Petroleum Exploration and Development最新文献

{"title":"A transient and steady state integrated evaluation framework for interwell connectivity in fractured-vuggy reservoirs","authors":"Ruofan Yan,&nbsp;Jing Wang,&nbsp;Zhiyuan Xu,&nbsp;Xu Lou,&nbsp;Songqing Zheng,&nbsp;Qi Zhang,&nbsp;Kuangyi Xu,&nbsp;Huiqing Liu","doi":"10.1016/S1876-3804(26)60748-3","DOIUrl":"10.1016/S1876-3804(26)60748-3","url":null,"abstract":"<div><div>To address the challenges of uncertain interwell injection-production relationships, high monitoring costs, and limited production data that constrain reliable interwell-connectivity evaluation during the early development of fractured-vuggy carbonate reservoirs, an interwell connectivity evaluation framework integrating transient disturbance propagation with steady-state production similarity is developed. Under this framework, changes in operating conditions, including well opening, well shut-in, and choke adjustment, are identified as disturbance events. An impulse response function (IRF) is used to characterize transient propagation, while an adaptive multi-feature penalized dynamic time warping (AMP-DTW) method is employed to quantify steady-state production similarity. Coupling with information-theoretic weighting and Leiden clustering, connected units are identified. The proposed framework was applied to 37 wells in the Y fault zone of Field A. The results indicate that a total of 379 valid disturbance events are identified, and the self-identification accuracy of the proposed AMP-DTW method reaches 91.6%. The weights assigned to transient disturbance information and steady-state similarity information are 0.584 and 0.416, respectively, indicating that transient responses contribute more to interwell connectivity identification under the current development conditions. The study area is divided into six major connected units and five isolated wells, and the resulting partitioning is broadly consistent with the geological segmentation of the fault zone. The proposed framework provides a practical basis for evaluating interwell connectivity in fault-controlled fractured-vuggy reservoirs where systematic injection–production data and direct monitoring measurements are limited.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 1093-1109"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822549","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Multiple hydrocarbon accumulation models and new exploration areas in the Paleozoic strata in the western margin of the Ordos Basin, NW China","authors":"Hongwei Wang,&nbsp;Jiayi Wei,&nbsp;Min Xu,&nbsp;Hongping Bao,&nbsp;Zhi Yang,&nbsp;Yajuan Yang,&nbsp;Han Li,&nbsp;Puyu Liu,&nbsp;Yan Zhang","doi":"10.1016/S1876-3804(26)60738-0","DOIUrl":"10.1016/S1876-3804(26)60738-0","url":null,"abstract":"<div><div>Based on the latest high-precision gravity, magnetic and three-dimensional seismic exploration data in the western margin of the Ordos Basin, the fine analysis of Paleozoic tectonic system and the re-understanding of hydrocarbon accumulation conditions are carried out. The research shows that, by redefining the classification of faults, four types of structural styles are identified, including back thrust belt, hanging wall syncline, footwall in-situ rock mass uplift belt, and strike-slip–thrust imbricate belt. According to the characteristics of source-reservoir configuration, five hydrocarbon accumulation models are established, including the Hengshanbao structural trap gas reservoir group in the northern zone, the tight gas accumulation in the intra-source syncline in the hanging wall and concealed uplift structure controlled accumulation in the footwallof of the thrust belt in the central zone, the low-mature shale self-generation and self-storage in the southern zone, and the grain beach + dual-source hydrocarbon supply in the platform margin. Combined with the analysis of exploration results, five favorable exploration areas are delineated: the Hengshanbao complex structural area in the northern zone, covering 410 km<span><span>^b</span></span>, which belongs to the realistic and efficient exploration target area; the concealed uplift belt in the central zone, covering 1 800 km<span><span>^b</span></span>, which is the first breakthrough in the 8^th member of Lower Shihezi Formation; the Carboniferous Yanghugou Formation in the central zone, which has been revealed with the potential for coal-rock gas and tight sandstone gas accumulation within the source; the marine shale oil in the Middle Ordovician Wulalike Formation in the southern zone, covering 275 km<span><span>^b</span></span>, with Well YT3 achieving an industrial breakthrough; and the western platform margin of the Ordovician strata, covering about 5 300 km<span><span>^b</span></span>. These findings have guiding significance for further breakthrough, expansion, and reserves addition in subsequent oil and gas exploration activities in the western margin of the basin.