Energy Geoscience最新文献

{"title":"Identification of denudation periods and thickness in petroliferous basins and their geological significance: A case study of the central Sichuan Basin","authors":"Jingdong Liu ,&nbsp;Shaohua Wang ,&nbsp;Ke Pan ,&nbsp;Chenggang Ren ,&nbsp;Qihang Zhang ,&nbsp;Jianting Xu","doi":"10.1016/j.engeos.2025.100390","DOIUrl":"10.1016/j.engeos.2025.100390","url":null,"abstract":"<div><div>Restoration of denudation thickness is of great significance to understanding tectonic evolution, hydrocarbon migration and accumulation history in petroliferous basins. How to accurately restore and distinguish denudation thicknesses in different periods, however, is difficult. With measurements of vitrinite reflectance (<em>R</em>_o) and interval transit time, along with stratigraphic profile comparison, we restored the total denudation thickness of the Cretaceous in the central Sichuan Basin at a depth range of 1100–3300 m. The apatite fission track analysis (AFTA) was employed to identify the denudation periods, namely, the Late Yanshanian, Early Himalayan and the Late Himalayan orogenic epochs, and the ratio of their denudation intensity is about 3.8:1:3.9. The denudation thicknesses at different periods provide an important basis for tectonic evolution and hydrocarbon migration and accumulation. Affected by the diverse denudation intensities, the paleo-structures in the study area feature high in the south and low in the north at the Late Jurassic, high in the north and low in the south at the late Early Cretaceous, high in the southeast and low in the northwest at present in succession. EW- and NE-trending folds and faults are the products of inherited development, which have a controlling effect on hydrocarbon migration and accumulation.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100390"},"PeriodicalIF":0.0,"publicationDate":"2025-02-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143696023","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrating geographic information system and 3D virtual reality for optimized modeling of large-scale photovoltaic wind hybrid system: A case study in Dakhla City, Morocco","authors":"Elmostafa Achbab ,&nbsp;Rachid Lambarki ,&nbsp;Hassan Rhinane ,&nbsp;Dennoun Saifaoui","doi":"10.1016/j.engeos.2025.100389","DOIUrl":"10.1016/j.engeos.2025.100389","url":null,"abstract":"<div><div>This research pioneers the integration of geographic information systems (GIS) and 3D modeling within a virtual reality (VR) framework to assess the viability and planning of a 20 MW hybrid wind-solar-photovoltaic (PV) system connected to the local grid. The study focuses on Dakhla, Morocco, a region with vast untapped renewable energy potential. By leveraging GIS, we are innovatively analyzing geographical and environmental factors that influence optimal site selection and system design. The incorporation of VR technologies offers an unprecedented level of realism and immersion, allowing stakeholders to virtually experience the project's impact and design in a dynamic, interactive environment. This novel methodology includes extensive data collection, advanced modeling, and simulations, ensuring that the hybrid system is precisely tailored to the unique climatic and environmental conditions of Dakhla. Our analysis reveals that the region possesses a photovoltaic solar potential of approximately 2400 kWh/m² per year, with an average annual wind power density of about 434 W/m² at an 80-meter hub height. Productivity simulations indicate that the 20 MW hybrid system could generate approximately 60 GWh of energy per year and 1369 GWh over its 25-year lifespan. To validate these findings, we employed the System Advisor Model (SAM) software and the Global Solar Photovoltaic Atlas platform. This comprehensive and interdisciplinary approach not only provides a robust assessment of the system's feasibility but also offers valuable insights into its potential socio-economic and environmental impact.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100389"},"PeriodicalIF":0.0,"publicationDate":"2025-02-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143601680","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quantitative characterization of permeability heterogeneity of tight-sand reservoirs using nano-CT technology: A case study of the Yanchang Formation, Ordos Basin","authors":"Junlong liu ,&nbsp;Xiangchun Zhang","doi":"10.1016/j.engeos.2025.100388","DOIUrl":"10.1016/j.engeos.2025.100388","url":null,"abstract":"<div><div>The physical properties of hydrocarbon reservoirs are important factors affecting the percolation ability of the reservoirs. Tight-sand reservoirs exhibit complex pore throat connectivity due to the extensive development of micro- and nano-scale pore and throat systems. Characterizing the microscopic properties of these reservoirs using nondestructive, quantitative methods serves as an important means to determine the characteristics of microscopic pores and throats in tight-sand reservoirs and the mechanism behind the influence of these characteristics on reservoir porosity and permeability. In this study, a low-permeability sandstone sample and two tight sandstone samples collected from the Ordos Basin were nondestructively tested using