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High-Efficient Exploration and Development of Oil & Gas from Ocean—2nd...
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High-Efficient Exploration and Development of Oil & Gas from Ocean—2nd Edition

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: closed (31 March 2024) | Viewed by 3222

Special Issue Editors

Prof. Dr. Mianmo Meng

E-Mail Website
Guest Editor
1. Hubei Key Laboratory of Marine Geological Resources, China University of Geosciences, Wuhan 430074, China 2. College of Marine Science and Technology, China University of Geosciences, Wuhan 430074, China
Interests: pore structure characterization; fluid occurrence; water–rock interaction; nuclear magnetic resonance; unconventional oil/gas
Special Issues, Collections and Topics in MDPI journals
Dr. Wenming Ji

E-Mail Website
Guest Editor
School of Geosciences, China University of Petroleum (East China), Qingdao 266580, China
Interests: shale oil and gas geology; petroleum migration and accumulation; shale reservoir characterization; shale pore system; organic matter accumulation
Special Issues, Collections and Topics in MDPI journals
Dr. Guodong Cui

E-Mail Website
Guest Editor
Faculty of Engineering, China University of Geosciences, Wuhan 430074, China
Interests: CO2 geological storage; CO2 flooding; heavy oil recovery; thermal recovery; gas hydrate
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

There are still some critical problems in developing unconventional oil and gas. First, the selection of sweet points is still challenging from a geological perspective. The explanation of geophysical data (wireline logs and seismic data) to identify the most favorable layers remains controversial. Second, prospecting well can directly recover a sample from the target layers, and detailed information about the fluid and reservoir aids in selecting the best layer for development. It is also problematic to evaluate hydrocarbon occurrence, especially movability, in in situ conditions. Finally, hydraulic fracturing is a basic method which is widely used to develop the most unconventional oil/gas. However, there remain unsolved problems with generating an ideal fracture network due to complex natural cracks and artificial fractures. The highly efficient development of unconventional offshore oil/gas, such as gas hydrate, is still challenging and attracts a great deal of attention. This Special Issue proposes a collection of state-of-the-art research on the exploration and development of unconventional offshore oil/gas. We invite prospective authors to submit high-quality original articles or reviews regarding how to develop unconventional oil/gas with high efficiency from both geological and engineering aspects.

Potential topics include, but are not limited to:

  • High-resolution geochemical characterization of reservoir lithofacies and diagenesis.
  • The origin, evolution, and petrophysical characterization of unconventional reservoirs.
  • High-resolution 3D reconstruction of digital cores and relevant upscaling methods.
  • In situ hydrocarbon generation, occurrence, and movability.
  • Drilling, completion, and hydraulic fracturing.
  • Rock–fluid interaction and its influence on reservoir property.
  • Natural and artificial fracture characterization.
  • CO2 flooding in oil/gas recovery and its application in carbon sequestration.
  • Enhanced gas hydrate recovery with geothermal energy.
  • Enhanced oil recovery via physical and chemical methods.

Prof. Dr. Mianmo Meng
Dr. Wenming Ji
Dr. Guodong Cui
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.

Keywords

  • gas hydrate
  • shale oil
  • shale gas
  • tight gas
  • tight oil
  • coalbed gas
  • CCUS

Related Special Issue

Published Papers (5 papers)

