Pub Date : 2025-11-01Epub Date: 2025-07-05DOI: 10.1016/j.petsci.2025.06.021
Cong Luo , Jun-Wei Cheng , Jing Ba , José Carcione , Lu-Lu Chen
Source rocks (shales) exhibit different geometric pore types and considerable anisotropy caused by the preferential orientation of the clay and kerogen layers, which is not accounted for in classical rock-physics models. Pore geometry can be effectively studied through the aspect ratio, and in this study, we use the aspect ratio to characterize different pore geometries. Then, we consider a pore connectivity index as well as a lamination index associated with these orientations. An inclusion-based theory (differential effective medium and self-consistent approximation) and the Brown-Korringa equations are used in the modeling approach. The results show that the indices as well as the aspect ratio of the connected pores significantly affect the elastic properties. We propose an inversion method to invert these three parameters simultaneously from experimental vertical P- and S-wave velocities using a global optimization algorithm. The method is applied to well log and seismic data from the Longmaxi shale reservoir in southwest China to verify its predictive ability.
{"title":"A modeling-inversion methodology for source rocks based on clay-kerogen lamination and pore geometry","authors":"Cong Luo , Jun-Wei Cheng , Jing Ba , José Carcione , Lu-Lu Chen","doi":"10.1016/j.petsci.2025.06.021","DOIUrl":"10.1016/j.petsci.2025.06.021","url":null,"abstract":"<div><div>Source rocks (shales) exhibit different geometric pore types and considerable anisotropy caused by the preferential orientation of the clay and kerogen layers, which is not accounted for in classical rock-physics models. Pore geometry can be effectively studied through the aspect ratio, and in this study, we use the aspect ratio to characterize different pore geometries. Then, we consider a pore connectivity index as well as a lamination index associated with these orientations. An inclusion-based theory (differential effective medium and self-consistent approximation) and the Brown-Korringa equations are used in the modeling approach. The results show that the indices as well as the aspect ratio of the connected pores significantly affect the elastic properties. We propose an inversion method to invert these three parameters simultaneously from experimental vertical P- and S-wave velocities using a global optimization algorithm. The method is applied to well log and seismic data from the Longmaxi shale reservoir in southwest China to verify its predictive ability.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4462-4491"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145697929","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-07-28DOI: 10.1016/j.petsci.2025.07.017
Yi-Lun Zhang , Zhi-Chao Yu , Chuan He
Passive microseismic monitoring (PMM) serves as a fundamental technology for assessing hydraulic fracturing (HF) effectiveness, with a key focus on accurate and efficient phase detection/arrival picking and source location. In PMM data processing, the data-driven paradigm (deep learning based) outperforms the model-driven paradigm in characteristic extraction but lacks quality control and uncertainty quantification. Monte Carlo Dropout, a Bayesian uncertainty quantification technique, performs stochastic neuron deactivation through multiple forward propagation samplings. Therefore, this study proposes a deep learning neural network incorporating uncertainty quantification with manual quality control integration, establishing an optimized workflow spanning automated phase detection to robust source location. The methodology implementation comprises two principal components: (1) The MD-Net employing Monte Carlo Dropout strategy enabling simultaneous phase detection/arrival picking and uncertainty estimation; (2) an integrated hybrid-driven workflow with a traveltime-based inversion method for source location. Validation with field data demonstrates that MD-Net achieves superior performance under low signal-to-noise ratio conditions, maintaining detection accuracy exceeding 99% for both P- and S-waves. The phase arrival picking precision shows significant improvement, with a 40% reduction in standard deviation compared to the baseline model (P-S time difference decreasing from 12.0 ms to 7.1 ms), while providing quantifiable uncertainty metrics for manual calibration. Source location results further reveal that our hybrid-driven workflow produces more physically plausible event distributions, with 100% of microseismic events clustering along the primary fracture expanding direction. This performance surpasses traditional cross-correlation methods and single/multi-trace data-driven methods in spatial rationality. This study establishes an interpretable, high-precision automated framework for HF-PMM applications, demonstrating potential for extension to diverse geological settings and monitoring configurations.
