Petroleum Exploration and Development最新文献

{"title":"Data credibility evaluation method for formation water in oil and gas fields and its influencing factors","authors":"Wei LI,&nbsp;Wuren XIE,&nbsp;Saijun WU,&nbsp;Yanhua SHUAI,&nbsp;Xingzhi MA","doi":"10.1016/S1876-3804(25)60572-6","DOIUrl":"10.1016/S1876-3804(25)60572-6","url":null,"abstract":"<div><div>The formation water sample in oil and gas fields may be polluted in processes of testing, trial production, collection, storage, transportation and analysis, making the properties of formation water not be reflected truly. This paper discusses identification methods and the data credibility evaluation method for formation water in oil and gas fields of petroliferous basins within China. The results of the study show that: (1) the identification methods of formation water include the basic methods of single factors such as physical characteristics, water composition characteristics, water type characteristics, and characteristic coefficients, as well as the comprehensive evaluation method of data credibility proposed on this basis, which mainly relies on the correlation analysis sodium chloride coefficient (<em>r</em>_Na/<em>r</em>_Cl) and desulfurization coefficient [<em>r</em>_SO4×100/(<em>r</em>_Cl+ <em>r</em>_SO4)] and combines geological background evaluation; (2) The basic identifying methods for formation water enable the preliminary identification of hydrochemical data and the preliminary screening of data on site, the proposed comprehensive method realizes the evaluation by classifying the CaCl₂-type water into types A-I to A-VI and the NaHCO₃-type water into types B-I to B-IV, so that researchers can make in-depth evaluation on the credibility of hydrochemical data and analysis of influencing factors; (3) When the basic methods are used to identify the formation water, the formation water containing anions such as CO₃^2-, OH^- and NO₃^-, or the formation water with the sodium chloride coefficient and desulphurization coefficient not matching the geological setting, are all invaded with surface water or polluted by working fluid; (4) When the comprehensive method is used, the data credibility of A-I, A-II, B-I and B-II formation water can be evaluated effectively and accurately only if the geological setting analysis in respect of the factors such as formation environment, sampling conditions, condensate water, acid fluid, leaching of ancient weathering crust, and ancient atmospheric fresh water, is combined, although such formation water is believed with high credibility.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 361-376"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873171","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Response of organic matter pore development to functional groups in overmature marine shale: Insights from AFM-IR spectroscopy","authors":"Jianhua ZHAO ,&nbsp;Keyu LIU ,&nbsp;Shenghui ZHAO ,&nbsp;Qinhong HU ,&nbsp;Wei WU ,&nbsp;Yang CHEN ,&nbsp;Guoheng LIU ,&nbsp;Junqian LI ,&nbsp;Lingjie YU ,&nbsp;Zuhui YOU ,&nbsp;Ye WANG","doi":"10.1016/S1876-3804(25)60578-7","DOIUrl":"10.1016/S1876-3804(25)60578-7","url":null,"abstract":"<div><div>Taking the Lower Silurian Longmaxi Formation shale in the Sichuan Basin as an example, this study employs atomic force microscopy-based infrared (AFM-IR) spectroscopy to analyze the submicron-scale molecular functional groups of different types and occurrences of organic matter. Combined with the quantitative evaluation of pore development via scanning electron microscopy (SEM), the response of organic pore formation and evolution mechanisms to chemical composition and structural evolution of organic matter in overmature marine shale is investigated. The results indicate that the AFM-IR spectra of graptolite periderms and pyrobitumen in shale are dominated by the stretching vibrations of conjugated C=C bonds in aromatic compounds at approximately 1 600 cm^-1, with weak absorption peaks near 1 375, 1 450 and 1 720 cm^-1, corresponding to aliphatic chains and carbonyl/carboxyl functional groups. Overall, the AFM-IR structural indices (A and C factors) of organic matter show a strong correlation with visible porosity in shales of equivalent maturity. Lower A and C factor values correlate with enhanced development of organic pores, which is associated with the detachment of more aliphatic chains and oxygen-containing functional groups during thermal evolution. Pyrobitumen-clay mineral composites generally exhibit superior pore development, likely attributable to clay mineral dehydration participating in hydrocarbon generation reactions that promote the removal of more functional groups. Additionally, hydrocarbon generation within organic-clay composites during high–over mature stages may induce volumetric expansion, resulting in microfracturing and hydrocarbon expulsion. The associated higher hydrocarbon expulsion rates promote the formation of larger pores and fracture-shaped pores along the flake-shaped clay minerals. This study highlights that the research of submicron-scale molecular functional groups provides a deeper understanding of organic matter evolution and pores development mechanisms in overmature shales, thereby offering critical theoretical parameters for reservoir evaluation in shale oil and gas exploration.