Energy Geoscience最新文献

{"title":"Numerical simulations of geological CO2 storage in a gas reservoir of the B depression, Pearl River Mouth Basin","authors":"Chen Wang ,&nbsp;Shaocheng Luo ,&nbsp;Yu Mou ,&nbsp;Jianhui Zeng ,&nbsp;Yawen Ren ,&nbsp;Chengfei Guo","doi":"10.1016/j.engeos.2025.100512","DOIUrl":"10.1016/j.engeos.2025.100512","url":null,"abstract":"<div><div>Geological CO₂ storage is a promising strategy for reducing greenhouse gas emissions and has become a growing focus of research and deployment. This paper presents numerical simulations of CO₂ injection and storage in a depleted gas reservoir within the B Depression and evaluates associated CO₂ trapping mechanisms. In the base case, a constant injection rate of 3500.00 m³/d over fifteen years resulted in a cumulative injection of 19.2 × 10⁶ m³. The CO₂ plume expanded radially during injection and subsequently migrated up-dip under buoyancy forces. The final stored mass of CO₂ in the reservoir was 10.6 million tonnes (MT), representing less than 10% of its theoretical capacity. The plume was projected to reach the entrapment crest and the top of the reservoir within a century, indicating secure long-term containment. Structural, stratigraphic, and residual trapping dominate in Reservoir A (approximately 90%). Anticlinal closures with thick overlying mudstones in the Zhujiang Formation provide effective seals, further enhancing storage security. Reservoir properties and heterogeneity play a crucial role in controlling CO₂ storage. However, reservoir heterogeneity exerts only a limited influence when intrinsic properties are favorable. Overall, the study and implementation of CO₂ capture, utilization, and storage (CCUS) in China's offshore basins show promising prospects.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"7 1","pages":"Article 100512"},"PeriodicalIF":3.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145736437","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Fault sealing evolution in complex fault zones of the Houxia Basin, China","authors":"Sujie Yan ,&nbsp;Yunwen Guan ,&nbsp;Peng Wu ,&nbsp;Renhai Pu","doi":"10.1016/j.engeos.2025.100510","DOIUrl":"10.1016/j.engeos.2025.100510","url":null,"abstract":"<div><div>Fault sealing capacity is controlled by present-day geometry and clay content, with current research focusing on enhancing the accuracy of capacity estimates. The mechanisms for evaluating both present-day and paleo-sealing are consistent, where the current sealing capacity representing the final stage in the evolutionary process of fault sealing. To address the limitations of the conventional shale gouge ratio (<em>SGR</em>) in evaluating the dynamic nature of fault sealing, this study proposes a visual model for fault sealing evolution. Fault sealing evolution is jointly controlled by the burial history and clay smear history and exerts a critical influence on hydrocarbon migration and accumulation. Hydrocarbon exploration data confirm that fault sealing during and after hydrocarbon migration critically impacts reservoir preservation. If faults remain unsealed during hydrocarbon migration and accumulation, they serve solely as conduits, with their present-day sealing capacity having limited impact. Effective fault sealing thus depends on the alignment between the evolutionary sealing stages and hydrocarbon activity. Building on this framework, we propose a method to visually and quantitatively characterize the fault sealing evolution alongside hydrocarbon activity. A case study of the Xishanyao Formation in the Houxia Basin highlights that the F4 fault transitioned from being over-open to sealed at the onset of hydrocarbon migration, thereby preserving the trap, while the F8-2 fault underwent a complete sealed–reopen cycle, with the late-stage reopening leading to an absence of hydrocarbon accumulation. This temporal contrast forms the basis for a new time-sensitive methodology for assessing fault-seal integrity in complex structural settings.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"7 1","pages":"Article 100510"},"PeriodicalIF":3.