Topic Editors

Department of Geology, Federal University of Ceará (UFC), Fortaleza 60440-554, CE, Brazil
Department of Natural Resources, Federal University of Maranhão (UFMA), Grajaú 65940-000, MA, Brazil
Core Laboratories LP, 6316 Windfern Road, Houston, TX 77040, USA

Petroleum Geology and Geochemistry of Sedimentary Basins

Abstract submission deadline
closed (31 March 2024)
Manuscript submission deadline
31 May 2024
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5182

Topic Information

Dear Colleagues,

We are pleased to announce the Topic “Petroleum Geology and Geochemistry of Sedimentary Basins”, devoted to a broad spectrum of research in the field, including the origin, storage, pathways and characterization of hydrocarbons, both as traditional economic sources and for several application purposes. Applications may include ways and solutions dealing with greenhouse gases in a wide scope, i.e., from fossil sources to storage in the geological realms.  

In the context of an increasing demand for energy resources and for answers to global warming at the same time, petroleum geology and geochemical research are positioned in the middle of these issues, considering that hydrocarbon sources will remain essential during an energy transition scenario for humankind in the coming decades. Therefore, we are seeking not only alternative sources of energy but also new ways to improve reservoir modeling and recovery of hydrocarbons from both fresh and mature fields, and its unconventional sources, such as shale gas, tight oil, etc.

Our goal for this Topic is to gather topical, high-quality works in a concise collection focusing on petroleum geology and geochemistry, namely geology, geochemistry and mineralogy of conventional and unconventional oil and gas resources, including excellent reviews in these topics.

Dr. Daniel Rodrigues do Nascimento Junior
Dr. Ana Clara Braga de Souza
Dr. Thomas Gentzis
Topic Editors

Keywords

  • organic geochemistry
  • pyrolysis
  • petrophysics
  • well and outcrop data
  • carbon capture and storage
  • stable isotopes

Participating Journals

Journal Name Impact Factor CiteScore Launched Year First Decision (median) APC
Energies
energies
3.2 5.5 2008 16.1 Days CHF 2600 Submit
Geosciences
geosciences
2.7 5.2 2011 23.6 Days CHF 1800 Submit
Minerals
minerals
2.5 3.9 2011 18.7 Days CHF 2400 Submit
Quaternary
quaternary
2.3 3.6 2018 29.2 Days CHF 1600 Submit

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Published Papers (5 papers)

