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A special issue of Journal of Marine Science and Engineering (ISSN 2077-1312). This special issue belongs to the section "Geological Oceanography".

Deadline for manuscript submissions: 31 December 2024 | Viewed by 10074

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Special Issue Editors

Dr. Yanlong Li

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Guest Editor

The Key Laboratory of Gas Hydrate, Ministry of Natural Resources, Qingdao Institute of Marine Geology, Qingdao 266071, China
Interests: gas hydrate

Dr. Cunqi Jia

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Guest Editor

Hildebrand Department of Petroleum and Geosystems Engineering, The University of Texas at Austin, Austin, TX 78712, USA
Interests: reservoir simulation development and application; carbonate acid stimulation; naturally fractured and vuggy carbonate reservoirs; underground hydrogen storage (UHS); geological carbon sequestration

Special Issue Information

Dear Colleagues,

Background:

Petroleum and natural gas serve as critical resources for energy production worldwide. In the move toward more sustainable energy models, gas hydrate is becoming essential to facilitate the transition toward lower-carbon energy sources.

Aim and scope:

This Special Issue serves as a comprehensive forum dedicated to the latest research and advancements in petroleum and gas hydrate exploration, as well as marine geology.

History:

These fields have been fundamental in driving our industrial and technological growth.

Cutting-edge research:

Current diverse and progressive research fields, such as enhanced exploration technologies, artificial intelligence and machine learning, environmental impact and climate change studies, deep sea and marine geology, and sustainable practices and green energy, are collectively shaping the future of energy exploration, climate study, and marine geological understanding.

What kind of papers we are looking for:

We welcome high-quality research articles and reviews that delve into novel exploration techniques, cutting-edge geological models, efficient resource extraction methods, and studies on the environmental impact and sustainability of these processes. Potential topics include, but are not limited to, the following:

Marine geology and geophysics;
Innovative exploration technologies;
Reservoir engineering and characterization;
Sustainable exploration technologies;
Gas hydrates as a future energy source;
Artificial intelligence and machine learning applications;
Risk assessment and management;
Environmental and climate impacts.

Dr. Yanlong Li
Dr. Cunqi Jia
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. Journal of Marine Science and Engineering 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 2600 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.

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Published Papers (8 papers)

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Research

24 pages, 5064 KiB

Open AccessArticle

High-Precision Permeability Evaluation of Complex Carbonate Reservoirs in Marine Environments: Integration of Gaussian Distribution and Thomeer Model Using NMR Logging Data

by Hengyang Lv, Jianhong Guo, Baoxiang Gu, Yuhan Liu, Li Wang, Long Wang, Zuomin Zhu and Zhansong Zhang

J. Mar. Sci. Eng. 2024, 12(12), 2135; https://doi.org/10.3390/jmse12122135 - 22 Nov 2024

Abstract

Accurate evaluation of permeability parameters is critical for the exploration and development of oil and gas fields. Among the available techniques, permeability assessment based on nuclear magnetic resonance (NMR) logging data is one of the most widely used and precise methods. However, the rapid biochemical variations in marine environments give rise to complex pore structures and strong reservoir heterogeneity, which diminish the effectiveness of traditional SDR and Timur–Coates models. To address these challenges in complex carbonate reservoirs, this study proposes a high-precision permeability evaluation method that integrates the Gaussian distribution model with the Thomeer model for more accurate permeability calculations using NMR logging data. Multimodal Gaussian distributions more accurately capture the size and distribution of multiscale pores. In this study, we innovatively employ the Gaussian distribution function to construct NMR-derived pseudo-pore size distribution curves. Subsequently, Thomeer model parameters are derived from Gaussian distribution parameters, enabling precise permeability calculation. The application of this method to the marine dolomite intervals of the Asmari Formation, Section A, within Oilfield A in southeastern Iraq, demonstrates its superior performance under both bimodal and unimodal pore size distributions. Compared to traditional models, this approach significantly reduces errors, providing crucial support for the accurate evaluation of complex reservoirs and the development of hydrocarbon resources. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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22 pages, 10347 KiB

Open AccessArticle

Study of Cretaceous Provenance Tracing and Sedimentary Patterns in the Western Qiantang Sag, East China Sea Shelf Basin

by Kailong Feng, Weilin Zhu, Xiaowei Fu, Kai Zhong, Shijie Zhao, Weizhen Chen, Zengyuan Zhou and Lichen Hu