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145736318","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Physical property characteristics and controlling factors of shale oil reservoirs in the Beibuwan Basin, southern China","authors":"Yuejiao Liu ,&nbsp;Jianmeng Sun ,&nbsp;Fuqiang Lai ,&nbsp;Xu Dong ,&nbsp;Dong Yang ,&nbsp;Jiajie Cheng","doi":"10.1016/j.engeos.2025.100504","DOIUrl":"10.1016/j.engeos.2025.100504","url":null,"abstract":"<div><div>The Liushagang Formation in the Weixinan Depression, Beibuwan Basin, southern China, is one of the key stratigraphic units for offshore shale oil exploration in the country. The shale oil reservoirs in the formation are characterized by low porosity, low permeability and strong heterogeneity, which constrain the precise evaluation of reservoir properties, the accurate prediction of sweet spots, and efficient development. This study integrates core observation, mineralogical analysis, and multi-scale pore characterization to systematically clarify the variations in reservoir properties and their controlling mechanisms. The results show that the physical properties of matrix-type, lamina-type, and interlayer-type reservoirs exhibit distinct stepwise variations: Among these, interlayer-type reservoirs show the greatest development potential (quartz content 65%, average porosity 15%, permeability &gt;10 mD, and mobile fluid saturation 60%), whereas matrix-type reservoirs are the least favorable (dominated by 40 nm nanoscale pores, and clay content 45%). Mineral composition, sedimentary-diagenetic processes, and fault systems collectively control reservoir property heterogeneity. Quartz-rich rigid frameworks resist compaction, resulting in a porosity increase by approximately 2% for every 10% rise in quartz content. The transformation of clay minerals induces stratified porosity zoning within the layered reservoirs, while fault systems enhance heterogeneity through the development of fracture networks and acid-induced dissolution. This study provides theoretical support for the evaluation and development of shale oil sweet spots in the Weixinan Depression and holds practical significance for the commercial development of shale oil in China's offshore areas.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"7 1","pages":"Article 100504"},"PeriodicalIF":3.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145618282","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Unconventional rare earth element archives in the energy transition era: The Cenozoic organic sediments from west coast of southern India","authors":"P. Athira Chandran ,&nbsp;Arunima M. Lal ,&nbsp;Arun J. John ,&nbsp;G.K. Indu ,&nbsp;Ajai M. Lal ,&nbsp;Runcie Paul Mathews ,&nbsp;M. Santosh ,&nbsp;S. Rajesh ,&nbsp;P.E. Binusarma","doi":"10.1016/j.engeos.2025.100507","DOIUrl":"10.1016/j.engeos.2025.100507","url":null,"abstract":"<div><div>Organic-rich sediments represent vital components of Earth's geochemical cycles, acting both as potential hydrocarbon and coal reservoirs and as unconventional archives for critical metals such as rare earth elements (REEs). With the growing emphasis on clean energy technologies, the Cenozoic organic deposits of India have gained renewed significance; however, those from the southern state of Kerala remain understudied. This study investigates lignite and associated carbonaceous sediments from the Cheruvathur and Warkalli Formations using a multi-proxy approach integrating organic petrography, infrared spectroscopy, stable carbon isotopes, and REE geochemistry. The lignite exhibits huminite dominance with Type III kerogen, deposited in a wet, mesotropic bog forest swamp under anoxic conditions. The mineral assemblage, dominated by kaolinite, quartz, illite, montmorillonite, feldspar, and pyrite/marcasite, reflects strong chemical alteration in a reducing environment. The δ¹³C values (−25.1‰ to −27.3‰) indicate a C₃ angiosperm source and deposition in tropical to subtropical swamp settings. REE patterns reveal LREE enrichment in carbonaceous shales and HREE enrichment in lignite, with distinct Ce, Eu, and Gd anomalies associated with provenance and redox conditions. The findings provide new insights into the paleoenvironmental evolution of Kerala's Cenozoic basins and highlight their potential as unconventional REE-bearing resources in the context of the global energy transition.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"7 1","pages":"Article 100507"},"PeriodicalIF":3.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145736436","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Characteristics of carbon emission point sources and industry analysis in the Guangdong-Hong Kong-Macau Greater Bay Area","authors":"Ying Teng ,&nbsp;Jiajie Li ,&nbsp;Yiqi Chen ,&nbsp;Meiyu Guo ,&nbsp;Tian Gao ,&nbsp;Ji Kong ,&nbsp;Yuze Wang ,&nbsp;Pengfei Wang ,&nbsp;Jinlong Zhu ,&nbsp;Songbai Han ,&nbsp;Senyou An ,&nbsp;Jianbo Zhu ,&nbsp;Heping Xie","doi":"10.1016/j.engeos.2025.100437","DOIUrl":"10.1016/j.engeos.2025.100437","url":null,"abstract":"<div><div>Carbon Capture, Utilization, and Storage (CCUS) technology has gained widespread attention in recent years as a critical strategy to combat global climate change, particularly in achieving carbon neutrality goals. The Guangdong-Hong Kong-Macau Greater Bay Area (GBA), as one of China's most economically active regions, serves as a key engine for economic growth while also facing considerable carbon emission