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Research

27 pages, 3320 KiB  
Article
Characteristics and Reservoir Development Model of the Unconformity Caused by Huaiyuan Movement in Bohai Bay Basin, China: A Case Study of Chengdao-Zhuanghai Buried Hill in Jiyang Depression
by Ruijuan Liu, Guozhi Wang, Yongshi Wang, Xuefeng Hao, Feng Qin, Xianxu Fang, Wei Meng and Gang Liu
J. Mar. Sci. Eng. 2024, 12(5), 804; https://doi.org/10.3390/jmse12050804 (registering DOI) - 11 May 2024
Viewed by 243
Abstract
It is beneficial in terms of the theoretical significance and application prospects to define the structure and reservoir development model of the lower Paleozoic unconformity in the Jiyang Depression of Bohai Bay Basin, China, for oil and gas exploration of unconformity in carbonate [...] Read more.
It is beneficial in terms of the theoretical significance and application prospects to define the structure and reservoir development model of the lower Paleozoic unconformity in the Jiyang Depression of Bohai Bay Basin, China, for oil and gas exploration of unconformity in carbonate strata. Geological and geochemical evidence shows that a regional unconformity formed during the Huaiyuan Movement in the lower Paleozoic strata of the Jiyang Depression. Along the top of the regional unconformity between the Yeli Liangjiashan Formation and Fengshan Formation, various types of karst breccia have developed, showing prominent characteristics of development and vertical karst zonation. The paleokarst zone can be divided into the vadose zone and the underflow zone, and there are apparent differences between the two zones in terms of the mode of karst activity and type of reservoir space. Primitive sedimentary microfacies, dolomitization, and supergene karstification controlled the reservoirs of the Fengshan Formation and Yeli-Liangjiashan Formation. There are significant differences in the original physical properties due to the differences in the original sedimentary microfacies. The pore development of granular dolomite of high-energy beach facies has the best reservoir performance. In the later period, the superposition of dolomitization and supergene karstification resulted in apparent differences in karst development mode, development intensity, reservoir type, and reservoir physical properties. Among them, the granular dolomite reservoir has the best physical properties and has developed a cavity-type reservoir that has a planar distribution along an unconformity surface. Full article
(This article belongs to the Special Issue High-Efficient Exploration and Development of Oil & Gas from Ocean—2nd Edition)
19 pages, 10355 KiB  
Article
Lower Limits of Petrophysical Properties Allowing Natural Gas Accumulation in Marine Sandstones: An Example from the Qiongdongnan Basin, Northern South China Sea
by Chao Li, Shuai Guo, Qianshan Zhou, Chaochao Xu and Guojun Chen
J. Mar. Sci. Eng. 2024, 12(5), 735; https://doi.org/10.3390/jmse12050735 - 28 Apr 2024
Viewed by 355
Abstract
The lower limits of petrophysical properties for an effective reservoir are among the key parameters for assessing hydrocarbon reserves and are therefore directly related to hydrocarbon exploration and development strategies. However, the lower limits for marine sandstone gas reservoirs are still not clear [...] Read more.
The lower limits of petrophysical properties for an effective reservoir are among the key parameters for assessing hydrocarbon reserves and are therefore directly related to hydrocarbon exploration and development strategies. However, the lower limits for marine sandstone gas reservoirs are still not clear and the impact factors also remain to be discussed. This study analysed the lower petrophysical property limits of an effective sandstone reservoir in the Qiongdongnan Basin using porosity, permeability and gas testing. The results showed that the lower porosity and permeability limits of effective reservoirs developed in the deltas are 8.9% and 1.2 × 10−3 μm2, respectively, and 11.3% and 4.0 × 10−3 μm2 in the submarine canyons and fans, respectively. Sedimentary facies, sediment transport distance, grain size and burial depth of sandstone significantly influence the lower physical property limits. The lower porosity and permeability limits increase with the increase in sediment transport distance as well as the decrease in sandstone grain size and burial depth. Sediment sources and sedimentary facies determine whether sandstone can become an effective reservoir in the Qiongdongnan Basin. Specifically, the sediment source dramatically influences the petrophysical properties of sandstone. The sandstone sourced from the Red River has higher porosity and permeability, followed by the sandstone sourced from the Hainan Uplift, and the sandstone sourced from the palaeo-uplift within the basin has the lowest porosity and permeability. The feldspar dissolution by CO2 and organic acid is the primary formation mechanism of the effective reservoir in the Lingshui Formation, whereas the dissolution of glauconite is more common in the sandstone reservoirs of the Sanya and Meishan formations. Full article
(This article belongs to the Special Issue High-Efficient Exploration and Development of Oil & Gas from Ocean—2nd Edition)
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11 pages, 25015 KiB  
Article
Study on the Mechanism of Natural Gas Hydrate Decomposition and Seabed Seepage Triggered by Mass Transport Deposits
by Pengqi Liu, Wei Zhang, Shuang Mao, Pibo Su, Huaizhen Chen and Liguo Hu
J. Mar. Sci. Eng. 2024, 12(4), 646; https://doi.org/10.3390/jmse12040646 - 12 Apr 2024
Viewed by 524
Abstract
Previous studies indicate that mass transport deposits are related to the dynamic accumulation of natural gas hydrates and gas leakage. This research aims to elucidate the causal mechanism of seabed seepage in the western region of the southeastern Qiongdongnan Basin through the application [...] Read more.