{"title":"Uncertainty-aware neural networks with manual quality control for hydraulic fracturing downhole microseismic monitoring: From automated phase detection to robust source location","authors":"Yi-Lun Zhang , Zhi-Chao Yu , Chuan He","doi":"10.1016/j.petsci.2025.07.017","DOIUrl":"10.1016/j.petsci.2025.07.017","url":null,"abstract":"<div><div>Passive microseismic monitoring (PMM) serves as a fundamental technology for assessing hydraulic fracturing (HF) effectiveness, with a key focus on accurate and efficient phase detection/arrival picking and source location. In PMM data processing, the data-driven paradigm (deep learning based) outperforms the model-driven paradigm in characteristic extraction but lacks quality control and uncertainty quantification. Monte Carlo Dropout, a Bayesian uncertainty quantification technique, performs stochastic neuron deactivation through multiple forward propagation samplings. Therefore, this study proposes a deep learning neural network incorporating uncertainty quantification with manual quality control integration, establishing an optimized workflow spanning automated phase detection to robust source location. The methodology implementation comprises two principal components: (1) The MD-Net employing Monte Carlo Dropout strategy enabling simultaneous phase detection/arrival picking and uncertainty estimation; (2) an integrated hybrid-driven workflow with a traveltime-based inversion method for source location. Validation with field data demonstrates that MD-Net achieves superior performance under low signal-to-noise ratio conditions, maintaining detection accuracy exceeding 99% for both P- and S-waves. The phase arrival picking precision shows significant improvement, with a 40% reduction in standard deviation compared to the baseline model (P-S time difference decreasing from 12.0 ms to 7.1 ms), while providing quantifiable uncertainty metrics for manual calibration. Source location results further reveal that our hybrid-driven workflow produces more physically plausible event distributions, with 100% of microseismic events clustering along the primary fracture expanding direction. This performance surpasses traditional cross-correlation methods and single/multi-trace data-driven methods in spatial rationality. This study establishes an interpretable, high-precision automated framework for HF-PMM applications, demonstrating potential for extension to diverse geological settings and monitoring configurations.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4520-4537"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145698108","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-08-18DOI: 10.1016/j.petsci.2025.08.019
Liu-Ru Liu , Yu Liu , Lang Luo , Xin-Ke Wang , Wen-Rui Yan , Bo Wang , Quan Zhu
The active cooling technology of endothermic hydrocarbon fuels is a key way to solve the thermal protection of high-speed aircraft engines, but the condensation coking problem during engine shutdown is a bottleneck that affects the reusability of aircraft. In this study, a self-designed apparatus was used to separately analyze the condensation coking during the fuel cooling process, and the coking characteristics under different temperature conditions were obtained. The condensation coking mechanism of fuel during cooling process was proposed based on the changes in physical properties of coking precursors obtained by the group contribution method. When the temperature drops to 300 °C, not only the gas yield and conversion increase to 71.42% and 89.75% respectively, but the coke mass on the inner surface of the tube also significantly increases from 0.39 to 1.92 mg. Meanwhile, as the temperature further decreases, the morphology of coke gradually transforms into amorphous carbon with a higher degree of graphitization. During the cooling process, due to the liquefaction of coking precursors, their physical properties such as viscosity, density, and saturated vapor pressure undergo sudden changes at 300 °C, leading to enhanced intermolecular physical interactions and promoting the physical aggregation of coking precursor molecules, which are deposited on the inner wall of the tube. This work provides a theoretical basis for the subsequent study of condensation coking mechanisms and inhibition methods.