challenges. This study analyzes the industrial emission volume and geographical distribution of key emitting enterprises in the GBA, summarizes their technological processes and main carbon-emitting equipment, and provides scientific support for precise mitigation policies and low-carbon development. Based on data from 176 key emitting enterprises, the study reveals that Guangzhou and Dongguan host the largest number of such enterprises. Carbon emissions are primarily concentrated in the power sector, dominated by coal- and gas-fired power units, characterized by significant spatial dispersion and uneven distribution. Beyond the power sector, the paper industry has a high number of enterprises but lower emissions. Key facilities such as boilers, cogeneration systems, and production lines are predominantly located near tributaries rivers in Dongguan and Jiangmen. The building materials sector, primarily cement production, ranks as the second-largest emitter, with high-temperature kilns and grinding equipment, particularly rotary kilns and glass furnaces, as the main sources. The petrochemical and chemical sectors have fewer enterprises and lower emissions in the GBA, mainly located in suburban industrial clusters. Carbon emissions in the GBA exhibit distinct industry concentration and geographical distribution disparities. This study provides crucial data and theoretical insights for the development of targeted emission reduction strategies, optimization of source-sink matching, and the advancement of CCUS technologies in the region, particularly from the GBA to the northern South China Sea.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"7 1","pages":"Article 100437"},"PeriodicalIF":3.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"146172626","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Big data-driven analysis of shale gas enrichment patterns: A case study of the Wufeng–Longmaxi Formation in the Sichuan Basin and its periphery","authors":"Zongquan Hu ,&nbsp;Jin Meng ,&nbsp;Wei Du ,&nbsp;Yitian Xiao ,&nbsp;Chuanxiang Sun ,&nbsp;Guanping Wang ,&nbsp;Baojian Shen ,&nbsp;Tianrui Ye ,&nbsp;Dongjun Feng ,&nbsp;Zengqin Liu ,&nbsp;Longfei Lu ,&nbsp;Ruyue Wang ,&nbsp;Qianru Wang","doi":"10.1016/j.engeos.2025.100476","DOIUrl":"10.1016/j.engeos.2025.100476","url":null,"abstract":"<div><div>The Wufeng–Longmaxi Formation derives its name from the Upper Ordovician Wufeng Formation and the Lower Silurian Longmaxi Formation, found in sequence in the Sichuan Basin. This formation hosts rich shale gas reservoirs, and its shale gas enrichment patterns are examined in this study using data from 1197 shale samples collected from 14 wells. Five basic and three key parameters, eight in all, are assessed for each sample. The five basic parameters include burial depth and the contents of four mineral types—quartz, clay, carbonate, and other minerals; the three key parameters, representing shale gas enrichment, are total organic carbon (TOC) content, porosity, and gas content. The SHapley Additive exPlanations (SHAP) analysis originated in game theory is used here in an interpretable machine learning framework, to address issues of heterogeneous data structure, noisy relationships, and multi-objective optimization. An evaluation of the ranking, contribution values, and conditions of changes for these parameters offers new quantitative insights into shale gas enrichment patterns. A quantitative analysis of the relationship between data-sets identifies the primary factors controlling <em>TOC</em>, porosity, and gas content of shale gas reservoirs. The results show that <em>TOC</em> and porosity jointly influence gas content; mineral content has a significant impact on both, <em>TOC</em> and porosity; and the burial depth governs porosity which, in turn, affects the conditions under which shale gas is preserved. Input parameter thresholds are also determined and provide a basis for the establishment of quantitative criteria to evaluate shale gas enrichment. The predictive accuracy of the model used in this study is significantly improved by the step-wise addition of two input parameters, namely <em>TOC</em> and porosity, separately and together. Thus, the game theory method in big data-driven analysis uses a combination of <em>TOC</em> and porosity to evaluate the gas content with encouraging results—suggesting that these are the key parameters that indicate source rock and reservoir properties.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"7 1","pages":"Article 100476"},"PeriodicalIF":3.