high-resolution nano-CT technology to quantitively characterize their microscopic pore throat structures and model them three-dimensionally (in 3D) based on CT threshold differences and gray models. A thorough analysis and comparison reveal that the three samples exhibit a certain positive correlation between their porosity and permeability but the most important factor affecting both porosity and permeability is the microscopic pore throat structure. Although the number of pores in tight sandstones shows a minor impact on their porosity, large pores (more than 20 μm) contribute predominantly to porosity, suggesting that the permeability of tight sandstones is controlled primarily by large pore throats. For these samples, higher permeability corresponds to larger average throat sizes. Therefore, throats with average radii greater than 2 μm can significantly improve the permeability of tight sandstones.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100388"},"PeriodicalIF":0.0,"publicationDate":"2025-02-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143705526","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Gas geochemistry evaluation of onshore Colombian basins: New insights for natural gas and liquified petroleum gas prospectivity","authors":"César Mora ,&nbsp;Antonio Rangel ,&nbsp;Mauricio A Bermúdez ,&nbsp;Gleubis Belén Silveira Moreno ,&nbsp;Claudia Posada","doi":"10.1016/j.engeos.2025.100387","DOIUrl":"10.1016/j.engeos.2025.100387","url":null,"abstract":"<div><div>This study examines the molecular and isotopic composition of 193 gas samples collected from oil and gas fields across Colombia's onshore basins with active hydrocarbon production. Comparative analyses were conducted on both isotopic and molecular compositions across the Lower Magdalena Basin (LMB), Middle Magdalena Basin (MMB), Upper Magdalena Basin (UMB), Putumayo Caguán Basin (PUTCAB), Catatumbo Basin (CATB), Eastern Llanos Basin (LLAB), and Eastern Cordillera Basin (ECB). The primary objectives were to classify the gases produced, characterize their origins, assess transformation processes such as biodegradation and migration, and analyze the statistical distribution patterns of their components. This geochemical characterization aims to support the discovery of new reserves for both natural gas (NG) and liquefied petroleum gas (LPG), given Colombia's potential risk of diminished energy self-sufficiency in gas resources. The basins under study produce dry gas, wet gas, and liquefied petroleum gas (LPG/C₃₊), all associated with oil and gas fields of commercial hydrocarbon production. Notably, the LLAB contains the highest proportions of heavy isotopic carbon and C₃₊ (LPG) concentrations, whereas LMB is characterized by isotopically lighter methane, indicative of dry gas predominance. Results suggest a predominantly thermogenic origin for the gases studied, generated within the oil and gas windows, with several samples originating from secondary oil cracking, while some samples from LMB display a likely biogenic origin. Additionally, evidence of gas migration and biodegradation was observed in a significant subset of samples. The analysis of statistical distributions and compositional trends reveals a prevalent high methane content, with substantial C₂-C₅ (C₂₊) gas concentrations across all basins studied. This composition underscores the potential for both natural gas (NG) and LPG production. The C₃₊ (LPG) content varies between 1 % and 92 %, with 35 % of the samples containing less than 5 % LPG. High original gas-in-place (OGIP) volumes and substantial LPG content in the Eastern Llanos foothills, encompassing fields such as Cusiana and Cupiagua, highlight the prospective potential of this region. Near-field exploration could further add reserves of both NG and LPG.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100387"},"PeriodicalIF":0.0,"publicationDate":"2025-02-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143610614","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quantitative characterization and vertical evolution of fan delta sand bodies: A case study of the Liushagang Formation in the Weixi'nan sag, China","authors":"Mingjun Li ,&nbsp;Chuang Er ,&nbsp;Lei Li ,&nbsp;Liang Zhang ,&nbsp;Tao Fu ,&nbsp;Jian Man ,&nbsp;Congmin Shen","doi":"10.1016/j.engeos.2025.100384","DOIUrl":"10.1016/j.engeos.2025.100384","url":null,"abstract":"<div><div>The study on sand body connectivity and distribution patterns is of great significance for well emplacement and injection-production pattern analysis in the A oilfield of the Weixi'nan Sag currently at a pre-development stage. Based on the current drilling data, seismic data, and fault development characteristics, this study investigates the connectivity, geometric morphology, planar distribution, and vertical evolution of composite sand bodies (multi-stage superimposed channel sand bodies) within the fault block using seismic forward and inversion modeling. The E<em>l</em>₃Ⅰ oil layer group in the third member of the Liushagang Formation is developed in the fan delta-front sub-facies, which mainly consists of subaqueous distributary channels. The thickness of single-stage subaqueous distributary channel sand bodies ranges from 2 to 6 m, and the width of composite channel