{"title":"Coking behavior during the cooling process of cracked hydrocarbon fuels: Characterization of coke and elucidation of condensation coking mechanism","authors":"Liu-Ru Liu , Yu Liu , Lang Luo , Xin-Ke Wang , Wen-Rui Yan , Bo Wang , Quan Zhu","doi":"10.1016/j.petsci.2025.08.019","DOIUrl":"10.1016/j.petsci.2025.08.019","url":null,"abstract":"<div><div>The active cooling technology of endothermic hydrocarbon fuels is a key way to solve the thermal protection of high-speed aircraft engines, but the condensation coking problem during engine shutdown is a bottleneck that affects the reusability of aircraft. In this study, a self-designed apparatus was used to separately analyze the condensation coking during the fuel cooling process, and the coking characteristics under different temperature conditions were obtained. The condensation coking mechanism of fuel during cooling process was proposed based on the changes in physical properties of coking precursors obtained by the group contribution method. When the temperature drops to 300 °C, not only the gas yield and conversion increase to 71.42% and 89.75% respectively, but the coke mass on the inner surface of the tube also significantly increases from 0.39 to 1.92 mg. Meanwhile, as the temperature further decreases, the morphology of coke gradually transforms into amorphous carbon with a higher degree of graphitization. During the cooling process, due to the liquefaction of coking precursors, their physical properties such as viscosity, density, and saturated vapor pressure undergo sudden changes at 300 °C, leading to enhanced intermolecular physical interactions and promoting the physical aggregation of coking precursor molecules, which are deposited on the inner wall of the tube. This work provides a theoretical basis for the subsequent study of condensation coking mechanisms and inhibition methods.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4781-4793"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145698021","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-09-04DOI: 10.1016/j.petsci.2025.09.001
Rui Yang , Xiao-Guang Wu , Teng-Da Long , Gen-Sheng Li , Zhong-Wei Huang , Zi-Xiao Xie , Xiao-Xuan Li , Xiang-Yang Wang
Exploring the interaction between hydraulic fractures and complex geological conditions is critical for multilayered commingling production in the laminated continental shale oil reservoirs. In this paper, a 2D hydro-mechanical coupling numerical model is developed to investigate the fracture propagation behavior affected by the joint interaction of multi-lithologic stack and shale anisotropy. The model adopts a smear approach to reproduce the mechanical anisotropy of shale observed from laboratory experiments with powerful finite-discrete element method (FDEM) to precisely capture the transition from elastic deformation to failure during fluid injection in layered heterogeneous media. The results indicate that shale anisotropy affects hydraulic fracture initiation and propagation behavior. The estimated breakdown pressure is 15% higher than that in horizontal homogeneous shale oil reservoirs. The elastic anisotropy alters the stress trajectory and magnitudes, while the strength anisotropy affects the failure mode and fracture morphology. Under the combined two factors, the established fracture network reveals potent cross-layer abilities with less activation of weak planes. Additionally, the sedimentary structure of thin interlayers hinders fracture height extension, resulting in a limited stimulated reservoir volume (SRV). Optimization of engineering and geological parameters could mitigate this limitation and efficiently co-develop the multiple sweet-spot pay zones. For field application, it is proposed to select a modest stress difference formation (Kv around 0.75–1.00) for stimulation. Then, an alternated high/low injection rate can be employed to improve the cross-layer ability and activate the underlying weak planes, finally realizing an ideal SRV. The key findings are expected to provide new insights into the fracture propagation mechanism and guide reservoir stimulation in continental shale oil.
{"title":"FDEM modeling of the fracture propagation behavior under the joint interaction of shale anisotropy and multi-lithologic stack","authors":"Rui Yang , Xiao-Guang Wu , Teng-Da Long , Gen-Sheng Li , Zhong-Wei Huang , Zi-Xiao Xie , Xiao-Xuan Li , Xiang-Yang Wang","doi":"10.1016/j.petsci.2025.09.001","DOIUrl":"10.1016/j.petsci.2025.09.001","url":null,"abstract":"<div><div>Exploring the interaction between hydraulic fractures and complex geological conditions is critical for multilayered commingling production in the laminated continental shale oil reservoirs. In this paper, a 2D hydro-mechanical coupling numerical model is developed to investigate the fracture propagation behavior affected by the joint interaction of multi-lithologic stack and shale anisotropy. The model adopts a smear approach to reproduce the mechanical anisotropy of shale observed from laboratory experiments with powerful finite-discrete element method (FDEM) to precisely capture the transition from elastic deformation to failure during fluid injection in layered heterogeneous media. The results indicate that shale anisotropy affects hydraulic fracture initiation and propagation behavior. The estimated breakdown pressure is 15% higher than that in horizontal homogeneous shale oil reservoirs. The elastic anisotropy alters the stress trajectory and magnitudes, while the strength anisotropy affects the failure mode and fracture morphology. Under the combined two factors, the established fracture network reveals potent cross-layer abilities with less activation of weak planes. Additionally, the sedimentary structure of thin interlayers hinders fracture height extension, resulting in a limited stimulated reservoir volume (SRV). Optimization of engineering and geological parameters could mitigate this limitation and efficiently co-develop the multiple sweet-spot pay zones. For field application, it is proposed to select a modest stress difference formation (<em>K</em><sub>v</sub> around 0.75–1.00) for stimulation. Then, an alternated high/low injection rate can be employed to improve the cross-layer ability and activate the underlying weak planes, finally realizing an ideal SRV. The key findings are expected to provide new insights into the fracture propagation mechanism and guide reservoir stimulation in continental shale oil.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4656-4681"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145698015","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-08-08DOI: 10.1016/j.petsci.2025.08.004
