Journal of Petroleum Geology最新文献

{"title":"Risk Assessment of Subsea Oil Pipeline Decommissioning Under Uncertainty","authors":"Zhengshan Luo,&nbsp;Mengfan Li,&nbsp;Yiqiong Gao","doi":"10.1111/jpg.70026","DOIUrl":"https://doi.org/10.1111/jpg.70026","url":null,"abstract":"<div>\u0000 \u0000 <p>To address the complex challenges of subsea pipeline decommissioning under uncertain conditions, this article proposes a risk assessment methodology integrating the noisy-or gate model, Bayesian networks (BNs), and Monte Carlo simulation (MCS). The methodology is applied to the decommissioning of the Hainan 8 subsea pipeline as a case study. Twenty-three risk factors, including behavioral variability, state dependence, inherent uncertainty, cognitive limitations, and control vulnerability, were determined by noisy-or gate model to establish BN model, risk level and potential losses were classified on the basis of risk probabilities; and the risk probability was analyzed by MCS. The sensitivity analysis is used to identify the key factors affecting the safety risk of subsea pipeline operation. The results indicate that the primary risk factors for subsea pipeline decommissioning include unstable seabed geology, the standardization of hosting operations, and the failure of dynamic positioning. Relevant scientific recommendations for risk prevention measures are provided.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 2","pages":"346-356"},"PeriodicalIF":1.7,"publicationDate":"2026-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147615110","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":"Unravelling Hydrocarbon Microseepage: Evidence of Petroleum Systems in a Semi-Arid Rift Setting","authors":"Mussa Mathew Nalogwa,&nbsp;Paul Faustine Matumbi","doi":"10.1111/jpg.70022","DOIUrl":"https://doi.org/10.1111/jpg.70022","url":null,"abstract":"<div>\u0000 \u0000 <p>The persistence of hydrocarbon microseepage on the surface creates a reducing environment that causes mineralogical alterations. This study focuses on identifying zones affected by such microseepage-related mineral alterations to support the potential presence of an active petroleum system in a semi-arid region within the East African Rift System. To achieve this objective, the study employed an integrated methodology that combined Advanced Spaceborne Thermal Emission and Reflection Radiometer (ASTER) image processing, amplified geochemical imaging (AGI), and potential field data analysis. The analysis enabled the mapping of six optimal signatures consistent with either gas-condensate or oil in the area of interest (AOI). From the study, the mapped prospects are in proximity to the major faults and a basin depth of around 4 km, which is considered sufficient for hydrocarbon generation. Although no wells have been drilled to date, the mineralogical changes identified through processed satellite imagery, which include ferrous from ferric (red bed bleaching), increased kaolinite concentration and carbonate mineral precipitation, suggest the potential presence of hydrocarbon microseepage and a functioning petroleum system. The result supports further exploration investments, enhances the AOI value and attracts external funding that may expedite hydrocarbon discovery.</p>\u0000 </div>","PeriodicalId":16748,"journal":{"name":"Journal of Petroleum Geology","volume":"49 2","pages":"272-285"},"PeriodicalIF":1.7,"publicationDate":"2026-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147565112","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":"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}