Journal of Petroleum Geology最新文献

{"title":"Prospectivity of Passive Margin Turbidite Fans: Implications of an Unconventional Resource, Hydrocarbon Storage Capacity, and Tectonic Evolution, Rio Del Rey Basin, Cameroon","authors":"Mbouemboue Nsangou Moussa Ahmed,&nbsp;Anatole Eugene Djieto Lordon,&nbsp;Olugbengha Ajayi Ehinola,&nbsp;Binyet Joseph,&nbsp;Marie Joseph Ntamak Nida","doi":"10.1111/jpg.70024","DOIUrl":"https://doi.org/10.1111/jpg.70024","url":null,"abstract":"<div>\u0000 \u0000 <p>The Rio del Rey Basin, situated at the easternmost extension of the Niger Delta in the Gulf of Guinea, remains one of the least explored deep-water provinces, despite its proven petroleum system and structural affinity with the prolific neighboring basins. This study integrates well-log interpretation, petrophysical evaluation, and seismic stratigraphy to assess the depositional architecture and hydrocarbon prospectivity of slope-to-basin-floor turbidite systems within two exploratory wells (Idabato and Ifiari East) and regional 2D seismic profiles. Petrophysical analysis using Interactive Petrophysics software indicates that middle Miocene sand-rich intervals exhibit favorable reservoir properties, with effective porosity ranging from 20% to 35% and permeability locally exceeding 400 mD. Total organic carbon (TOC) values derived from log-based ΔlogR modeling range between 1.6 and 8.4 wt%, confirming the presence of organic-rich shales capable of sourcing hydrocarbons. Cross-plot analyses (neutron–density and sonic–density) reveal three dominant lithofacies: clean turbiditic sands, shaly sands, and marine shales organized into low-stand and high-stand system tracts within fault-bounded mini-basins. Seismic interpretation identifies growth faults, rollover anticlines, and shale diapirs as key structural controls on sand distribution and trapping geometry. These findings confirm the presence of a fully functional petroleum system comprising source, reservoir, and seal elements within deep-water turbidite complexes. Exploration potential remains high in stratigraphic traps at channel-lobe transitions and in structural closures adjacent to shale diapirs. This study provides a predictive framework for hydrocarbon exploration in the Rio del Rey Basin and analogous Atlantic passive margins globally.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 2","pages":"286-311"},"PeriodicalIF":1.7,"publicationDate":"2026-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147567041","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Paleo-Environment and Organic Matter Enrichment of Lacustrine Shale From Aershan Formation, E'rennaoer Sag, Erlian Basin","authors":"Han Wu,&nbsp;Pengfei Zhang,&nbsp;Shuangfang Lu,&nbsp;Junjie Wang,&nbsp;Xiangchun Chang,&nbsp;Chao Liu,&nbsp;Weizheng Gao,&nbsp;Yangjian Yi,&nbsp;Chenxi Wu,&nbsp;Panxue Li,&nbsp;Xinlin Song","doi":"10.1111/jpg.70034","DOIUrl":"https://doi.org/10.1111/jpg.70034","url":null,"abstract":"<div>\u0000 \u0000 <p>Understanding the controls on organic matter enrichment in lacustrine shales is a fundamental issue in petroleum geology. Although organic matter enrichment in large, relatively stable lake basins has been well studied, the mechanisms controlling enrichment in small fault-controlled basins remain poorly understood. To address this gap, this study investigates the fourth member of the Cretaceous Aershan Formation (FMAF) in the E'rennaoer Sag, Erlian Basin, as a representative case of a tectonically active lacustrine system. The FMAF in the E'rennaoer Sag is an important lacustrine shale source rock in the Erlian Basin. This study aims to reconstruct its depositional environment and clarify the mechanisms controlling organic matter enrichment. Comprehensive geochemical analyses, including total organic carbon (TOC), Rock–Eval pyrolysis, elemental ratios, and gas chromatography–mass spectrometry (GC–MS) biomarkers, were conducted. The results indicate that the FMAF was deposited under a semiarid to arid paleoclimate, with semi-saline to saline water conditions, and predominantly anoxic bottom waters. Contrary to previous assumptions of overall shallow settings, the FMAF was mainly formed in a relatively deep lacustrine environment, with localized short-term shallowing driven by tectonic and hydrological fluctuations. Organic matter is dominated by Types II₁–II₂ kerogen derived from mixed terrestrial and algal inputs, and the generally low-TOC content reflects limited primary productivity. Overall, organic matter enrichment in the FMAF was controlled primarily by preservation under reducing, stratified water-column conditions, whereas productivity increases played only a secondary role. These findings enhance the understanding of shale oil accumulation mechanisms in fault-controlled lacustrine basins.