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"146172625","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Carbon dioxide plumes, pressure space and legacy well risk for Southern North Sea CO2 storage projects","authors":"Alexandra Smith ,&nbsp;Gary Hampson ,&nbsp;Iman Rahimzadeh Kivi ,&nbsp;Sam Krevor","doi":"10.1016/j.engeos.2025.100475","DOIUrl":"10.1016/j.engeos.2025.100475","url":null,"abstract":"<div><div>Unsecured legacy wells pose significant risks to carbon capture and storage (CCS) as they present potential leakage pathways for stored CO₂ to return to the atmosphere. In the UK, legacy wells must be assessed for a carbon storage permit to be granted and high-risk wells require costly remediation. We use a well risk assessment scheme to evaluate the risk of wells in the Southern North Sea. We then combine our well risk assessment with investigation using the analytical tool CO2BLOCK, which relies on a gravity current model to estimate pressure and plume migration distances. We evaluate the Viking, Camelot and Poseidon projects, which plan to inject CO₂ into the depleted reservoirs of Southern North Sea gas fields. Carbon dioxide plumes are typically several kilometers wide, and it should be possible to avoid plume migration to high-risk legacy wells. In contrast, pressure fields produced by CO₂ injection are tens of kilometers wide and low magnitude pressure increases frequently extend beyond the bounds of storage licence areas. The pressure fields encounter hundreds of wells and in the cases of the Camelot and Poseidon projects, interact with each other.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"7 1","pages":"Article 100475"},"PeriodicalIF":3.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145398604","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Microscopic pore combination type identification of tight sandstone reservoir based on improved swin transformer architecture","authors":"Zhenyu Pang ,&nbsp;Zhicong Chen ,&nbsp;Sijie Lu ,&nbsp;Zhenbo Cai ,&nbsp;Yuqing Lu ,&nbsp;Mengting Peng","doi":"10.1016/j.engeos.2025.100450","DOIUrl":"10.1016/j.engeos.2025.100450","url":null,"abstract":"<div><div>Tight sandstone reservoirs differ fundamentally from conventional medium to high permeability reservoirs due to their complex and heterogeneous microscopic pore structures. This complexity poses significant challenges for accurate reservoir characterization and often results in suboptimal development performance. The specific configuration of microporosity combinations plays a decisive role in determining the storage and seepage capacities of tight sandstone reservoirs. Therefore, the precise identification of microporosity combination types is essential for improving both reservoir evaluation accuracy and development effectiveness. However, traditional computer vision models exhibit limitations in capturing fine-grained textures and spatial relationships among microscopic pores with complex morphologies, leading to inadequate generalization capabilities. To address these issues, this study proposes an enhanced Swin Transformer-based neural network architecture, termed SwinLSC (Swin Transformer with Linformer and Self-Adaptive Channel Attention). The model incorporates a global-local attention mechanism and is trained on image datasets of cast thin sections from tight sandstone reservoirs in the Yanchang Oilfield. To evaluate model performance, <em>Top-1 Accuracy</em>, <em>Loss</em>, and <em>Recall</em> metrics were employed, and the SwinLSC model was benchmarked against three mainstream architectures: Swin Transformer, Vision Transformer (ViT), and ResNet. Experimental results demonstrate that SwinLSC achieves a prediction accuracy of 93.3 %, significantly outperforming the comparative models. These findings indicate that the SwinLSC model effectively addresses the generalization deficiencies of conventional approaches in recognizing microstructural features in cast thin section imagery. Consequently, it offers a robust and accurate solution for microporosity type identification, thereby providing reliable technical support for the efficient exploration and development of tight sandstone reservoirs.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100450"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144830216","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quantitative recognition and petroleum geological significance of interlayers in coastal sandstone reservoirs: A case study from the Donghe Sandstone in the Hade Oilfield, Tarim Basin, NW China","authors":"Rui Yuan ,&nbsp;Chenlong Lu ,&nbsp;An Zhao ,&nbsp;Wei Wang ,&nbsp;Zhiwei Wu ,&nbsp;Zijin Yan ,&nbsp;Qi Sun","doi":"10.1016/j.engeos.2025.100439","DOIUrl":"10.1016/j.engeos.2025.100439","url":null,"abstract":"<div><div>Buried coastal sandstones would be of high-quality hydrocarbon reservoirs. Controlled by deposition and diagenesis, coastal sandstones mixed with muddy and calcareous materials are usually low in porosity and permeability and small in layer