary rocks of the Upper Ganchaigou Formation in the Huatugou Oilfield of the Qaidam Basin, China. This study integrates data from field [...] Read more.

This study systematically investigates the lithofacies, sedimentary microfacies, vertical evolution, and spatial distribution of the braided river delta–shallow lacustrine carbonate mixed sedimentary rocks of the Upper Ganchaigou Formation in the Huatugou Oilfield of the Qaidam Basin, China. This study integrates data from field outcrops, core observations, thin section petrography, laboratory analyses, and well-logging interpretations. Based on these datasets, the sedimentary characteristics are identified, and a comprehensive sedimentary model is constructed. The results reveal that the study area contains five clastic facies, three types of mixed sedimentary facies, and ten sedimentary microfacies. Two distinct modes of mixed sedimentation are recognized: component mixing and stratigraphic mixing. A full lacustrine transgression–regression cycle is formed by the two types of mixed sedimentation characteristics, which exhibit noticeable differences in vertical evolution. Component mixing, which occurs in a mixed environment of continuous clastic supply and carbonate precipitation during the transgression, is the primary characteristic of the VIII–X oil formation. The mixed strata that make up the VI–VII oil formation show rhythmic interbedding of carbonate and clastic rocks. During the lacustrine regression, it shows the alternating sedimentary environment regulated by frequent variations in lacustrine levels. The planar distribution is affected by both intensity of sediment from the west and the changes in lacustrine level. During the lacustrine transgression, it is dominated by littoral-shallow lacustrine mixed beach bar and mixed sedimentary delta. On the other hand, during the lacustrine regression, it is dominated by laterally amalgamated sand bodies in the braided-river delta front. Based on this, a mixed sedimentary evolution model controlled by the coupling of “source–lacustrine level” is established. It offers a guide for reconstructing the sedimentary environment in basins that are similar to it and reveals the evolution path of mixed sedimentation in the short-axis source area of arid saline lacustrine basins. Full article

(This article belongs to the Topic Reservoir Genesis and Quality Evolution in Hydrocarbon Systems)

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20 pages, 18087 KB  

Open AccessArticle

Formation Mechanism of Pores and Throats in the Permian Continental Shales of the Junggar Basin in China

by Ze Li, Xianglu Tang, Lei Chen, Zhenxue Jiang, Zhenglian Yuan, Leilei Yang, Yifan Jiao and Wanxin Shi

Minerals 2026, 16(1), 38; https://doi.org/10.3390/min16010038 - 29 Dec 2025

Viewed by 307

Abstract

Shale pores and throats are key factors controlling the enrichment and development efficiency of shale oil and gas. However, the characteristics and formation mechanisms of shale pores and throats remain unclear. Taking the Permian continental shales in the Mahu Sag of the Junggar [...] Read more.

Shale pores and throats are key factors controlling the enrichment and development efficiency of shale oil and gas. However, the characteristics and formation mechanisms of shale pores and throats remain unclear. Taking the Permian continental shales in the Mahu Sag of the Junggar Basin as an example, this paper studies the formation mechanisms of pores and throats in shales of different lithofacies through a series of experiments, such as high-pressure mercury injection and scanning electron microscopy. The results show that the Permian continental shales in the Junggar Basin are mainly composed of five lithofacies: rich siliceous shale (RSS), calcareous–siliceous shale (CSS), argillaceous–siliceous shale (ASS), siliceous–calcareous shale (SCS), and mixed-composition shale (MCS). The pores in shale are dominated by intergranular and intragranular pores. The intergranular pores are mainly primary pores and secondary dissolution pores. The primary pores are mainly slit-like and polygonal, with diameters between 40 and 1000 nm. The secondary dissolution pores formed by dissolution are irregular with serrated edges, and their diameters range from 0.1 to 10 μm. The throats are mainly pore-constriction throats and knot-like throats, with few vessel-like throats, overall exhibiting characteristics of nanometer-scale width. The mineral composition has a significant influence on the development of pores and throats. Siliceous minerals promote the development of macropores, and carbonate minerals promote the development of mesopores. Clay minerals inhibit pore development. Diagenesis regulates the development of pores and throats through mechanical compaction, cementation, and dissolution. Compaction leads to a reduction in porosity, and cementation has varying effects on the preservation of pores and throats. Dissolution is the main factor for increased pores and throats. These findings provide a lithofacies-based geological framework for evaluating effective porosity, seepage capacity, and shale oil development potential in continental shale reservoirs. Full article

(This article belongs to the Topic Reservoir Genesis and Quality Evolution in Hydrocarbon Systems)

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19 pages, 3641 KB  

Open AccessArticle

The Enrichment of Uranium in Marine Organic-Rich Overmature Shales: Association with Algal Fragments and Implications for High-Productivity Interval

by Guoliang Xie, Kun Jiao, Shugen Liu, Yuehao Ye, Jiayu Wang, Bin Deng, Juan Wu and Xiaokai Feng

Minerals 2025, 15(12), 1238; https://doi.org/10.3390/min15121238 - 23 Nov 2025

Viewed by 616

Abstract

Marine organic-rich shales frequently exhibit anomalously high uranium (U) concentrations, yet the mechanisms governing its enrichment in overmature formations like the Wufeng–Longmaxi shales remain unclear. This study examines the distribution and enrichment patterns of uranium in the Wufeng–Longmaxi shales in typical wells through [...] Read more.

Marine organic-rich shales frequently exhibit anomalously high uranium (U) concentrations, yet the mechanisms governing its enrichment in overmature formations like the Wufeng–Longmaxi shales remain unclear. This study examines the distribution and enrichment patterns of uranium in the Wufeng–Longmaxi shales in typical wells through integrated geochemical and geophysical analyses, supplemented by natural gamma spectral logging data. Key findings include: (1) Multiple (up to three) uranium enrichment events are identified within the Wufeng–Longmaxi sequence, consistently corresponding to shale gas sweet spots. (2) Uranium content shows a clear dependence on organic matter (OM) type, with algal fragments being the primary host of uranium, likely due to incorporation during early diagenesis. Pore-water redox conditions and pH further govern the reduction of U (U⁶⁺) and its subsequent sequestration into organic phases. (3) The equivalent vitrinite reflectance (ER_o) of uranium-rich shales is 0.11%–0.17% higher than that of non-uranium-rich shales, suggesting that uranium enrichment may slightly enhance OM thermal maturity. (4) Uranium distribution is collectively controlled by reducing conditions, volcanic eruptions (e.g., tuff layers), and OM type. Additionally, uranium enrichment provides chronostratigraphic markers that may aid in timing marine black shales. These findings thus offer a mechanistic understanding of uranium enrichment in overmature shales, with direct implications for targeting productive intervals in shale gas systems. Full article

(This article belongs to the Topic Reservoir Genesis and Quality Evolution in Hydrocarbon Systems)

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