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 2","pages":"466-483"},"PeriodicalIF":1.7,"publicationDate":"2026-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147570163","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Application of Kozeny–Carman Model Optimized Based on Fractal Theory in Mixed Shale Oil Reservoirs","authors":"Lixin Tian","doi":"10.1111/jpg.70029","DOIUrl":"https://doi.org/10.1111/jpg.70029","url":null,"abstract":"<div>\u0000 \u0000 <p>In oil and gas exploration, permeability is a key parameter that affects the flow and extraction efficiency of oil and gas. The traditional Kozeny–Carman (KC) equation, based on the assumption of uniform porosity, is difficult to accurately predict the permeability of reservoirs with complex pore structures such as shale and tight sandstone. This article takes the mixed shale oil reservoir of the Lucaogou Formation in the X depression of the Junggar Basin as the research object. Aiming at the problems of complex lithology and significant physical property heterogeneity of the reservoir, a New KC (NKC) model based on fractal theory optimization and considering lithological differences is constructed. This model quantifies the power-law distribution characteristics of pore radius through pore fractal dimension (<span></span><math></math>). The curvature degree of the fluid path is characterized by the tortuosity fractal dimension (<span></span><math></math>). The arithmetic mean pore radius in the traditional model is upgraded to the area-weighted average radius, and lithological differences are taken into account. The application results show that the mean square error (MSE) of the NKC model is 101.03, which is lower than 132.64 of the traditional KC model and 143.14 of the Standard Deviation Reduction (SDR) model. The correlation coefficient is as high as 0.8066, which is better than 0.3968 and 0.2518 of the traditional model. The NKC equation optimized on the basis of fractal theory constructed in this study can more accurately describe the heterogeneity of reservoir physical properties and can provide more reliable technical support for the permeability evaluation of similar complex lithologic reservoirs in the study area.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 2","pages":"397-408"},"PeriodicalIF":1.7,"publicationDate":"2026-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147570336","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Identification of Several Tetramethylated and C4-Alkyl-Substituted Biphenyls in Petroleum and Source Rocks","authors":"Guangli Wang,&nbsp;Meng Deng,&nbsp;Yifan Wang,&nbsp;Shengbao Shi","doi":"10.1111/jpg.70023","DOIUrl":"https://doi.org/10.1111/jpg.70023","url":null,"abstract":"<div>\u0000 \u0000 <p>Biphenyl (BP) and its alkyl-substituted derivatives, distinguished by rotational flexibility between covalently linked phenyl rings, constitute significant constituents of petroleum and sedimentary organic matters. Through comprehensive gas chromatography–mass spectrometry (GC–MS) analysis and co-injection validation with authentic standards, this study unambiguously identifies four novel isomers, that is, the 2,2′,5,5′-tetramethylbiphenyl (TeMBP), 3,3′,5,5′-TeMBP, 4-butanebiphenyl (BBP), and 3,3′,4,4′-TeMBP, in a set of petroleum and source rock samples. Quantitative comparisons reveal distinct substitution patterns across depositional environments, that is, marine-derived oils exhibit progressive enrichment of mono-, di-, tri-, and tetramethylbiphenyls relative to their lacustrine counterparts. Notably, the 3,3′-dimethylbiphenyl (3,3′-DMBP) demonstrates preferential accumulation in sulfidic oils associated with carbonate source rocks deposited under anoxic, sulfur-rich conditions. Thermal maturity analysis indicates systematic compositional evolution: The BP concentrations increase with thermal stress across the oil generation window, while <i>meta</i>- and <i>para</i>-substituted derivatives, for example, 3-methylbiphenyl (MBP), 4-MBP, 3,5-DMBP, and 3,5,3′-trimethylbiphenyl (TMBP), become predominant in high-mature source rock extracts and condensates. This thermal resilience highlights BPs’ geochemical significance as proxies for high-maturity petroleum systems.