thickness. These impermeable interlayers act as baffles and barriers between flow units and are crucial in hydrocarbon development. Donghe Sandstone in the Hade Oilfield of Tarim Basin, NW China, belongs to coastal clastic reservoirs of high oil productivity. Following nearly 30 years of development, the distribution of remaining hydrocarbon resources is affected by the muddy, calcareous, and marlaceous interlayers. Taking the Donghe Sandstone as an example, a quantitative recognition method of interlayers in coastal sandstone reservoirs is proposed in this paper. Based on cores from 26 wells, the sensitive conventional log curves of different interlayers, namely the natural gamma-ray (GR), density (DEN), compensated neutron (CNL), and acoustic (AC), are extracted by the Extreme Gradient Boosting (XGBoost). Multi-mineral model (MMM) is used to calculate continuous curves for muddy, sandy, and calcareous contents by the mentioned sensitive logs. A set of quantitative standard system is established for identifying muddy, calcareous, and marlaceous interlayers based on their respective contents. The types of interlayers are identified across all vertical wells. The interlayers exhibit lateral continuity at the top of each bed-set. Interlayers are currently more developed in the slope region than in the coastal region. Muddy and marlaceous interlayers are more developed at high relative sea-level, while calcareous interlayers are more developed at low relative sea-level. The extended interlayers at the top of BS6 lead to two different oil-water contacts in the Donghe Sandstone. The proposed quantitative recognition method for interlayers provides valuable insights into the exploitation potential of petroleum systems in the Donghe Sandstone of the Hade Oilfield. The flexible and easy-to-use method can be applied to other marine sandstone reservoirs or similar formations.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100439"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145157947","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrated field characterization and static hydrocarbon reserve estimation of the Penobscot Field, Nova Scotia, Canada","authors":"Ahmed Eleslambouly ,&nbsp;Tarek Khalifa ,&nbsp;Omar Aldhanhani ,&nbsp;Mursal Zeynalli ,&nbsp;Ahmed Abdelmaksoud","doi":"10.1016/j.engeos.2025.100448","DOIUrl":"10.1016/j.engeos.2025.100448","url":null,"abstract":"<div><div>The Penobscot Field, located within the Scotian Basin offshore Nova Scotia, Canada, represents an underexplored hydrocarbon field with potential for future development. Previous studies have been confined to specific reservoir intervals without integrating multiple stratigraphic levels, and a comprehensive static reservoir characterization and volumetric assessment of the Penobscot Field has yet to be undertaken, constraining its full development evaluation. This study presents a comprehensive characterization of the field by integrating geological, geophysical, and petrophysical datasets, leading to static hydrocarbon reserve estimation. The workflow involves seismic interpretation, structural modeling, petrophysical evaluation, and static volumetric calculations. Seismic analysis revealed a structurally complex setting dominated by normal and inverted faults, with reservoir intervals primarily within the Missisauga Formation, which is subdivided into upper, middle, and lower units. Petrophysical evaluation from well logs and core data identified key reservoir properties, including porosity ranging from 12 % to 28 %, permeability spanning from 1 to 1000 mD, and variable water saturations. Stochastic modeling of facies and petrophysical attributes provided insights into lateral and vertical heterogeneity. The Penobscot Field's original oil-in-place ranges from 41.6 × 10⁶ m³ to 109.7 × 10⁶ m³, with the Middle Missisauga sands presenting the highest reservoir potential. Fault seal analysis indicated predominantly sealing behavior in the shallow sections and semi-permeable conditions at greater depths, suggesting potential lateral migration pathways. The results underscore the field's hydrocarbon potential while emphasizing the significance of structural complexity, facies distribution, and petrophysical variability in reservoir quality, as well as its potential for future development or utilization of similar sand reservoirs for CO₂ storage utilization. This work provides the first fully integrated static reservoir model of the Penobscot Field, offering critical insights for delineating the hydrocarbon reservoirs potential and future production strategies in the Scotian Basin.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100448"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144830215","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}