J. Mar. Sci. Eng. 2024, 12(3), 474; https://doi.org/10.3390/jmse12030474 - 10 Mar 2024

Cited by 1 | Viewed by 1262

Abstract

The Qiantang Sag, as one of the East China Sea Shelf Basin’s sags with thick residual Mesozoic strata, has long lacked comprehensive foundational sedimentary research, significantly impeding the understanding of the region’s resource potential and geological history. This study focuses on the Cretaceous strata of the Qiantang Sag, proposing a multi-phase sedimentary model for the Cretaceous Period. Through detailed analysis of the regional geological structure and sedimentary strata, this study unveils the complex sedimentary processes experienced by the Qiantang Sag during the Cretaceous. Utilizing drilling and core data combined with seismic geological interpretation, this study identifies that the western part of the Qiantang Sag predominantly developed alluvial fan and braided river deposits in an arid to semi-arid environment during the Cretaceous. Detrital zircon U-Pb dating analysis provides key information on the provenance areas and sedimentation ages, indicating that the Zhe-Min Uplift was the primary source region for the Qiantang Sag during the Cretaceous. Integrating vertical sedimentary sequences with provenance analysis, this study proposes sedimentary models and reconstructs the paleo-depositional evolution of the Qiantang Sag across different geological periods. During the Early Cretaceous Yushan Period, the region was influenced by intense volcanic activity, while also developing alluvial fan deposits in an arid environment. The Late Cretaceous Minjiang Period was characterized by semi-arid alluvial fan and braided river deposits. In contrast, the subsequent Shimentan Period saw the development of similar deposits, with the possible addition of seasonal lake deposits. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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13 pages, 7717 KiB

Open AccessArticle

Deep-Towed Array Geometry Inversion Based on an Improved Particle Swarm Optimization Algorithm

by Xiaohu Luo, Kai Liu, Yanliang Pei, Chenguang Liu, Xishuang Li and Yibao Xiao

J. Mar. Sci. Eng. 2024, 12(2), 282; https://doi.org/10.3390/jmse12020282 - 4 Feb 2024

Viewed by 1012

Abstract

When marine deep-towed multichannel seismic data are processed, the description of the receiving array geometry significantly impacts the quality of the imaging profile. Therefore, achieving a highly precise description of the receiving array geometry is very important for the fine imaging of such data. While basic particle swarm optimization (PSO) is known for its ease of implementation and efficiency, it often exhibits a low convergence accuracy. Consequently, the PSO algorithm is improved by modifying the inertia weight and incorporating Gaussian mutation. In combination with the actual motion of the towing streamer during surveys, a strategy for inheriting particle positions is introduced. When each seismic shot is solved sequentially, the results from the previous shot can serve as the initial particle positions for the next shot. The results indicate that this strategy achieves superior fitness values and outperforms the basic PSO algorithm. This method exhibits simplicity, rapid optimization, and a favorable solution quality, thereby offering a valuable approach to deep-towed array geometry inversion. It enhances the efficiency of deep-towed seismic data processing and serves as a reference for similar applications. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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22 pages, 34866 KiB

Open AccessArticle

Distribution Patterns and Genesis of Geological Fractures/Microfaults in the Qiongdongnan Basin, North of the South China Sea