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 445-458"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873165","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Fracture parameter diagnostic method during staged multi-cluster fracturing based on distributed temperature sensing","authors":"Cao WEI ,&nbsp;Haitao LI ,&nbsp;Xiaohua ZHU ,&nbsp;Nan ZHANG ,&nbsp;Hongwen LUO ,&nbsp;Kun TU ,&nbsp;Shiqing CHENG","doi":"10.1016/S1876-3804(25)60582-9","DOIUrl":"10.1016/S1876-3804(25)60582-9","url":null,"abstract":"<div><div>The Carter model is used to characterize the dynamic behaviors of fracture growth and fracturing fluid leakoff. A thermo-fluid coupling temperature response forward model is built considering the fluid flow and heat transfer in wellbore, fracture and reservoir. The influences of fracturing parameters and fracture parameters on the responses of distributed temperature sensing (DTS) are analyzed, and a diagnosis method of fracture parameters is presented based on the simulated annealing algorithm. A field case study is introduced to verify the model's reliability. Typical V-shaped characteristics can be observed from the DTS responses in the multi-cluster fracturing process, with locations corresponding to the hydraulic fractures. The V-shape depth is shallower for a higher injection rate and longer fracturing and shut-in time. Also, the V-shape is wider for a higher fracture-surface leakoff coefficient, longer fracturing time and smaller fracture width. Additionally, the cooling effect near the wellbore continues to spread into the reservoir during the shut-in period, causing the DTS temperature to decrease instead of rise. Real-time monitoring and interpretation of DTS temperature data can help understand the fracture propagation during fracturing operation, so that immediate measures can be taken to improve the fracturing performance.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 496-505"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873243","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Connotation, pathways, and significance of building China into an “energy powerhouse”;","authors":"Caineng ZOU ,&nbsp;Shixiang LI ,&nbsp;Bo XIONG ,&nbsp;Zhi YANG ,&nbsp;Hanlin LIU ,&nbsp;Guosheng ZHANG ,&nbsp;Feng MA ,&nbsp;Songqi PAN ,&nbsp;Chunxiao GUAN ,&nbsp;Yingbo LIANG ,&nbsp;Boning TANG ,&nbsp;Songtao WU ,&nbsp;Yin LONG ,&nbsp;Ziheng WANG","doi":"10.1016/S1876-3804(25)60584-2","DOIUrl":"10.1016/S1876-3804(25)60584-2","url":null,"abstract":"<div><div>By summarizing the characteristics of the global energy structure and China's energy resource endowment, this study analyzes the historical context and opportunities for China to build an “energy powerhouse”;, and proposes pathways and measures for its realization. It is indicated that the energy resource endowment in China is characterized by abundant coal, limited oil and gas, and vast renewable potential, coupled with an energy consumption structure characterized by high coal consumption, low oil and gas consumption, and rapidly growing renewable energy use. The “whole-energy system”; approach that integrates multi-energy complementarity, green development, stable supply, smart utilization and carbon neutrality is an effective solution to addressing energy transition and energy independence. To build an “energy powerhouse”;, China can follow the approach of the steady and orderly low-carbon development of fossil fuels, the safe and scaled development of new energy, the integrated development of a carbon-neutral “whole-energy system”;, and the shared development of the “Belt and Road”; energy corridor. The construction of an “energy powerhouse”; should follow a “three-phase”; strategic pathway: from 2025 to 2030, achieving peak primary energy consumption and “carbon peaking”;; from 2031 to 2050, energy production will achieve parity with consumption for the first time, striving for “energy independence”;; and from 2051 to 2060, aiming for “carbon neutrality”;, and establishing an “energy powerhouse”;. Building an “energy powerhouse”; will fundamentally safeguard national energy security, advance the achievement of carbon neutrality goals, provide Chinese solutions for global energy transition and green Earth construction, and support the modernization and great rejuvenation of the Chinese nation.