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 2","pages":"255-271"},"PeriodicalIF":1.7,"publicationDate":"2026-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147565113","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Tectonostratigraphic Evolution and Petroleum Potential of the Lake Edward Basin, Uganda: Insights From Integrated Surface and Subsurface Data Analysis","authors":"Lauben Twinomujuni,&nbsp;Keyu Liu,&nbsp;Kabir Shola Ahmed,&nbsp;Nurudin Njabire,&nbsp;Tonny Sserubiri,&nbsp;Bruce Namara","doi":"10.1111/jpg.70020","DOIUrl":"https://doi.org/10.1111/jpg.70020","url":null,"abstract":"<div>\u0000 \u0000 <p>This study integrates geological (well logs, outcrop), geophysical (2D seismic and gravity surveys), and palynological data to reconstruct the tectonostratigraphic evolution of the Lake Edward Basin (Uganda) and assess its hydrocarbon potential. Results confirm an asymmetric half-graben bounded by major faults to the west and subsidiary faults to the east, with westward-thickening sediments reflecting basement geometry. Seismic interpretation reveals growth strata, fault-controlled depocenters, and structural traps, whereas lithological and wireline data confirm the presence of fluvio-deltaic reservoirs interbedded with local and possible regional seals. With a rift thermal gradient of ∼33–35°C/km, depocenters in the western part of the basin fall within the oil window. The clustering of hydrocarbon seeps on the surface of Lake Edward above the Kasindi–Bantu Fault Zone, coupled with well failure analysis, suggests that lateral hydrocarbon migration from source areas is likely limited, indicating restricted long-distance migration pathways. Although no hydrocarbon discovery has yet been made, the basin exhibits favorable structural and stratigraphic configurations comparable to proven rift plays in the wider Albertine Rift. This work underscores the need for further offshore high-resolution geophysical data acquisition, cross-border data integration, and advanced basin modeling to de-risk the petroleum system and guide future exploration.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 1","pages":"193-214"},"PeriodicalIF":1.7,"publicationDate":"2025-11-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145983747","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Geologic Well-Log Interpretation Across Carbonate Reservoir Types in the Middle East: Insights Into Reservoir Heterogeneity and Play Characteristics","authors":"A. S. Alsharhan,&nbsp;Antun Husinec,&nbsp;C. G. St. C. Kendall","doi":"10.1111/jpg.70021","DOIUrl":"https://doi.org/10.1111/jpg.70021","url":null,"abstract":"<div>\u0000 \u0000 <p>Characterizing carbonate reservoirs in the Middle East remains a persistent challenge due to pronounced heterogeneity, complex diagenetic overprints, and facies variability associated with shelf-margin dynamics. This study develops depositional and diagenetic models for major carbonate play types—shelf sheets (inner shelf sheets, sheets proximal to and updip from the carbonate shelf edge, and basinal sheets and wedges), buildups (shelf buildups and downslope buildups), and shelf-margin clinoforms—to improve qualitative interpretation of well-log responses in data-limited settings. Because many legacy wells lack digital log data, interpretations are derived from published values, emphasizing the reproducibility of diagnostic gamma-ray, neutron–density, and sonic motifs across stratigraphic intervals. The resulting framework defines characteristic log signatures for end-member carbonate plays and clarifies how depositional setting and diagenetic evolution govern porosity and reservoir quality. Although limited by incomplete stratigraphic coverage and the absence of direct seismic-to-well calibration, the study provides a regionally consistent qualitative model that enhances understanding of carbonate reservoir architecture across the Arabian Gulf. These models form a foundation for future quantitative analyses integrating modern log suites and, potentially, for artificial intelligence (AI)-assisted approaches to automated facies recognition.