Hao Wang , Ke-Lai Xi , Ying-Chang Cao , Xian-Zhang Yang , Ke-Yu Liu , Guo-Ding Yu , Nian-Min Zan , Yin Liu
The formation mechanisms of deep high-quality reservoirs in the Dibei area of Kuqa Depression foreland thrust belt were investigated through an integrated multidisciplinary approach combining petrographic analysis (thin section and cathodoluminescence microscopy), geochemical characterization (fluid inclusion microthermometry, stable isotope analysis) and structural modeling (2D finite element simulation). Systematic analysis reveals that the Ahe Formation reservoirs exhibit superior storage capacity characterized by: (1) high fracture density (0–8 m−1, based on imaging log interpretation and core analysis), (2) intensive feldspar dissolution (resulting in up to 5% porosity enhancement, derived from thin section point counting-derived), and (3) limited authigenic clay mineral content (<3 vol%, thin section point counting-derived). Reservoir heterogeneity is mechanistically controlled by structural-lithofacies-fluid interactions, with optimal reservoir development occurring in sandstone-mudstone interbeds of back thrust structures. These units display composite pore networks composed of dissolution pores (50–500 μm) interconnected by shear-induced microfractures (aperture: 5–15 μm). Two-dimensional finite element simulations demonstrate that differential deformation between ductile lithofacies (mudstones and coals) and brittle sandstones promotes fracture proliferation in interbedded sequences, with increasing fracture density by 40%–60% compared to massive sandstone units. Organic acid migration induces LREE-MREE enrichment in calcite and kaolinite, coupled with depleted δ13C (−15.2‰ to −9‰) and δD (−96.8‰ to −84.1‰) values, indicative of redox-driven diagenetic alteration. Open fracture networks in shear-tension zones (mid-upper sections of back thrust structures) provide effective migration pathways for organic acids, establishing localized open geochemical systems that drive feldspar dissolution while inhibiting authigenic clay precipitation (kaolinite <0.5 vol%, illite <1 vol%). Conversely, weakly deformed opposing thrust structures in compression-dominated regimes exhibit reduced fracture connectivity (aperture <5 μm), limited dissolution (dissolution porosity <3%), and pervasive pore-filling cements (authigenic quartz >1 vol%, kaolinite >1 vol%), collectively degrading reservoir quality.
{"title":"The formation mechanism of high-quality clastic rock reservoir controlled by coupling of “structure-lithofacies-fluid” in the foreland thrust belt in northern Kuqa, Tarim Basin, Northwestern China","authors":"Hao Wang , Ke-Lai Xi , Ying-Chang Cao , Xian-Zhang Yang , Ke-Yu Liu , Guo-Ding Yu , Nian-Min Zan , Yin Liu","doi":"10.1016/j.petsci.2025.08.004","DOIUrl":"10.1016/j.petsci.2025.08.004","url":null,"abstract":"<div><div>The formation mechanisms of deep high-quality reservoirs in the Dibei area of Kuqa Depression foreland thrust belt were investigated through an integrated multidisciplinary approach combining petrographic analysis (thin section and cathodoluminescence microscopy), geochemical characterization (fluid inclusion microthermometry, stable isotope analysis) and structural modeling (2D finite element simulation). Systematic analysis reveals that the Ahe Formation reservoirs exhibit superior storage capacity characterized by: (1) high fracture density (0–8 m<sup>−1</sup>, based on imaging log interpretation and core analysis), (2) intensive feldspar dissolution (resulting in up to 5% porosity enhancement, derived from thin section point counting-derived), and (3) limited authigenic clay mineral content (<3 vol%, thin section point counting-derived). Reservoir heterogeneity is mechanistically controlled by structural-lithofacies-fluid interactions, with optimal reservoir development occurring in sandstone-mudstone interbeds of back thrust structures. These units display composite pore networks composed of dissolution pores (50–500 μm) interconnected by shear-induced microfractures (aperture: 5–15 μm). Two-dimensional finite element simulations demonstrate that differential deformation between ductile lithofacies (mudstones and coals) and brittle sandstones promotes fracture proliferation in interbedded sequences, with increasing fracture density by 40%–60% compared to massive sandstone units. Organic acid migration induces LREE-MREE enrichment in calcite and kaolinite, coupled with depleted <em>δ</em><sup>13</sup>C (−15.2‰ to −9‰) and <em>δ</em>D (−96.8‰ to −84.1‰) values, indicative of redox-driven diagenetic alteration. Open fracture networks in shear-tension zones (mid-upper sections of back thrust structures) provide effective migration pathways for organic acids, establishing localized open geochemical systems that drive feldspar dissolution while inhibiting authigenic clay precipitation (kaolinite <0.5 vol%, illite <1 vol%). Conversely, weakly deformed opposing thrust structures in compression-dominated regimes exhibit reduced fracture connectivity (aperture <5 μm), limited dissolution (dissolution porosity <3%), and pervasive pore-filling cements (authigenic quartz >1 vol%, kaolinite >1 vol%), collectively degrading reservoir quality.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4357-4380"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145697805","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-08-08DOI: 10.1016/j.petsci.2025.08.012