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 951-966"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822918","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Elemental fingerprint-based microstructure identification method for deep coal-seam horizontal wells: A case study of No. 8 coal seam of Carboniferous Benxi Formation in Ordos Basin, NW China","authors":"Jiayuan He,&nbsp;Shicheng Zhang,&nbsp;Xusheng Guo,&nbsp;Xiang Wang,&nbsp;Xugang Liu,&nbsp;Zhengjun Yin,&nbsp;Yushu Wu,&nbsp;Jianye Mou","doi":"10.1016/S1876-3804(26)60747-1","DOIUrl":"10.1016/S1876-3804(26)60747-1","url":null,"abstract":"<div><div>To address the problem of high-precision microstructure identification in the deep No. 8 coal seam of Carboniferous Benxi Formation in the Ordos Basin, “elemental fingerprints” of the deep coal seam and its roof and floor strata were constructed, and measurement points along the horizontal well were mapped to their corresponding reference positions in the vertical profile of the pilot well, thereby enabling the identification of microstructural features along the horizontal section of deep coalbed methane horizontal wells. First, based on elemental logging data and constrained by the lithological framework, candidate elements were determined for distinguishing the coal seam from its roof and floor strata and for identifying different coal lithotypes. Then, the candidate elements were screened using the coefficient of variation to obtain the characteristic elements for microstructure identification. The concentrations of the characteristic elements were adjusted using Z-score normalization, and the combination of characteristic-element concentrations at the same measurement point was expressed as a vector, termed an “elemental fingerprint”. Subsequently, the elemental fingerprints of the pilot well were matched with those of the horizontal section to determine the vertical-profile positions and distributional variations of the horizontal section. Finally, horizontal-well drilling information was integrated to determine the locations and types of microstructures developed along the horizontal section, thereby guiding adjustments to the drilling direction of the bit. Field drilling and hydraulic- fracturing practices demonstrate that the elemental fingerprint-based microstructure identification method can accurately identify microstructural features (e.g. small-scale folds, superimposed faults, and tectonically disturbed zones) along the horizontal section, and provide technical support for the optimized design of drilling and hydraulic fracturing in deep coalbed methane horizontal wells.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 1081-1092"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822548","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Molecular dynamics simulation of helium adsorption-diffusion behavior in nanopores of anthracite from Permian Shanxi Formation in Qinshui Basin, China","authors":"Xidong Du,&nbsp;Shikun Zuo,&nbsp;Junping Zhou,&nbsp;Guangjin Wang,&nbsp;Dengfeng Zhang,&nbsp;Wengang Huang,&nbsp;Jie Zou,&nbsp;Hong Yin,&nbsp;Xianwei Heng,&nbsp;Chao Qin","doi":"10.1016/S1876-3804(26)60755-0","DOIUrl":"10.1016/S1876-3804(26)60755-0","url":null,"abstract":"<div><div>To understand the occurrence and migration mechanisms of helium in coal-measure gas, this study investigated anthracite from No. 3 coal seam of Lower Permian Shanxi Formation in the Jincheng mining area of the southern Qinshui Basin, China, through experiment analysis and molecular simulation. Firstly, low-temperature CO₂ and N₂ adsorption experiments were performed to characterize the multi-scale pore structure of anthracite, and accordingly, a 1–10 nm slit pore model of anthracite was constructed. Using grand canonical Monte Carlo, molecular dynamics and non-equilibrium molecular dynamics simulation methods, the effects of pore size, temperature, pressure, pore water, and associated gases (CO₂, CH₄, N₂, H₂) on helium adsorption, diffusion, and pressure-driven flow were systematically examined. The results show that helium exhibits weak enrichment near wall in nano-scale slit pores and coexistence of free gas in the pore center. Its interaction with coal wall is significantly weaker than those of CO₂, CH₄ and N₂, and is relatively close to that of H₂. Pore size, temperature and pressure all affect helium diffusion and flow behaviors. Smaller pores reduce helium diffusion coefficient and increase its viscosity, whereas larger pores facilitate helium migration. Pore water weakens continuous gas-phase pathways through film formation, permeation and interfacial friction, causing a sudden drop in helium diffusion coefficient at high water content stage. Strong adsorption of associated gases (CH₄ and CO₂) will further suppress helium diffusion, while H₂ as a lightweight carrier can enhance the diffusion ability of helium and H₂ itself to a certain extent. The research results provide theoretical references for understanding the microscopic migration and occurrence characteristics of helium in coal-measure gas.