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21 pages, 14051 KiB  
Article
Diagenetic Impact on High-Pressure High-Temperature Reservoirs in Deep-Water Submarine Fan Sandstone of Qiongdongnan Basin, South China Sea
by Lin Hu, Wei Luo and Benben Ma
Minerals 2024, 14(4), 361; https://doi.org/10.3390/min14040361 - 29 Mar 2024
Viewed by 416
Abstract
The diagenetic evolution of sandstone is very complicated under the conditions of high temperatures and pressures in deep-water, deep-buried regimes, which have great influence on reservoir quality. This study investigates the typical reservoir target of Neogene deep-water, submarine-fan sandstones under high-temperature, high-pressure regimes [...] Read more.
The diagenetic evolution of sandstone is very complicated under the conditions of high temperatures and pressures in deep-water, deep-buried regimes, which have great influence on reservoir quality. This study investigates the typical reservoir target of Neogene deep-water, submarine-fan sandstones under high-temperature, high-pressure regimes in the Qiongdongnan Basin, South China Sea. Utilizing a thin section, scanning electron microscope (SEM), mineral geochemistry combined with burial history evolution, complex diagenetic events, and main controlling factors of the sandstone in the Neogene Meishan Formation were determined. The results show that the evolution of sandstone reservoirs is initially controlled by depositional framework compositions and subsequently modified by eogenetic and mesogenetic alterations during progressive burial. Eogenetic alterations mainly include the following: (1) mechanical compaction; (2) dissolution of feldspar; (3) low-Fe calcite cementation. Mesogenetic events were identified as the following: (1) dissolution of feldspar; (2) ferroan calcite and ankerite formation; (3) precipitation of quartz and clay mineral. Mechanical compaction is greatly influenced by the original depositional framework composition, and sandstone samples enriched in high contents of detrital clay matrix always experienced extensive mechanical compaction. Different phases of carbonate cement during different diagenetic regimes lead to continuous destruction on reservoir porosity. The dissolution of unstable feldspar minerals during eogenetic and mesogenetic environments leads to the development of secondary porosities and would enhance the quality of the reservoir. Overpressure formation is pervasively developed owing to early disequilibrium compaction and subsequent natural gas charging. Only well-sorted sandstones with low contents of detrital clay matrix could resist early mechanical compaction, lead to ample residual original porosities, and then undergo extensive mineral dissolution to generate sufficient secondary porosities. Subsequently, these porosities would be effectively protected by overpressure formation. Poor-sorted sandstones with high contents of detrital clay matrix would experience strong mechanical compaction and extensive destruction of original porosities. Thus, these sandstones are difficult to have significant dissolution and are unable to be effectively protected by overpressure formation. Therefore, the interplay between the original framework composition and the corresponding diagenetic pathways coupled with overpressure formation would result in strong reservoir heterogeneity for the deep-buried sandstones during progressive burial. Full article
(This article belongs to the Topic Petroleum Geology and Geochemistry of Sedimentary Basins)
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18 pages, 20043 KiB  
Article
New Age Constraints of the Bilong Co Oil Shale in the Qiangtang Basin, Northern Tibet: Evidence from In Situ U–Pb Dating and Palaeontology
by Haowei Zhang, Jian Wang, Ahmed Mansour, Jianyong Zhang, Hengye Wei, Xiugen Fu, Lijun Shen, Shaoyun Xiong, Mohamed S. Ahmed and Thomas Gentzis
Minerals 2024, 14(3), 246; https://doi.org/10.3390/min14030246 - 28 Feb 2024
Viewed by 715
Abstract
The Bilong Co oil shale is one of the most significant source rocks in the Mesozoic Qiangtang Basin (Northern Tibet); however, its absolute chronology remains controversial. In this study, in situ carbonate U–Pb isotope dating analysis was carried out for the first time. [...] Read more.
The Bilong Co oil shale is one of the most significant source rocks in the Mesozoic Qiangtang Basin (Northern Tibet); however, its absolute chronology remains controversial. In this study, in situ carbonate U–Pb isotope dating analysis was carried out for the first time. Detailed field geological investigations yielded some age-diagnostic ammonites, enabling a re-evaluation of the stratigraphic age of the Bilong Co oil shale. A total of 61 spots of U–Pb isotope dating from the middle part of the Bilong Co oil shale section suggests an average age of 181 ± 13 Ma. Elemental geochemistry and diagenetic analysis indicate that the proposed age represents the early deposition of the calcite, and the oil shale was deposited during the Early Jurassic time. This estimated age is further supported by the newly discovered ammonite assemblage of HildoceratidaeTiltoniceras sp. at the top part of the oil shale section, which confirms the deposition of the oil shale during the Toarcian age of the late Early Jurassic. Consequently, the Bilong Co oil shale can be assigned to the Quse Formation, which is attributed to the Lower Jurassic rather than the Middle Jurassic. The re-assessment of the stratigraphic age of the Bilong Co oil shale is of great significance for regional evaluation and exploration activities of hydrocarbon source rock layers in the Qiangtang Basin as well as for global stratigraphic correlation of the late Early Jurassic Toarcian oceanic anoxic event. Full article
(This article belongs to the Topic Petroleum Geology and Geochemistry of Sedimentary Basins)
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42 pages, 71568 KiB  
Article
Assessment of Oil and Gas Potential in Vychegda Trough in Connection with the Identification of Potential Petroleum Systems
by Sergey Krivoshchekov and Andrey Botalov
Geosciences 2024, 14(3), 57; https://doi.org/10.3390/geosciences14030057 - 21 Feb 2024
Viewed by 817
Abstract
At present, the study of the oil and gas potential of poorly explored areas of oil and gas basins in the Russian Federation is of great importance due to the possibility of discovering large hydrocarbon accumulations in them. The Vychegda Trough in the [...] Read more.