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 519-535"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873245","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Geochemical differences in natural gas of Sinian Dengying Formation on the east and west sides of the Deyang-Anyue rift trough and their genesis, Sichuan Basin, SW China","authors":"Zezhang SONG ,&nbsp;Shigui JIN ,&nbsp;Bing LUO ,&nbsp;Qingyong LUO ,&nbsp;Xingwang TIAN ,&nbsp;Dailin YANG ,&nbsp;Ziyu ZHANG ,&nbsp;Wenjin ZHANG ,&nbsp;Luya WU ,&nbsp;Jiali TAO ,&nbsp;Jiahuan HE ,&nbsp;Wenzheng LI ,&nbsp;Bingfei GE ,&nbsp;Guan WANG ,&nbsp;Jiawei GAO","doi":"10.1016/S1876-3804(25)60576-3","DOIUrl":"10.1016/S1876-3804(25)60576-3","url":null,"abstract":"<div><div>Taking the natural gas reservoirs of the Sinian Dengying Formation on the east and west sides (Gaoshiti-Moxi area and north slope of central Sichuan paleo-uplift on the east; Weiyuan and Well Datan-1 block on the west) of the Deyang-Anyue rift trough in the Sichuan Basin, China, as the research object, the geochemical parameters (component, isotopic composition) of natural gas from the Dengying Formation in different areas are compared, and then the differences in geochemical characteristics of Dengying natural gas on the east and west sides of the Deyang-Anyue rift trough and their genesis are clarified. First, the Dengying gas reservoirs on both sides of the rift trough are predominantly composed of oil-cracking gas with high maturity, which is typical dry gas. Second, severely modified by thermochemical sulfate reduction (TSR) reaction, the Dengying gas reservoirs on the east side exhibit high H₂S and CO₂ contents, with an elevated δ¹³C₂ value (average value higher than −29‰). The Dengying gas reservoirs in the Weiyuan area are less affected by TSR modification, though the δ¹³C₁ values are slightly greater than that of the reservoirs on the east side with partial reversal of carbon isotope composition, likely due to the water-soluble gas precipitation and accumulation mechanism. The Dengying gas reservoir of Well Datan-1 shows no influence from TSR. Third, the Dengying gas reservoirs reflect high helium contents (significantly higher than that on the east side) in the Weiyuan and Datan-1 areas on the west side, which is supposed to attribute to the widespread granites in basement and efficient vertical transport along faults. Fourth, controlled by the paleo-salinity of water medium in the depositional period of the source rock, the δ²H_CH4 values of the Dengying gas reservoirs on the west side are slightly lighter than those on the east side. Fifth, the Dengying natural gas in the Datan-1 area is contributed by the source rocks of the Sinian Doushantuo Formation and the third member of the Dengying Formation, in addition to the Cambrian Qiongzhusi Formation.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 422-434"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873786","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Equivalent force model of deformation induced by oil and gas reservoir development and its volume boundary element method solution","authors":"Xuehao PEI ,&nbsp;Yuetian LIU ,&nbsp;Liang XUE","doi":"10.1016/S1876-3804(25)60581-7","DOIUrl":"10.1016/S1876-3804(25)60581-7","url":null,"abstract":"<div><div>To address the issue that traditional finite element methods cannot fully consider the semi-infinite earth strata and have lower solution accuracy, a new equivalent force model for induced deformation during oil and gas reservoir development is derived from the perspective of semi-infinite strata. A brand-new volume boundary element numerical method solution has been developed and verified and tested. The influences of internal flow and flow boundary of the reservoir on strata deformation are equivalent to the impacts on strata deformation when external forces act at the interior and boundary of the reservoir, respectively. Calculation methods for the flow equivalent force and boundary equivalent force are provided. The deformation solution at any point in the strata can be obtained through the convolution of flow equivalent forces, boundary equivalent forces and Green's functions. After discretization, the deformation solution at any point in the strata can be obtained by multiplying the grid boundary equivalent forces, grid flow equivalent forces with their corresponding grid boundary sources and grid volume sources respectively, and then summing them up. This numerical method is termed the Volumetric Boundary Element Method (VBEM). Compared with traditional commercial simulators, VBEM fully considers the effects of reservoir flow boundaries, pore pressure gradient fields within the reservoir, and fluid mass changes within pores on formation deformation. It eliminates the need for meshing outside the reservoir, achieves significantly improved solution accuracy, and provides a new technical framework for simulating deformation induced by reservoir development.