Xiao-Jun Shi , Cong Li , Jia-Nan Li , Zhi-Qiang He , Bo Yu , Ya-Chen Xie , He-Ping Xie
Accurately evaluating the quality and scale of deep oil and gas reservoirs is the key to effectively exploring and developing deep oil and gas resources. Changes in temperature and pressure can cause significant variations in key reservoir quality parameters, such as porosity, permeability, and saturation, leading to distortions in oil and gas reserve assessments. To addresses the technical bottleneck of the existing pressure-preserved coring systems, which has a pressure-preserved capacity not exceed 70 MPa due to the limitations of small coring space, a complex coring environment, significant disturbance during the coring process, and the difficulty in controlling coring operations, a self-sealing control principle and method for pressure-preserved coring was proposed. The sealing structural parameters of the pressure-preserved controller (PPC) under high temperature (150 °C) were optimized through experiments and numerical simulations, the sealing failure mechanism was thoroughly revealed, and the pressure-preserved capacity of the PPC under high temperature was enhanced from 100 to 140 MPa. In addition, to achieve the temperature preservation of the core in the deep oil and gas environment, a temperature preservation system combining active and passive temperature preservation was designed and integrated into the deep oil and gas in-situ temperature pressure preserved (ITPP) coring system. Finally, the coring function and temperature pressure preserved capacity of the ITPP coring system were verified through field and laboratory tests. The results show that the developed ITPP coring system can successfully achieve the temperature pressure preserved function, and can sample oil and gas-bearing core samples with a diameter of 50 mm and a maximum length of 1000 mm from wells up to 5000 m. This study addresses the urgent need for reliable and effective pressure-preservation in deep oil and gas exploration.
{"title":"Self-sealing control principle and technology of in-situ temperature pressure preserved coring for deep oil and gas","authors":"Xiao-Jun Shi , Cong Li , Jia-Nan Li , Zhi-Qiang He , Bo Yu , Ya-Chen Xie , He-Ping Xie","doi":"10.1016/j.petsci.2025.08.012","DOIUrl":"10.1016/j.petsci.2025.08.012","url":null,"abstract":"<div><div>Accurately evaluating the quality and scale of deep oil and gas reservoirs is the key to effectively exploring and developing deep oil and gas resources. Changes in temperature and pressure can cause significant variations in key reservoir quality parameters, such as porosity, permeability, and saturation, leading to distortions in oil and gas reserve assessments. To addresses the technical bottleneck of the existing pressure-preserved coring systems, which has a pressure-preserved capacity not exceed 70 MPa due to the limitations of small coring space, a complex coring environment, significant disturbance during the coring process, and the difficulty in controlling coring operations, a self-sealing control principle and method for pressure-preserved coring was proposed. The sealing structural parameters of the pressure-preserved controller (PPC) under high temperature (150 °C) were optimized through experiments and numerical simulations, the sealing failure mechanism was thoroughly revealed, and the pressure-preserved capacity of the PPC under high temperature was enhanced from 100 to 140 MPa. In addition, to achieve the temperature preservation of the core in the deep oil and gas environment, a temperature preservation system combining active and passive temperature preservation was designed and integrated into the deep oil and gas in-situ temperature pressure preserved (ITPP) coring system. Finally, the coring function and temperature pressure preserved capacity of the ITPP coring system were verified through field and laboratory tests. The results show that the developed ITPP coring system can successfully achieve the temperature pressure preserved function, and can sample oil and gas-bearing core samples with a diameter of 50 mm and a maximum length of 1000 mm from wells up to 5000 m. This study addresses the urgent need for reliable and effective pressure-preservation in deep oil and gas exploration.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4584-4602"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145697933","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-10-04DOI: 10.1016/j.petsci.2025.09.036
Bing-Yuan Hong , Zhi-Wei Chen , Hai-Feng Chen , Meng-Xi Zhou , Jing Gong , Yu-Peng Xu , Zhen-Yu Zhu , Xiao-Ping Li
The multi-stage development strategy is often adopted in the gas field. However, when the productivity decline occurs, many large processing stations will be severely idle and underutilized, significantly reducing operating efficiency and revenue. This study proposes a novel operation mode of multiple gathering production systems for gas field multi-stage development, integrating the decisions about processing capacity allocation and infrastructure construction to share processing stations and improve multi-system operating efficiency. A multi-period mixed integer linear programming model for multi-system operation optimization is established to optimize the Net present value (NPV), considering the production of gas wells, time-varying gas prices, and the capacity of processing stations. The decision of processing capacity, location, construction timing, and capacity expansion of processing stations, as well as transmission capacity of pipelines and processing capacity allocation schemes, can be obtained to meet long-term production demand. Furthermore, a real case study indicates that the proposed processing capacity allocation approach not only has a shorter payback period and increases NPV by 4.8%, but also increases the utilization efficiency of processing stations from 27.37% to 48.94%. This work demonstrates that the synergy between the processing capacity allocation and infrastructure construction can hedge against production fluctuations and increase potential profits.