by Junfeng Yu, Ruiyou Song and Caixia Chao

J. Mar. Sci. Eng. 2024, 12(1), 37; https://doi.org/10.3390/jmse12010037 - 22 Dec 2023

Viewed by 1037

Abstract

The Qiongdongnan Basin (QDNB), located in the north of the South China Sea, is a Cenozoic rift basin with abundant oil and gas resources. Large flake hydrates have been found in the core fractures of Quaternary formations in the deep-water depression of the QDNB. In order to understand the spatial distribution patterns of these fractures, their geneses in sedimentary basins, and their influences on gas migration and accumulation, such fractures have been observed using high-resolution 3D seismic images and visualization techniques. Four types of fractures and their combinations have been identified, namely bed-bounded fractures/microfaults, unbounded fractures, fracture bunches, and fracture clusters. Bed-bounded fractures/microfaults are mainly short and possess high density; they have developed in mass transport depositions (MTDs) or Meishan and Sanya Formations. The unbounded fractures/microfaults that occur in Miocene–Pliocene formations are mainly long and discrete, and are dominantly caused by strong tectonic movements, the concentration of stress, and sustained intense overpressure. The fracture bunches and fracture clusters that occur in Oligocene–Early Miocene formations have commonly developed with the accumulation of large numbers of fractures and may be related to the release of pressure, diapirs, and basement fault blocks (228.9 ± 1 Ma). In this study, six fluid charging or leakage models are proposed based on distinct fracture types, assuming the uniform conductivity of each fracture. In a 3D space view, a vertical decrease in the fracture scale (number or density) will more likely result in gas supply than dispersion, thus promoting the accumulation of gas in the reservoirs. Nevertheless, the fractures above the Bottom Simulating Reflect (BSR)/seismic anomaly are excessively developed, and bed-bounded fractures within a particular layer, such as MTDs, can easily cause seabed leakage. These results are useful for explaining the vertical migration of gas/fluids in areas and formations with less developed gas chimneys, faults, diapirs, and other structures, particularly in post-rifting basins. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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21 pages, 7697 KiB

Open AccessArticle

Influence of Natural Gas Hydrate Distribution Patterns on the Macroscale–Mesoscale Mechanical Properties of Hydrate-Bearing Sediments

by Yujing Jiang, Xiaoyu Du, Peng Yan, Meng Li, Hengjie Luan, Xianzhuang Ma and Yichen Shi

J. Mar. Sci. Eng. 2024, 12(1), 20; https://doi.org/10.3390/jmse12010020 - 20 Dec 2023

Viewed by 1026

Abstract

Studying the mechanical characteristics of hydrate-bearing sediments (HBS) contributes to the comprehensive understanding of the mechanical behavior in environments with natural gas hydrate (NGH) occurrences. Simultaneously, the distribution patterns of hydrates significantly influence the strength, deformation, and stability of HBS. Therefore, this paper employs particle flow code (PFC) to conduct biaxial discrete element simulations on specimens of HBS with different hydrate distribution patterns, revealing the macroscale–mesoscale mechanical properties, evolution patterns, and destructive mechanisms. The results indicate that the strain-softening behavior of HBS specimens strengthens with the increase in hydrate layer thickness, leading to higher peak strength and E₅₀ values. During the gradual movement of the hydrate layer position (A_y) from both ends to the center of the specimen (A_y = 0.40 mm → A_y = 20 mm), the strain-softening behavior weakens. However, when A_y = 20 mm, the specimen exhibits evident strain-softening behavior again. Moreover, with an increase in the angle between the hydrate layer and the horizontal direction (α) greater than 20°, the peak strength of the specimen increases, while E₅₀ shows an overall decreasing trend. The influence of axial loads on the hydrate layer in specimens varies with α, with larger contact forces and fewer cracks observed for higher α values. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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16 pages, 6120 KiB

Open AccessArticle

Formation Mechanism of Heavy Hydrocarbon Carbon Isotope Anomalies in Natural Gas from Ordovician Marine Carbonate in the Ordos Basin

by Wen Zhang, Wenhui Liu, Xiaofeng Wang, Zhengliang Huang, Qingfen Kong, Houyong Luo, Dongdong Zhang, Peng Liu, Xiaoyan Chen and Zhenghong Cai

J. Mar. Sci. Eng. 2023, 11(11), 2176; https://doi.org/10.3390/jmse11112176 - 15 Nov 2023

Viewed by 1166

Abstract

Interactive depositional systems of marine carbonates and gypsum salt rocks are closely related to natural gas reservoirs. Despite continuous progress in the exploration of new areas of marine carbonate genesis within the Ordos Basin, the source and mechanism of “sub-salt” natural gas genesis remains controversial. In this study, we investigated natural gas genesis through geochemical analysis of Lower Paleozoic natural gas samples from the mid-eastern Ordos Basin, obtaining natural gas composition data and carbon/hydrogen isotope compositions. We found evident differences between the geochemical characteristics of “sub-salt” and “post-salt” natural gas; the methane carbon isotope signature of “sub-salt” natural gas was lighter overall than that of “post-salt” natural gas, while the ethane carbon isotope composition of the former was more widely distributed and partially lighter than that of the latter. Combining these data with the regional geological background and existing geochemical data, it is evident that Ordovician “post-salt” natural gas comprises a composite of Upper Paleozoic coal-type gas and Lower Paleozoic oil-type gas, with the oil-type gas accounting for the largest proportion. In contrast, the “sub-salt” natural gas was formed and preserved within the Ordovician marine carbonates or sourced from deeper and more ancient hydrocarbon source rocks. Geochemical anomalies, including light methane carbon isotopes and ethane carbon isotopes with coal-type gas characteristics, are closely related to the prevalence of thermochemical sulfate reduction during hydrocarbon formation and reservoir formation of natural gas in “sub-salt” strata. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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20 pages, 6755 KiB