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 1194-1208"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822611","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quantitative characterization of tectonic characteristics of intraplate small-displacement strike-slip faults: A case study of the FI17 strike-slip fault zone in the Fuman Oilfield, Tarim Basin, NW China","authors":"Xiaofei Fu,&nbsp;Chang Feng,&nbsp;Yintao Zhang,&nbsp;Hai Wu,&nbsp;Jingshuang Luo,&nbsp;Zhaohan Xie,&nbsp;Haixue Wang,&nbsp;Jun Feng,&nbsp;Wenhao Jia","doi":"10.1016/S1876-3804(26)60736-7","DOIUrl":"10.1016/S1876-3804(26)60736-7","url":null,"abstract":"<div><div>Intraplate small-displacement strike-slip faults cannot be identified accurately and quantitatively analyzed quantitatively by conventional techniques. To clarify the tectonic characteristics and deformation process of intraplate small-displacement strike-slip faults, taking the Fuman Oilfield in the northern Tarim Basin as an example, structural physical simulation experiments were designed based on the geological conditions of the study area. Laser scanning was adopted to elaborately and quantitatively analyze the deformation features and differences of the strike-slip faults at each evolutionary stage. This study indicates that the deformation of the F_I17 fault zone in the Fuman Oilfield evolves in four stages: diffuse deformation, R-shear fracture, branched fault interconnection, and through-going principal displacement zone (PDZ). During the evolution of the strike-slip fault zone, en echelon anticlines serve as a diagnostic marker for R-shear fracture, and their relief amplitude represents a vital parameter to classify evolutionary stages. A “Net Deformation Magnitude” method is proposed, which can effectively remove post-tectonic stratigraphic deformations irrelevant to strike-slip-related folds and extract fold geometries and uplift amplitudes solely generated by strike-slip faulting. This method further enables quantitative characterization of along-strike heterogeneities in deformation intensity and connectivity of strike-slip fault zones, thereby realizing integrated seismic-geological interpretation. A case study of the Fuman Oilfield demonstrates that the F_I17 fault zone is currently in the branched fault interconnection stage, characterized by alternating through-going and disconnected segments along its strike. The findings establish a geological model for the refined interpretation of intraplate small-displacement strike-slip faults. Furthermore, the newly recognized fault-karst traps associated with R-shear fractures are expected to become promising new targets for hydrocarbon exploration.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 925-939"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822898","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Differential enrichment mechanisms and quantitative evaluation on controlling factors of organic matter in Cambrian Qiongzhusi Formation shale in Deyang-Anyue rift trough, Sichuan Basin, China","authors":"Caihua Lin,&nbsp;Wei Yang,&nbsp;Kesu Zhong,&nbsp;Guoqi Wei,&nbsp;Xianglu Tang,&nbsp;Zhenxue Jiang,&nbsp;Demin Shi,&nbsp;Xinyue Zhang,&nbsp;Wenliang Shang,&nbsp;Zhe Wu,&nbsp;Yuhan Nie","doi":"10.1016/S1876-3804(26)60744-6","DOIUrl":"10.1016/S1876-3804(26)60744-6","url":null,"abstract":"<div><div>Based on microscopic observations, total organic carbon (TOC) content measurements, and major, trace, and rare earth element analyses of core samples from the Cambrian Qiongzhusi Formation shale at different structural positions within the Deyang–Anyue rift trough of Sichuan Basin, this study employs a combined geochemical and random forest algorithm to qualitatively and quantitatively identify the controlling factors of organic matter enrichment in black shales, and to elucidate the patterns of organic matter enrichment under the influence of tectono-sedimentary differentiation within the rift trough. The results are obtained in four aspects. First, the Qiongzhusi shales were deposited under a warm and humid climate with intense chemical weathering. From the extra-trough to the intra-trough settings, paleoproductivity and sedimentary environmental restriction gradually increased, whereas terrigenous detrital input and redox potential progressively decreased. Moreover, hydrothermal activity intensity diminished from the trough margin toward the extra-trough and intra-trough areas. Second, vertically, layers 1 and 3, which remained under persistently high productivity and reducing conditions, exhibit high organic matter enrichment; layer 5 shows relatively high enrichment due to the high level of organism abundance period; layer 7, characterized by limited marine transgression, exhibits the lowest enrichment, attributed to reduced productivity, weakened reducing