{"title":"Processing capacity allocation of multiple production system for gas field multi-stage development","authors":"Bing-Yuan Hong , Zhi-Wei Chen , Hai-Feng Chen , Meng-Xi Zhou , Jing Gong , Yu-Peng Xu , Zhen-Yu Zhu , Xiao-Ping Li","doi":"10.1016/j.petsci.2025.09.036","DOIUrl":"10.1016/j.petsci.2025.09.036","url":null,"abstract":"<div><div>The multi-stage development strategy is often adopted in the gas field. However, when the productivity decline occurs, many large processing stations will be severely idle and underutilized, significantly reducing operating efficiency and revenue. This study proposes a novel operation mode of multiple gathering production systems for gas field multi-stage development, integrating the decisions about processing capacity allocation and infrastructure construction to share processing stations and improve multi-system operating efficiency. A multi-period mixed integer linear programming model for multi-system operation optimization is established to optimize the Net present value (NPV), considering the production of gas wells, time-varying gas prices, and the capacity of processing stations. The decision of processing capacity, location, construction timing, and capacity expansion of processing stations, as well as transmission capacity of pipelines and processing capacity allocation schemes, can be obtained to meet long-term production demand. Furthermore, a real case study indicates that the proposed processing capacity allocation approach not only has a shorter payback period and increases NPV by 4.8%, but also increases the utilization efficiency of processing stations from 27.37% to 48.94%. This work demonstrates that the synergy between the processing capacity allocation and infrastructure construction can hedge against production fluctuations and increase potential profits.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4766-4780"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145698020","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The Early Eocene Climate Optimum (EECO) represents the peak of the early Paleogene greenhouse climate. However, a comprehensive understanding of the terrestrial paleoenvironmental response to the EECO and its implications for organic matter (OM) enrichment remains lacking. We integrated sedimentological, astrochronological, and geochemical data from South China Sea sediments to reconstruct the paleoenvironment and establish the OM enrichment model during the EECO. Astronomical time scales (ATS) for the Lower Wenchang Formation (Lower WC Fm.) in the Kaiping Sag, South China Sea, were established, spanning 55.4 to 43.9 Ma. During 51.5–48.7 Ma, records of astronomical signal (with overlapping cycles of 2.4 Ma, 1.2 Ma, and 405 kyr), stratigraphy (organic-rich mudstone), and paleoclimatic reconstructions (warm and humid climate) provided convincing evidence for the EECO in Kaiping Sag. This study presented the first detailed record of the terrestrial paleoenvironment response to the EECO in the South China Sea, characterized by high terrestrial input, anoxia water conditions, and elevated paleo productivity. A transient pre-warming event before the EECO exhibited a similar paleoenvironmental response, highlighting the sensitivity of terrestrial records. Post-EECO conditions showed a reversal of paleoenvironmental trends observed during the EECO. Pearson correlation analysis reveals that the EECO influenced OM enrichment by regulating paleo productivity and preservation conditions of lake. Elevated atmospheric pCO2 levels and increased terrestrial input promoted algal blooms, thereby enhancing lake productivity. OM preservation was controlled by water column stratification and bottom water anoxia, driven by increased terrestrial input and rising lake levels. Our findings enhance the understanding of feedback mechanisms in terrestrial environments during global warming and provide insights into future climate change predictions.