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 485-495"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873248","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Fluid characteristics, gas accumulation controlling factors and gas enrichment modes in coal reservoirs: A case study of the Upper Paleozoic in the central-eastern Ordos Basin, NW China","authors":"Shida CHEN ,&nbsp;Dazhen TANG ,&nbsp;Wei HOU ,&nbsp;Daojun HUANG ,&nbsp;Yongzhou LI ,&nbsp;Jianling HU ,&nbsp;Hao XU ,&nbsp;Shu TAO ,&nbsp;Song LI ,&nbsp;Shuling TANG","doi":"10.1016/S1876-3804(25)60577-5","DOIUrl":"10.1016/S1876-3804(25)60577-5","url":null,"abstract":"<div><div>Based on the test and experimental data from exploration well cores of the Upper Paleozoic in the central-eastern Ordos Basin, combined with structural, burial depth and fluid geochemistry analyses, this study reveals the fluid characteristics, gas accumulation control factors and accumulation modes in the Upper Paleozoic coal reservoirs. The study indicates findings in two aspects. First, the 1 500–1 800 m interval represents the critical transition zone between open fluid system in shallow–medium depths and closed fluid system in deep depths. The reservoirs above 1 500 m reflect intense water invasion, with discrete pressure gradient distribution, and the presence of methane mixed with varying degrees of secondary biogenic gas, and they generally exhibit high water saturation and adsorbed gas undersaturation. The reservoirs deeper than 1 800 m, with extremely low permeability, are self-sealed, and contains closed fluid systems formed jointly by the hydrodynamic lateral blocking and tight caprock confinement. Within these systems, surface runoff infiltration is weak, the degree of secondary fluid transformation is minimal, and the pressure gradient is relatively uniform. The adsorbed gas saturation exceeds 100% in most seams, and the free gas content primarily ranges from 1 m³/t to 8 m³/t (greater than 10 m³/t in some seams). Second, the gas accumulation in deep coals is primarily controlled by coal quality, reservoir-caprock assemblage, and structural position governed storage, wettability and sealing properties, under the constraints of the underground temperature and pressure conditions. High-rank, low-ash yield coals with limestone and mudstone caprocks show superior gas accumulation potential. Positive structural highs and wide and gentle negative structural lows are favorable sites for gas enrichment, while slope belts of fold limbs exhibit relatively lower gas content. This research enhances understanding of gas accumulation mechanisms in coal reservoirs and provides effective parameter reference for precise zone evaluation and innovation of adaptive stimulation technologies for deep resources.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 435-444"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873787","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Deformation and migration characteristics of bubbles moving in gas-liquid countercurrent flow in annulus","authors":"Bangtang YIN ,&nbsp;Tianbao DING ,&nbsp;Shulong WANG ,&nbsp;Zhiyuan WANG ,&nbsp;Baojiang SUN ,&nbsp;Wei ZHANG ,&nbsp;Xuliang ZHANG","doi":"10.1016/S1876-3804(25)60580-5","DOIUrl":"10.1016/S1876-3804(25)60580-5","url":null,"abstract":"<div><div>The gas-liquid countercurrent flow pattern is complex and the bubble migration velocity is difficult to predict in the process of bullheading well killing. The experiment on bubble migration in gas-liquid countercurrent flow in annulus is carried out under different working conditions to reveal how the wellbore inclination angle, liquid phase property and countercurrent liquid velocity affect the bubble deformation and bubble migration trajectory/velocity, and to establish a bubble migration velocity prediction model. The bubbles in the countercurrent flow mainly migrate in two modes: free rising of isolated bubbles, and interactive rising of multiple bubbles. The bubbles migrate by an S-shaped trajectory in the countercurrent flow. With the increase of countercurrent liquid velocity, the lateral oscillation of bubbles is intensified. The increases of wellbore inclination angle, liquid density and liquid viscosity make the bubble migration trajectory gradually to be linear. The bubble is generally ellipsoidal during its rising. The wellbore inclination angle has little effect on the degree of bubble deformation. The bubbles are ellipsoidal during rising, with little influence of wellbore inclination angle on bubble deformation. With the increase of liquid viscosity and density, the aspect ratio of the bubble decreases. As the wellbore inclination angle increases, the bubble migration velocity gradually decreases. As the liquid viscosity increases, the bubble migration velocity decreases. As the liquid density increases, the bubble migration velocity increases slightly. The established bubble migration velocity prediction model yields errors within ± 15 %, and demonstrates broad applicability across a wide range of operating conditions.