conditions, and enhanced activities of terrigenous detritus and hydrothermal inputs. Third, the random forest model demonstrates a satisfactory performance in fitting the organic matter enrichment in black shales, revealing that it is primarily governed by paleoproductivity, secondarily by redox conditions, and to a lesser extent influenced by terrigenous detrital input and hydrothermal activity. Fourth, for organic-rich shale gas exploration, vertically, layers 1, 3, and 5 all show great exploration potential; laterally, priority should be given to the central intra-trough area north of the central zone of the rift trough. These findings contribute to a better understanding of the organic matter enrichment mechanisms in the Qiongzhusi Formation shales of the Sichuan Basin, and provide a geological theoretical basis for shale gas exploration and source rock evaluation.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 1041-1054"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822923","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Near-wellbore three-dimensional non-planar fracture propagation model","authors":"Sanbai Li,&nbsp;Xibing Li,&nbsp;Diyuan Li,&nbsp;Hongzhuo Fan,&nbsp;Xing Su","doi":"10.1016/S1876-3804(26)60751-3","DOIUrl":"10.1016/S1876-3804(26)60751-3","url":null,"abstract":"<div><div>To address the computational challenges of 3D non-planar fracture propagation near the wellbore during hydraulic fracturing, a hybrid numerical model based on the Displacement Discontinuity/Fictitious Stress Method (DDM/FSM) and Finite Volume/Finite Element Method (FVM/FEM) was developed, incorporating a dynamic mesh tracking technique for the fracture front. This 3D non-planar model, constrained by wellbore boundary conditions, was validated for accuracy and reliability, and subsequently used to analyze fracture morphology under stress shadow effects and its key controlling factors. The results indicate that fracture propagation is jointly governed by far-field stress and wellbore-fracture induced stress. Specifically, wellbore-induced stress dominates initiation and reorientation of fractures within three times the wellbore radius, while far-field stress dictates the propagation direction beyond this range. Furthermore, initial fracture dip and fracture number significantly influence morphology: a larger angle between the fracture and the minimum principal stress increases the reorientation distance, whereas a higher number of initial fractures intensify differential propagation and localized reorientation behavior.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 1140-1153"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822559","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Wellbore stability issues from exothermic pyrite oxidation causing temperature anomalies in the Pliocene Cisubuh Formation, onshore North West Java Basin, Indonesia","authors":"D S Basuki,&nbsp;S D Susilo,&nbsp;I A Sadisun,&nbsp;N B Setiawan,&nbsp;A M Ramdhan,&nbsp;B Sapiie","doi":"10.1016/S1876-3804(26)60752-5","DOIUrl":"10.1016/S1876-3804(26)60752-5","url":null,"abstract":"<div><div>The localized thermal anomalies caused by exothermic pyrite oxidation and their geomechanical implications in the Pliocene Cisubuh Formation of the onshore North West Java Basin are investigated in this study. X-ray diffraction analysis, thermodynamic modeling, multistage triaxial tests, and swelling tests are conducted, and a coupled thermo-chemo-poroelastic geomechanical model is developed to evaluate wellbore stability under elevated temperature conditions. Thermodynamic modeling indicates that the heat released by pyrite oxidation is sufficient to explain the observed thermal anomalies in the Cisubuh Formation under ideal conditions. Field data further show temperature anomalies of 20–30 °C above the regional normal temperature in pyrite-rich intervals, supporting pyrite oxidation as the dominant diagenetic heat source. Laboratory triaxial and swelling tests under elevated temperature conditions reveal significant variations in chemical sensitivity within the Cisubuh shale, show that shales lose up to 15.25% cohesion and 13.09% of its internal friction coefficient after 5 d of fluid exposure. Model validation using data from Well X in the Subang Field demonstrates that abnormally high temperatures elevate the risk of wellbore instability, increasing the mud weight to 1.6 g/cm<span><span>^c</span></span> prevents delayed collapse and maintains wellbore stability, while enabling drilling completion 3 d ahead of schedule, corresponding to an estimated operational saving of approximately USD 1.2 million.