{"title":"Terrestrial paleoenvironmental response of Early Eocene Climate Optimum: Implications for organic matter enrichment in the South China Sea","authors":"Jing Guo , Guang-Rong Peng , Fu-Jie Jiang , Yu-Qi Wu , Hong-Bo Li , Ya-Qi Li , Xin-Wei Qiu , Jun-Jie Cai , Fu-Sheng Yu , Xin Chen , Biao Jiang , Li-Shan Tang","doi":"10.1016/j.petsci.2025.08.005","DOIUrl":"10.1016/j.petsci.2025.08.005","url":null,"abstract":"<div><div>The Early Eocene Climate Optimum (EECO) represents the peak of the early Paleogene greenhouse climate. However, a comprehensive understanding of the terrestrial paleoenvironmental response to the EECO and its implications for organic matter (OM) enrichment remains lacking. We integrated sedimentological, astrochronological, and geochemical data from South China Sea sediments to reconstruct the paleoenvironment and establish the OM enrichment model during the EECO. Astronomical time scales (ATS) for the Lower Wenchang Formation (Lower WC Fm.) in the Kaiping Sag, South China Sea, were established, spanning 55.4 to 43.9 Ma. During 51.5–48.7 Ma, records of astronomical signal (with overlapping cycles of 2.4 Ma, 1.2 Ma, and 405 kyr), stratigraphy (organic-rich mudstone), and paleoclimatic reconstructions (warm and humid climate) provided convincing evidence for the EECO in Kaiping Sag. This study presented the first detailed record of the terrestrial paleoenvironment response to the EECO in the South China Sea, characterized by high terrestrial input, anoxia water conditions, and elevated paleo productivity. A transient pre-warming event before the EECO exhibited a similar paleoenvironmental response, highlighting the sensitivity of terrestrial records. Post-EECO conditions showed a reversal of paleoenvironmental trends observed during the EECO. Pearson correlation analysis reveals that the EECO influenced OM enrichment by regulating paleo productivity and preservation conditions of lake. Elevated atmospheric <em>p</em>CO<sub>2</sub> levels and increased terrestrial input promoted algal blooms, thereby enhancing lake productivity. OM preservation was controlled by water column stratification and bottom water anoxia, driven by increased terrestrial input and rising lake levels. Our findings enhance the understanding of feedback mechanisms in terrestrial environments during global warming and provide insights into future climate change predictions.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4394-4411"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145697807","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-08-21DOI: 10.1016/j.petsci.2025.08.024
Xiao-Fei Fu , Ming-Xing Fan , Hai-Xue Wang , Ru Jia , Xian-Qiang Song , Ye-Jun Jin
The ability of faults to transport oil and gas is affected by multiple geological factors, and the effects of various factors on oil and gas migration and accumulation are complex. In this study, based on the drilling and three-dimensional seismic data in the No. 4 structural zone of the Nanpu Sag and by considering the effects of fault throw, caprock thickness, shale content, fluid pressure, stress normal to the fault plane, and brittleness, we employed fault transport index (FTI) to quantitatively characterize the vertical transport ability of regional faults. Through statistical analysis, fault transport probability (Np) was used to characterize the relationship between FTI and the vertical hydrocarbon content in the formations. The results show that the faults with FTI less than 0.75 cannot transport oil and gas, while those with FTI greater than 2.5 are able to transport oil and gas. Specifically, when FTI is between 0.75 and 2.5, there is a functional relationship between the probability of faults transporting hydrocarbons and FTI. The current oil and water distribution and paleo oil reservoir test results indicate that there are oil layers or paleo oil reservoirs in horizons with large Np. Therefore, FTI can be used as an effective coefficient to indicate the vertical migration paths and accumulation spots of hydrocarbons moving along faults, providing an essential reference for further oil and gas exploration and development.