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 1","pages":"3-39"},"PeriodicalIF":1.7,"publicationDate":"2025-11-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145983631","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Field and Laboratory Evaluation of Potassium Chloride Polymer Mud for Drilling Stability in Clay-Rich Formations of Southeastern Türkiye","authors":"Ayşe Orhan,&nbsp;Şükrü Merey","doi":"10.1111/jpg.70018","DOIUrl":"https://doi.org/10.1111/jpg.70018","url":null,"abstract":"<div>\u0000 \u0000 <p>Southeastern Anatolia, Türkiye's largest oil reserve region, faces long-standing challenges in oil and gas drilling due to severe instability in clay-rich formations. Interaction between clay minerals and freshwater triggers hydration and osmotic swelling, which frequently results in wellbore collapse, circulation losses, nonproductive time, and significant equipment damage. Overcoming these issues requires drilling fluids specifically engineered to stabilize reactive clays under complex downhole conditions. This study presents a field-scale validation of potassium chloride (KCl) polymer-based drilling fluids, designed to enhance wellbore stability in the Germav and Kastel formations of Areas A and B. Daily monitoring of mud properties, conducted in accordance with API standards, was integrated directly with drilling operations in wells A-1 and B-1, while 41 supplementary laboratory experiments provided additional verification of mud performance. The findings demonstrated that KCl polymer mud markedly improved wellbore stability under real operational conditions. In A-1, KCl mud outperformed conventional lignosulfonate fluids, limiting clay contamination to only 2.5 lb/bbl after passing 2030 m and enabling smooth, problem-free drilling to 2209 m. In B-1, logistical challenges and a 5 lb/bbl increase in clay underscored the importance of maintaining an adequate potassium concentration; nevertheless, KCl mud successfully mitigated collapse risks following mud loss events by restoring circulation and hydrostatic balance. Overall, the study provides one of the first comprehensive validations of KCl polymer mud performance at the field scale in Southeastern Anatolia, delivering novel insights for drilling fluid optimization. These findings confirm the reliability, safety, and practicality of KCl polymer systems for mitigating clay-related instabilities in challenging reservoirs when supported by appropriate engineering design and application.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 1","pages":"179-192"},"PeriodicalIF":1.7,"publicationDate":"2025-11-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145993937","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Correction to “Palynofacies Analysis Illustrates the Source Rock Potential of the Menilite Beds, Polish Outer Carpathians”","authors":"","doi":"10.1111/jpg.70019","DOIUrl":"https://doi.org/10.1111/jpg.70019","url":null,"abstract":"<p>Anna, F., Marcin, B., Anna, W. and Leszek, J. (2025), Palynofacies Analysis Illustrates the Source Rock Potential of the Menilite Beds, Polish Outer Carpathians. Journal of Petroleum Geology, 48(4): 352–391. https://doi.org/10.1111/jpg.70005.</p><p>The order of the authors' names and surnames on the title page is incorrect. The article should be cited as follows: Filipek A., Barski M., Wysocka A., Jankowski L., Palynofacies analysis illustrates the source rock potential of the Menilite Beds, Polish Outer Carpathians. Journal of Petroleum Geology. 2025: 48(4): 352–391.</p><p>We apologize for this error.</p>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 1","pages":""},"PeriodicalIF":1.7,"publicationDate":"2025-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1111/jpg.70019","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145970200","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Tracing Oil Migration Pathways Using Integrated Modeling and Nitrogenous Compound Data in the X Block, Oriente Basin, Ecuador","authors":"Zhong-Zhen Ma,&nbsp;Wen-Jie Ma,&nbsp;Hong-Jun Wang,&nbsp;Ke-Xin Zhang,&nbsp;Chun-Lei Zhang,&nbsp;Yu-Bing Zhou,&nbsp;Ruperto Orozco,&nbsp;Xiang-Lin Xu","doi":"10.1111/jpg.70015","DOIUrl":"https://doi.org/10.1111/jpg.70015","url":null,"abstract":"<div>\u0000 \u0000 <p>Successfully predicting effective migration pathways can greatly improve the accuracy of trap risk evaluations, increase