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 1154-1165"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822565","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"New insights and exploration directions for Ordovician platform-margin reef-shoal fault-karst reservoirs in the Manxi area, Tarim Basin, NW China","authors":"Xuefeng Bai,&nbsp;Yuangao Zhang,&nbsp;Bo Yan,&nbsp;Wenqing Pan,&nbsp;Junlong Zhang,&nbsp;Yang Liu,&nbsp;Yunfeng Zhang,&nbsp;Yanqing Cao,&nbsp;Shili Dai,&nbsp;Fuwen Luo,&nbsp;Linfeng Cheng","doi":"10.1016/S1876-3804(26)60737-9","DOIUrl":"10.1016/S1876-3804(26)60737-9","url":null,"abstract":"<div><div>Based on data including seismic interpretation, well logs and core slice, analyses were conducted on seismic reflection patterns, stages and distribution of faults, planar distribution of sedimentary facies, types of reservoir spaces, and genesis of reservoirs. This study identified the types of Ordovician carbonate platforms in the Manxi area of the Tarim Basin, analysed the controlling factors for high-quality reservoirs and hydrocarbon accumulation, established an accumulation model, and proposed potential exploration targets of oil and gas. The research indicates that the Ordovician in the Manxi area is characterized by a rimmed platform depositional system, where the platform-margin reef-shoal complexes cover an area of approximately 5 091 km<span><span>^b</span></span>. These complexes, superimposed with multi-stage karstification and reticulated fractures, form high-quality fractured-vuggy reservoirs, which exhibit a north-south orientation, large-scale distribution, and excellent storage capacity. The Ordovician platform-margin reef-shoal zone is situated within the hydrocarbon-generation center comprising the source rocks in the Precambrian Yuman rift trough, the Cambrian Yuertusi Formation, and the Cambrian to Ordovician platform-margin foreslope facies. Large-scale hydrocarbon-enriched zones are densely distributed in a north-south trend within the interval from the Ordovician Penglaiba Formation to the third member of the Yingshan Formation, while exhibiting a linear distribution pattern from the second member of the Yingshan Formation to the Yijianfang Formation. Guided by these insights, Well Qingyu 2 was drilled, and it achieved a high flow rate of 105.6×10<span><span>^d</span></span> m<span><span>^c</span></span>/d gas from the second member of the Yingshan Formation during test, with a stable tubing pressure of 107 MPa. This records a significant exploration breakthrough in the Ordovician platform-margin zones in the Manxi area, and reveals a new domain for reserve growth. The research results provide valuable guidance for exploring ultra-deep carbonate reservoirs in the Tarim Basin.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 940-950"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822917","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Permeability logging method and its application based on pure Stoneley waves induced by continuous low frequency planar shock waves","authors":"Ning Li,&nbsp;Junqiang Lu,&nbsp;Qingbin Guo,&nbsp;Chengwen Xiao,&nbsp;Peng Liu,&nbsp;Han Tian,&nbsp;Baiyong Men,&nbsp;Hongliang Wu,&nbsp;Yusheng Li,&nbsp;Zhenyu Qin,&nbsp;Huajun Fan,&nbsp;Kewen Wang","doi":"10.1016/S1876-3804(26)60735-5","DOIUrl":"10.1016/S1876-3804(26)60735-5","url":null,"abstract":"<div><div>Shock-tube core experiments have provided an important finding, that is, the low frequency acoustic field generated by planar shock waves can induce pure Stoneley waves in a borehole, with their amplitude attenuation demonstrating a definite correlation with fracture width and permeability. Accordingly, a method was proposed to transmit low frequency planar shock waves in a borehole through axially polarized axial vibration, thereby continuously inducing pure Stoneley waves. Equations were also derived for calculating fracture width and permeability from Stoneley wave amplitude attenuation. Moreover, the permeability logging prototype was successfully developed, together with acquisition and processing software incorporating amplitude-attenuation extraction and permeability calculation. The operability, stability, and measurement performance of the logging tool were tested and verified in two standard wells, R91 and LS2. In the 10 000-m extra-deep well SDTK1 in the Tarim Basin, matrix and fracture permeability curves of extra-deep carbonate formations were obtained in a single downhole logging. The results were immediately calibrated with the data of quasi-in-situ nuclear magnetic resonance (NMR) permeability measurement on full-diameter drilling cores taken from the same interval of the well. The results show that the proposed method performs well in quantitative permeability evaluation of extra-deep carbonate reservoirs and provides a new technical approach for permeability logging evaluation in other types of reservoirs. This theoretical and technological breakthrough provides an innovative means for quantitative permeability evaluation in reservoir logging.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"53 4","pages":"Pages 915-924"},"PeriodicalIF":10.7,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148822897","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}