{"title":"Control of fault transport ability on hydrocarbon migration and accumulation in the No. 4 structural zone of Nanpu Sag, Bohai Bay Basin, China","authors":"Xiao-Fei Fu , Ming-Xing Fan , Hai-Xue Wang , Ru Jia , Xian-Qiang Song , Ye-Jun Jin","doi":"10.1016/j.petsci.2025.08.024","DOIUrl":"10.1016/j.petsci.2025.08.024","url":null,"abstract":"<div><div>The ability of faults to transport oil and gas is affected by multiple geological factors, and the effects of various factors on oil and gas migration and accumulation are complex. In this study, based on the drilling and three-dimensional seismic data in the No. 4 structural zone of the Nanpu Sag and by considering the effects of fault throw, caprock thickness, shale content, fluid pressure, stress normal to the fault plane, and brittleness, we employed fault transport index (FTI) to quantitatively characterize the vertical transport ability of regional faults. Through statistical analysis, fault transport probability (<em>N</em><sub>p</sub>) was used to characterize the relationship between FTI and the vertical hydrocarbon content in the formations. The results show that the faults with FTI less than 0.75 cannot transport oil and gas, while those with FTI greater than 2.5 are able to transport oil and gas. Specifically, when FTI is between 0.75 and 2.5, there is a functional relationship between the probability of faults transporting hydrocarbons and FTI. The current oil and water distribution and paleo oil reservoir test results indicate that there are oil layers or paleo oil reservoirs in horizons with large <em>N</em><sub>p</sub>. Therefore, FTI can be used as an effective coefficient to indicate the vertical migration paths and accumulation spots of hydrocarbons moving along faults, providing an essential reference for further oil and gas exploration and development.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4412-4427"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145697917","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2025-11-01Epub Date: 2025-07-05DOI: 10.1016/j.petsci.2025.06.022
Lei Song , Xing-Yao Yin , Ying Shi , Kun Lang , Hao Zhou , Wei Xiang
Accurate characterization of the fault system is crucial for the exploration and development of fractured reservoirs. The fault characterization technique based on multi-azimuth and multi-attribute fusion is a hotspot. In this way, the fault structures of different scales can be identified and the characterization details of complex fault systems can be enriched by analyzing and fusing the fault-induced responses in multi-azimuth and multi-type seismic attributes. However, the current fusion methods are still in the stage of violent information stacking in utilizing fault information of multi-azimuth and multi-type seismic attributes, and the fault or fracture semantics in multi-type attributes are not fully considered and utilized. In this work, we propose a physic-guided multi-azimuth multi-type seismic attributes intelligent fusion method, which can mine fracture semantics from multi-azimuth seismic data and realize the effective fusion of fault-induced abnormal responses in multi-azimuth seismic coherence and curvature with the cooperation of the deep learning model and physical knowledge. The fused result can be used for multi-azimuth comprehensive characterization for multi-scale faults. The proposed method is successfully applied to an ultra-deep carbonate field survey. The results indicate the proposed method is superior to self-supervised-based, principal-component-analysis-based, and weighted-average-based fusion methods in fault characterization accuracy, and some medium-scale and microscale fault illusions in multi-azimuth seismic coherence and curvature can be removed in the fused result.
{"title":"Physic-guided multi-azimuth multi-type seismic attributes fusion for multiscale fault characterization","authors":"Lei Song , Xing-Yao Yin , Ying Shi , Kun Lang , Hao Zhou , Wei Xiang","doi":"10.1016/j.petsci.2025.06.022","DOIUrl":"10.1016/j.petsci.2025.06.022","url":null,"abstract":"<div><div>Accurate characterization of the fault system is crucial for the exploration and development of fractured reservoirs. The fault characterization technique based on multi-azimuth and multi-attribute fusion is a hotspot. In this way, the fault structures of different scales can be identified and the characterization details of complex fault systems can be enriched by analyzing and fusing the fault-induced responses in multi-azimuth and multi-type seismic attributes. However, the current fusion methods are still in the stage of violent information stacking in utilizing fault information of multi-azimuth and multi-type seismic attributes, and the fault or fracture semantics in multi-type attributes are not fully considered and utilized. In this work, we propose a physic-guided multi-azimuth multi-type seismic attributes intelligent fusion method, which can mine fracture semantics from multi-azimuth seismic data and realize the effective fusion of fault-induced abnormal responses in multi-azimuth seismic coherence and curvature with the cooperation of the deep learning model and physical knowledge. The fused result can be used for multi-azimuth comprehensive characterization for multi-scale faults. The proposed method is successfully applied to an ultra-deep carbonate field survey. The results indicate the proposed method is superior to self-supervised-based, principal-component-analysis-based, and weighted-average-based fusion methods in fault characterization accuracy, and some medium-scale and microscale fault illusions in multi-azimuth seismic coherence and curvature can be removed in the fused result.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 11","pages":"Pages 4492-4503"},"PeriodicalIF":6.1,"publicationDate":"2025-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145698106","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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