At present, the study of the oil and gas potential of poorly explored areas of oil and gas basins in the Russian Federation is of great importance due to the possibility of discovering large hydrocarbon accumulations in them. The Vychegda Trough in the north of the Volga–Ural basin is considered to be one of such areas. The research is devoted to the assessment of the oil and gas potential of the Vychegda Trough based on the concept of “petroleum systems”, which is widely used in oil and gas geology. A comprehensive analysis of geological and geophysical, petrophysical and geochemical data was carried out, and modern technologies for studying the oil and gas potential of sedimentary basins were applied: paleotectonic, paleogeographic reconstructions and basin modeling. The results of the research allowed us to determine a sufficiently high potential for the discovery of hydrocarbon accumulations and to identify three potential petroleum systems in the basin section: Riphean, Vendian and Devonian–Permian. Full article
(This article belongs to the Topic Petroleum Geology and Geochemistry of Sedimentary Basins)
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15 pages, 3558 KiB  
Article
Applying Statistical Analysis and Economics Models to Unscramble the Depositional Signals from Chemical Proxies in Black Shales
by Karin Goldberg and Lucas Goldberg Da Rosa
Geosciences 2024, 14(2), 43; https://doi.org/10.3390/geosciences14020043 - 03 Feb 2024
Viewed by 1087
Abstract
The complex controls on the accumulation of organic-rich rocks remain elusive, despite their economic importance as source rocks and unconventional reservoirs, partially due to the multitude of factors that may impact production and preservation of organic matter in sediments. The complexity of Earth [...] Read more.
The complex controls on the accumulation of organic-rich rocks remain elusive, despite their economic importance as source rocks and unconventional reservoirs, partially due to the multitude of factors that may impact production and preservation of organic matter in sediments. The complexity of Earth systems is comparable to the intricacies of Economics, and application of statistical and econometrics methods and models to analyze geological data may assist interpretation of the processes controlling organic burial. Chemical indices calculated for mudrock datasets from modern sediments and the Woodford Formation were used as proxies for detrital input, primary productivity, redox conditions, and upwelling, and a series of statistical analyses were run to test whether these methods were useful to discriminate different depositional conditions and establish the controls on total organic carbon (TOC) in the sediments. Model results showed that chemical proxies reliably predict not only TOC but also indicate correlations between indices. Our results suggest that detrital input, primary productivity and bottom-water anoxia are relevant drivers of organic content in the sediments, but the first two appear to have a more significant role in organic burial, illustrating the usefulness of these methods to assess depositional parameters in organic-rich rocks. Full article
(This article belongs to the Topic Petroleum Geology and Geochemistry of Sedimentary Basins)
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23 pages, 16660 KiB  
Article
Organic Matter Assessment and Paleoenvironmental Changes of the Middle Jurassic Main Source Rocks (Khatatba Formation) in the North Western Desert, Egypt: Palynofacies and Palynomorph Perspectives
by Ahmed Mansour, Sameh S. Tahoun, Aya Raafat, Mohamed S. Ahmed, Francisca Oboh-Ikuenobe, Thomas Gentzis and Xiugen Fu
Minerals 2023, 13(4), 548; https://doi.org/10.3390/min13040548 - 13 Apr 2023
Cited by 2 | Viewed by 1447
Abstract
The Middle Jurassic in the north Western Desert, Egypt, was a time of complex tectonics and increased environmental perturbations attributed to the predominant sedimentation of organic carbon-rich fine siliciclastic and carbonate deposits of the Khatatba Formation. Although some studies have addressed the hydrocarbon [...] Read more.
The Middle Jurassic in the north Western Desert, Egypt, was a time of complex tectonics and increased environmental perturbations attributed to the predominant sedimentation of organic carbon-rich fine siliciclastic and carbonate deposits of the Khatatba Formation. Although some studies have addressed the hydrocarbon potential and source rock characteristics of the Khatatba Formation, a regional-scale investigation of the prevalent paleoenvironmental conditions and organic matter characteristics is still necessary. In this study, the Khatatba Formation is investigated for detailed palynofacies analysis and palynomorph composition to assess organic matter kerogen types and reconstruct the depositional paleoenvironmental patterns on a regional scale. For this purpose, 116 drill cuttings were collected from five wells in the Matruh, Shushan, and Dahab-Mireir Basins. Moderately diverse assemblages of spores, pollen, and dinoflagellate cysts are reported. Age-diagnostic dinoflagellate cysts, including Adnatosphaeridium caulleryi, Dichadogonyaulax sellwoodii, Korystocysta gochtii, Wanaea acollaris, and Pareodinia ceratophora, along with occasional records of Systematophora areolate and Systematophora penicillate, defined a Bajocian–Callovian age. Based on particulate organic matter (POM) composition, four palynofacies assemblages (PFAs) are identified. PFA-1 is the most common within the Khatatba Formation in the five studied wells. It contains high proportions of phytoclast fragments versus low contents of amorphous organic matter (AOM) and palynomorphs and is defined by a gas-prone kerogen Type III. PFA-2 is comprised of moderate abundances of AOM and phytoclast characteristics of oil-prone kerogen Type II. PFA-3 is dominated by phytoclasts and moderate to low proportions of AOM and palynomorphs of kerogen Type III, whereas PFA-4 consists of AOM and palynomorphs defining kerogen Type II. PFA-1 indicates predominant deposition in proximal active fluvio-deltaic sources to marginal marine conditions with enhanced contributions of terrestrial/riverine influx. PFA-2 and PFA-3 reveal deposition under an enhanced dysoxic to anoxic proximal inner neritic shelf due to the abundant occurrences of spores and coastal to shallow marine dinoflagellate cysts. PFA-4 suggests deposition under enhanced suboxic to anoxic distal inner neritic conditions because of enhanced AOM and abundant proximate and some chorate dinoflagellate cysts. Thus, the Middle Jurassic experienced a predominantly marginal to shallow water column in this part of the southern margin of the Tethyan Ocean where the Matruh, Shushan, and Dahab-Mireir Basins were located. Full article
(This article belongs to the Topic Petroleum Geology and Geochemistry of Sedimentary Basins)
(This article belongs to the Section Mineral Exploration Methods and Applications)
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Planned Papers

The below list represents only planned manuscripts. Some of these manuscripts have not been received by the Editorial Office yet. Papers submitted to MDPI journals are subject to peer-review.

Title: Geochemistry of greenhouse gases exhaling from soils on the pimenteiras formation (brazil): origin of the organic matter and environmental impact
Authors: Ana Clara Braga de Souza, Daniel Rodrigues do Nascimento Junior et al.

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