Open AccessArticle

Coupling Submarine Slope Stability and Wellbore Stability Analysis with Natural Gas Hydrate Drilling and Production in Submarine Slope Strata in the South China Sea

by Yufa He, Benjian Song and Qingping Li

J. Mar. Sci. Eng. 2023, 11(11), 2069; https://doi.org/10.3390/jmse11112069 - 30 Oct 2023

Cited by 5 | Viewed by 1546

Abstract

This research explores the geomechanical challenges associated with gas hydrate extraction in submarine slope zones, a setting posing a high risk of significant geological calamities. We investigate slope and wellbore deformations driven by hydrate decomposition within a subsea environment. Utilizing Abaqus, a fluid-solid-thermal multi-field coupling model for gas hydrate reservoirs was created. Hydrate decomposition during drilling is minimal, resulting in minor formation deformation near the wellbore. However, a year of hydrate production caused a maximum displacement of up to 7 m in the wellbore and formation, highlighting the risk of submarine landslides. This indicates the need for meticulous surveillance of formation subsidence and wellhead equipment displacement. In the aftermath of a hydrate-induced submarine landslide, both the hydrate layer and the overlying strata descend together, inflicting considerable damage on the formation and wellbore. Our study presents a holistic examination of the interplay between environmental geomechanics risks and engineering structure risks for submarine slope instability and wellbore stability during hydrate development, providing crucial insights for enhancing safety measures in hydrate drilling and production, and ensuring wellbore stability. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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19 pages, 24194 KiB

Open AccessArticle

The Impact of Pre-Existing Faults on Fault Geometry during Multiphase Rifts: The Jiyang Depression, Eastern China

by Di Wang, Linlong Yang, Wei Li and Xidong Wang

J. Mar. Sci. Eng. 2023, 11(10), 1971; https://doi.org/10.3390/jmse11101971 - 12 Oct 2023

Cited by 2 | Viewed by 1431

Abstract

The combination of multi-phase extension and pre-existing fault reactivation results in a complex fault pattern within hydrocarbon-bearing basins, affecting hydrocarbon exploration at different stages. We used high-resolution 3D seismic data and well data to reveal the impact of multi-phase extension and pre-existing fault reactivation on Cenozoic fault pattern changes over time in the Jiyang Depression of eastern China. The results show that during the Paleocene, a portion of NW-striking pre-existing faults reactivated under NS extension and controlled the basin structure (type 1). Other parts of the NW-striking pre-existing faults stopped activity and served as weak surfaces, and a series of NNE-striking faults were distributed in an en-echelon pattern along the NW direction at shallow depths (type 2). In areas unaffected by pre-existing faults, NE-striking faults formed perpendicular to regional stresses. During the Eocene, the regional stresses shifted clockwise to near-NS extension, and many EW-striking faults developed within the basin. The NE-striking faults and the EW-striking faults were hard-linked, forming the ENE-striking curved faults that controlled the structure in the basin (type 3). The NNE-striking faults were distinctly strike-slip at this time, with the ENE-striking faults forming a horsetail pattern at their tails. Many ENE-striking faults perpendicular to the extension direction were formed in areas where the basement was more stable and pre-existing faults were not developed (type 4). There were also developing NS-striking faults that were small in scale and appeared in positions overlapping different main faults (type 5). Additionally, different fault patterns can guide different phases of hydrocarbon exploration. Type 1, type 2, and type 3 faults are particularly suitable for early-stage exploration. In contrast, type 4 and type 5 faults are more appropriate for mature exploration areas, where they may reveal smaller hydrocarbon reservoirs. Full article

(This article belongs to the Special Issue Petroleum and Gas Hydrate Exploration and Marine Geology)

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