the drilling success rate, and reduce the costs of exploration in general. Combined with modeling, a total of 47 crude oil samples and 24 source rock samples were analyzed to study oil migration pathways in the Cretaceous Napo Fm M1ss member in the X block in the Oriente Basin of Ecuador. The vitrinite reflectance values of 24 source rock samples show that the source rock in the southwest zone is in the oil maturity window and was capable of supplying oil to the X block. The nitrogenous compound ratios of 1,8-/2,6-dimethylcarbazole and 1,5-/2,7-dimethylcarbazole have a consistent decreasing trend which indicates that oils migrated within the M1ss member from southwest to northeast. Basin modeling of M1ss carrier shows that different oil supply areas have different migration pathways. The migration pathways associated with oil supplies from the southwest region of Block X are restricted to the southwest and central areas. In contrast, those linked to oil supplies from the Fanny fault extend across both the hanging wall and footwall of this fault. Meanwhile, the migration pathways connected to oil supplies from the MariannN and MariannM faults are confined solely to the hanging walls of these two faults. Basin modeling combined with nitrogenous compounds analysis verified the migration pathway distribution in X block which could explain the formation of most accumulations. The traps in the southwest and eastern areas of X block appear to be favorable for future exploration as they are located on a migration pathway.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 1","pages":"129-141"},"PeriodicalIF":1.7,"publicationDate":"2025-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145984038","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Integrated Remote Sensing, Sedimentological, Geochemical and Geophysical Approach for Mapping Prospective Areas for Hydrocarbons in the Proterozoic Cuddapah Basin, India","authors":"Santosh Garain,&nbsp;Dhritikanta Gorai,&nbsp;N. M. Singh,&nbsp;Snehasis Chakrabarty,&nbsp;Rakesh Tripathi,&nbsp;Asim Samanta,&nbsp;Aftab Alam Khan,&nbsp;S. S. Khanna,&nbsp;Parama Nand,&nbsp;Parmod Kumar","doi":"10.1111/jpg.70017","DOIUrl":"https://doi.org/10.1111/jpg.70017","url":null,"abstract":"<div>\u0000 \u0000 <p>Despite having promising evidence of hydrocarbons, the Proterozoic Cuddapah Basin in southern India has not been explored adequately for petroleum resources. The present study aims to identify potential regions for hydrocarbons in Cuddapah Basin by integrating various aspects of hydrocarbon exploration. The remote sensing approach involves structural and spectral analyses of multi-sensor satellite data to look for suitable surface manifestations of hydrocarbons. From remote sensing perspective, areas with high lineament density, presence of geomorphic highs and spectrally anomalous regions are mapped as potential hydrocarbon-bearing sites. The sedimentological studies focus on identifying the best suitable reservoirs for hydrocarbon accumulation through detailed analyses of mineralogy, texture and depositional environments. The geochemical aspects cover the surface geochemical prospecting and analysis to pinpoint anomalous areas of soil gas occurrence and potential source rocks. Geophysical studies interpret gravity, magnetic and seismic data to delineate sedimentary thickness and suitable traps for hydrocarbon accumulations. Remote sensing, combined with surface geochemical studies (adsorbed soil gas and microbial analyses), sedimentological, gravity, magnetic and seismic studies point out a promising area for hydrocarbon occurrence in the north-central part of the study area. Detailed sedimentological studies demonstrate Tadpatri, Pulivendla, Vempalle and Gulcheru formations as potential reservoir rocks for the identified promising area. Thick shales and intrusives are envisaged as potential seals. Furthermore, geochemical parameters and the presence of gas seepage reinforce the hydrocarbon potentiality of the mapped region. The study will provide valuable insights into hydrocarbon exploration in Cuddapah and other Proterozoic basins of the world.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 1","pages":"160-178"},"PeriodicalIF":1.7,"publicationDate":"2025-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145984046","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}