sand bodies varies from 50 to 100 m. Under the long-term transgression background, the subaqueous distributary channels in the E<em>l</em>₃Ⅰ oil layer group are relatively narrow, forming superimposed and continuous composite channel sand bodies through lateral migration and vertical stacking. The long-term base-level cycles control the width of subaqueous distributary channels, while the mid-term base-level cycles control the thickness of these channels. The subaqueous distributary channels developed during the late stage of mid-term base-level fall are thicker than those formed during the early stage. Accordingly, quantitative relationships between channel thickness and width are established for the early and late stages of mid-term base-level fall, to finely depict the evolution patterns of channel sand body geometry and stacking styles across different stages. These findings provide important guidance for accurately predicting the planar distribution and channel width of composite subaqueous distributary channels at different stages of the mid-term base-level cycles.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100384"},"PeriodicalIF":0.0,"publicationDate":"2025-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143594260","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Seismic and petrophysical data analysis for geological interpretation and subsurface modeling of Keva Field, onshore Niger Delta, Nigeria","authors":"Kembou Tsobin Evans ,&nbsp;Olawale Olakunle Osinowo ,&nbsp;Wasiu Odufisan ,&nbsp;Bashir A. Koledoye ,&nbsp;Yusuf Odusanwo ,&nbsp;Tobechukwu Oluchukwu Ude-Akpeh ,&nbsp;Glory Yenchek Tiele","doi":"10.1016/j.engeos.2025.100382","DOIUrl":"10.1016/j.engeos.2025.100382","url":null,"abstract":"<div><div>This study integrates seismic and petrophysical data to evaluate the subsurface geology of the Keva Field, located onshore in the Niger Delta, with the objective of constructing a 3D geological model and estimating the recoverable hydrocarbon volumes. Seismic lines and well log data from six wells—KV-2, KV-3, KV-4, KV-5, KV-6, and KV-7—were utilized for the interpretation. The seismic profiles revealed that the KV-4 well is the only well drilled on the up-thrown side of a significant horst fault block, bounded by four major normal faults, while all the other wells penetrated the downthrown side. Petrophysical analysis identified three key reservoirs, C500, D200, and E900, which exhibit excellent reservoir quality with high net-to-gross ratios, good porosity, and high hydrocarbon saturation. The identified depositional environments are tidal- and fluvial-dominated shoreface settings, with sheet sands deposited in distributary splay systems. The C500, D200, and E900 reservoirs have Gas Initially in Place (GIIP) values of 156.37, 28.44, and 27.89 BSCF, respectively, with corresponding Estimated Ultimate Recovery (EUR) values of 104.77, 19.06, and 18.69 BSCF, respectively. The Stock Tank Original Oil in Place (STOOIP) values are 24.43, 91.29, and 86.41 MMSTB, with EURs of 7.32, 27.4, and 25.92 MMSTB, respectively. The combined GIIP is 212.72 BSCF with EUR of 142.52 BSCF, while the total STOOIP is 202.13 MMSTB with a recoverable volume of 60.64 MMSTB. The reservoirs present an average porosity of 22.62 %, with gas saturation of 84.66 % and oil saturation of 73 %. The evaluated reservoir qualities suggest high potential for optimized hydrocarbon production.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100382"},"PeriodicalIF":0.0,"publicationDate":"2025-02-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143419064","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Machine learning-based prediction of physical parameters in heterogeneous carbonate reservoirs using well log data","authors":"Fuyong Wang ,&nbsp;Xianmu Hou","doi":"10.1016/j.engeos.2025.100383","DOIUrl":"10.1016/j.engeos.2025.100383","url":null,"abstract":"<div><div>This study explores the application of machine learning techniques for predicting permeability, porosity, and flow zone indicator (FZI) in carbonate reservoirs using well log data, aiming to overcome the limitations of traditional empirical methods. Six machine learning algorithms are utilized: support vector machine (SVM), backpropagation (BP) neural network, gaussian process regression (GPR), extreme gradient boosting (XGBoost), K-nearest neighbor (KNN), and random forest (RF). The methodology involves classifying pore-permeability types based on the flow index, leveraging logging curves and geological data. Models are trained using seven logging parameters—spectral gamma rays (SGR), uranium-free gamma rays (CGR), photoelectric absorption cross-section index (PE), lithologic density (RHOB), acoustic transit time (DT), neutron porosity (NPHI), and formation true resistivity (RT)—along with corresponding physical property labels. Machine learning models are trained and evaluated to predict carbonate rock properties. The results demonstrate that GPR achieves the highest accuracy in porosity prediction, with a coefficient of determination (<em>R</em>²) value of 0.7342, while RF proves to be the most accurate for permeability prediction. Despite these improvements, accurately predicting low-permeability zones in heterogeneous carbonate rocks remains a significant challenge. Application of cross-validation techniques optimized the performance of GPR, resulting in an accuracy index (<em>ACI</em>) value of 0.9699 for porosity prediction. This study provides a novel framework that leverages machine learning techniques to improve the characterization of carbonate reservoirs.