Previous studies indicate that mass transport deposits are related to the dynamic accumulation of natural gas hydrates and gas leakage. This research aims to elucidate the causal mechanism of seabed seepage in the western region of the southeastern Qiongdongnan Basin through the application of seismic interpretation and attribute fusion techniques. The mass transport deposits, bottom simulating reflector, submarine mounds, and other phenomena were identified through seismic interpretation techniques. Faults and fractures were identified by utilizing variance attribute analysis. Gas chimneys were identified using instantaneous frequency attribute analysis. Free gas and paleo-seepage points were identified using sweetness attributes, enabling the analysis of fluid seepage pathways and the establishment of a seepage evolution model. Research has shown that in areas where the mass transport deposits develop thicker layers, there is a greater uplift of the bottom boundary of the gas hydrate stability zone, which can significantly alter the seafloor topography. Conversely, the opposite is true. The research indicates that the upward migration of the gas hydrate stability zone, induced by the mass transport deposits in the study area, can result in the rapid decomposition of gas hydrates. The gas generated from the decomposition of gas hydrates is identified as the principal factor responsible for inducing seabed seepage. Moderate- and low-speed natural gas seepage can create spiny seamounts and domed seamounts, respectively. Full article
(This article belongs to the Special Issue High-Efficient Exploration and Development of Oil & Gas from Ocean—2nd Edition)
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20 pages, 3024 KiB  
Article
Predicting Stick-Slips in Sheared Granular Fault Using Machine Learning Optimized Dense Fault Dynamics Data
by Weihan Huang, Ke Gao and Yu Feng
J. Mar. Sci. Eng. 2024, 12(2), 246; https://doi.org/10.3390/jmse12020246 - 30 Jan 2024
Viewed by 780
Abstract
Predicting earthquakes through reasonable methods can significantly reduce the damage caused by secondary disasters such as tsunamis. Recently, machine learning (ML) approaches have been employed to predict laboratory earthquakes using stick-slip dynamics data obtained from sheared granular fault experiments. Here, we adopt the [...] Read more.
Predicting earthquakes through reasonable methods can significantly reduce the damage caused by secondary disasters such as tsunamis. Recently, machine learning (ML) approaches have been employed to predict laboratory earthquakes using stick-slip dynamics data obtained from sheared granular fault experiments. Here, we adopt the combined finite-discrete element method (FDEM) to simulate a two-dimensional sheared granular fault system, from which abundant fault dynamics data (i.e., displacement and velocity) during stick-slip cycles are collected at 2203 “sensor” points densely placed along and inside the gouge. We use the simulated data to train LightGBM (Light Gradient Boosting Machine) models and predict the gouge-plate friction coefficient (an indicator of stick-slips and the friction state of the fault). To optimize the data, we build the importance ranking of input features and select those with top feature importance for prediction. We then use the optimized data and their statistics for training and finally reach a LightGBM model with an acceptable prediction accuracy (R2 = 0.94). The SHAP (SHapley Additive exPlanations) values of input features are also calculated to quantify their contributions to the prediction. We show that when sufficient fault dynamics data are available, LightGBM, together with the SHAP value approach, is capable of accurately predicting the friction state of laboratory faults and can also help pinpoint the most critical input features for laboratory earthquake prediction. This work may shed light on natural earthquake prediction and open new possibilities to explore useful earthquake precursors using artificial intelligence. Full article
(This article belongs to the Special Issue High-Efficient Exploration and Development of Oil & Gas from Ocean—2nd Edition)
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15 pages, 12375 KiB  
Article
Early Jurassic Gypsum within Eastern African Continental Marginal Basins and Its Significance for Gas Play
by Jun Cai and Rong Guo
J. Mar. Sci. Eng. 2024, 12(1), 93; https://doi.org/10.3390/jmse12010093 - 2 Jan 2024
Viewed by 700
Abstract
Although the eastern African continental marginal basins have discovered giant gas fields, it is not clear whether the Early Jurassic gypsum associated with the main source rocks controls the gas play. In this paper, we use well logging, seismic reflection, and organic geochemistry [...] Read more.
Although the eastern African continental marginal basins have discovered giant gas fields, it is not clear whether the Early Jurassic gypsum associated with the main source rocks controls the gas play. In this paper, we use well logging, seismic reflection, and organic geochemistry data to synthesize the distribution and origin of the gypsum deposits and their control over the gas play. The results show that from 201 Ma to 183 Ma, a thick suite of mudstone with thin-layered gypsum began to form in the southern gulf-like sea due to water stratification. With the sea level falling since 183 Ma, a thick suite of gypsum was deposited in some grabens, where the sedimentary environment changed to lagoons. The gypsum increases the maturity threshold depth of Lower Jurassic source rocks and delays the peak time of gas generation, resulting in the ongoing filling of East African natural gas reservoirs and the formation of giant reserves. In addition, the gypsum not only controls the distribution of conventional gas but also makes the Lower Jurassic shale, where the faults are not developed, an important place for shale gas exploration in the future due to the good sealing properties of the gypsum. Full article
(This article belongs to the Special Issue High-Efficient Exploration and Development of Oil & Gas from Ocean—2nd Edition)
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