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 471-484"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873249","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Source and exploration potential of the ultra-deep Cambrian petroleum in Well XT-1, Tarim Basin, NW China","authors":"Jin SU ,&nbsp;Xiaomei WANG ,&nbsp;Chengdong Zhang ,&nbsp;Xianzhang YANG ,&nbsp;Jin LI ,&nbsp;Yupeng YANG ,&nbsp;Haizu ZHANG ,&nbsp;Yu FANG ,&nbsp;Chunlong YANG ,&nbsp;Chenchen FANG ,&nbsp;Yalong WANG ,&nbsp;Caiyun WEI ,&nbsp;Na WENG ,&nbsp;Shuichang ZHANG","doi":"10.1016/S1876-3804(25)60574-X","DOIUrl":"10.1016/S1876-3804(25)60574-X","url":null,"abstract":"<div><div>The ultra-deep (deeper than 8 000 m) petroleum in the platform-basin zones of the Tarim Basin has been found mainly in the Lower Paleozoic reservoirs located to the east of the strike-slip fault F5 in the north depression. However, the source and exploration potential of the ultra-deep petroleum in the Cambrian on the west of F5 are still unclear. Through the analysis of lithofacies and biomarkers, it is revealed that there are at least three kinds of isochronous source rocks (SRs) in the Cambrian Newfoundland Series in Tarim Basin, which were deposited in three sedimentary environments, i.e. sulfide slope, deep-water shelf and restricted bay. In 2024, Well XT-1 in the western part of northern Tarim Basin has yielded a high production of condensate from the Cambrian. In the produced oil, entire aryl-isoprenoid alkane biomarkers were detected, but triaromatic dinosterane was absent. This finding is well consistent with the geochemical characteristics of the Newfoundland sulfidized slope SRs represented by those in wells LT-1 and QT-1, suggesting that the Newfoundland SRs are the main source of the Cambrian petroleum discovered in Well XT-1. Cambrian crude oil of Well XT-1 also presents the predominance of C₂₉ steranes and is rich in long-chain tricyclic terpanes (up to C₃₉), which can be the indicators for effectively distinguishing lithofacies such as siliceous mudstone and carbonate rock. Combined with the analysis of hydrocarbon accumulation in respect of conduction systems including thrust fault and strike-slip fault, it is found that the area to the west of F5 is possible to receive effective supply of hydrocarbons from the Cambrian Newfoundland SRs in Manxi hydrocarbon-generation center. This finding suggests that the area to the west of F5 will be a new target of exploration in the Cambrian ultra-deep structural-lithologic reservoirs in the Tarim Basin, in addition to the Cambrian ultra-deep platform-margin facies-controlled reservoirs in the eastern part of the basin.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 391-407"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873784","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Technical progress and application of global carbon dioxide capture, utilization and storage cluster","authors":"Guofeng WANG ,&nbsp;Weifeng LYU ,&nbsp;Kai CUI ,&nbsp;Zemin JI ,&nbsp;Heng WANG ,&nbsp;Chang HE ,&nbsp;Chunyu HE","doi":"10.1016/S1876-3804(25)60585-4","DOIUrl":"10.1016/S1876-3804(25)60585-4","url":null,"abstract":"<div><div>By systematically reviewing the development status of global carbon dioxide capture, utilization and storage (CCUS) cluster, and comparing domestic and international CCUS industrial models and successful experiences, this study explores the challenges and strategies for the scaled development of the CCUS industry of China. Globally, the CCUS industry has entered a phase of scaled and clustered development. North America has established a system of key technologies in large-scale CO₂ capture, long-distance pipeline transmission, pipeline network optimization, and large-scale CO₂ flooding for enhanced oil recovery (CO₂-EOR), with relatively mature cluster development and a gradual shift in industrial model from CO₂-EOR to geological storage. The CCUS industry of China has developed rapidly across all segments but remains in the early stage of cluster development, facing challenges such as absent business model, insufficient policy support, and technological gaps in core areas. China needs to improve the policy support system to boost enterprises participation across the entire industrial chain, strengthen top-level design and medium- to long-term planning to accelerate demonstration projects construction for whole-process CCUS clusters, advance for a full-chain technological system, including low-cost capture, pipeline optimization and EOR/storage integration technologies, and strengthen personnel training, strengthen discipline construction and university-enterprise research cooperation.</div></div>","PeriodicalId":67426,"journal":{"name":"Petroleum Exploration and Development","volume":"52 2","pages":"Pages 536-547"},"PeriodicalIF":7.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143873246","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}