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100383"},"PeriodicalIF":0.0,"publicationDate":"2025-02-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143445244","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Determining CO₂ front in CO₂-EOR using a well-testing method","authors":"Jinghong Li ,&nbsp;Chuanzhi Cui ,&nbsp;Junkang Wang ,&nbsp;Yueru Zhang ,&nbsp;Guoqiang Li ,&nbsp;Youquan Li ,&nbsp;Hongbo Li ,&nbsp;Fengrui Han","doi":"10.1016/j.engeos.2025.100385","DOIUrl":"10.1016/j.engeos.2025.100385","url":null,"abstract":"<div><div>CO₂ flooding is a widely recognized method for enhanced oil recovery (EOR). This study aims to develop an accurate prediction method for determining the location and migration pathway of CO₂ front, which plays an essential role in designing effective CO₂ injection schemes and optimizing production strategies. Given the challenges of directly monitoring CO₂ front movement in subsurface reservoirs, numerical well testing serves as an effective tool for indirectly inferring the location and migration characteristics of the CO₂ front. This study established a numerical well-testing model based on a compositional framework to characterize interactions among multiple components during CO₂ flooding. The methodology used in this model involves generating well-testing curves of CO₂ flooding and then determining their flow stages based on CO₂ distribution within reservoirs. Accordingly, a new well-testing analysis approach was proposed to determine the CO₂ zone front and mixing zone front. This approach was applied to a pilot study of a practical oilfield, where it effectively predicted the positions of both fronts. The findings of this study reveal that the CO₂ zone front and the mixing zone front correspond to the beginning of the first horizontal segment and the endpoint of the upward segment in the pressure derivative curve, respectively. This study introduces a cost-effective and time-efficient method for CO₂ front monitoring, addressing the challenges of high costs and prolonged durations typically associated with CO₂-EOR operations.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100385"},"PeriodicalIF":0.0,"publicationDate":"2025-02-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143563647","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The control of differential tectonics on the formation of deep reservoirs in lacustrine rift basins: An insight of the Bodong Low Uplift in the Bohai Bay Basin, East China","authors":"Qunfeng Ding ,&nbsp;Yuhang Chen ,&nbsp;Lei Chen ,&nbsp;Lei Gao ,&nbsp;Shaofeng Bu ,&nbsp;Yuxing Liu ,&nbsp;Dongye Ma ,&nbsp;Rongjun Zhang ,&nbsp;Lijun Song ,&nbsp;Le Qu","doi":"10.1016/j.engeos.2025.100381","DOIUrl":"10.1016/j.engeos.2025.100381","url":null,"abstract":"<div><div>Tectonic activities significantly impact deep reservoir properties via sedimentary and diagenetic processes, and this is particularly true for lacustrine rift basins. The tectonic-sedimentary-diagenetic-reservoir system is crucial in deep reservoir exploration. This study examined the first member and upper submember of the second member of the Dongying Formation in the Bodong Low Uplift in the Bohai Bay Basin (East China), documenting the petrologic features and physical properties of reservoirs in different tectonic sub-units through integrated analysis of log and rock data, along with core observation. A mechanism for deep reservoir formation in lacustrine rift basins was developed to elucidate the sedimentary and diagenetic processes in complex tectonic settings. The results show that tectonic activities result in the occurrence of provenances in multiple directions and the existence of reservoirs at varying burial depths, as well as the significant diversity in sedimentary and diagenetic processes. The grain sizes of the sandstones, influenced by transport pathways rather than the topography of the sedimentary area, exhibit spatial complexity due to tectonic frameworks, which determine the initial pore content of reservoirs. However, the burial depth, influenced by subsequent tectonic subsidence, significantly impacts pore evolution during diagenesis. Based on the significant differences of reservoirs in slope zone, low uplift and depression zone, we establish different tectonic-diagenetic models in deep complex tectonic units of lacustrine rift basins.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100381"},"PeriodicalIF":0.0,"publicationDate":"2025-02-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143428643","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"OFC","authors":"","doi":"10.1016/S2666-7592(24)00087-8","DOIUrl":"10.1016/S2666-7592(24)00087-8","url":null,"abstract":"","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 1","pages":"Article 100372"},"PeriodicalIF":0.0,"publicationDate":"2025-01-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143156089","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}