Energy Geoscience最新文献

{"title":"Petroleum system, filling history and age appraisal of source rocks of the Niger Delta Basin: Fingerprinting of pentacyclic triterpenoids","authors":"Timothy Chibuike Anyanwu ,&nbsp;Bassey Offiong Ekpo","doi":"10.1016/j.engeos.2025.100399","DOIUrl":"10.1016/j.engeos.2025.100399","url":null,"abstract":"<div><div>Gas chromatography-mass spectrometry (GC-MS) was used to analyze the pentacyclic triterpenoid distributions, specifically hopane and oleanane fingerprints, in 24 crude oil samples from the Niger Delta depobelts, with the aim of defining the petroleum system, filling history, and the age of source rock producing these oils. The results indicate that the Niger Delta oils belong to a single fluvio-deltaic petroleum system, reflecting similar source organic facies and depositional environments. Geochemical parameters, including C₂₉/C₃₀ hopane ratios, oleanane index, Ts/Tm, (Ts/(Ts + Tm)), moretane/C₃₀ hopane ratios, and C₃₂ 22S/(22S + 22R) ratios, suggest oxic conditions during source rock deposition and thermal maturity of the oils. The presence of terrigenous organic matter and complex filling history are also evident and influenced by multiple phases of sedimentation, and petroleum generation. A comparative plot of geologic time (Paleogene-Neogene age) and oleanane percentage composition show that the crude oils are constrained to the chronostratigraphic ages of their respective depobelts, demonstrating the potential of oleanane-derived parameters for relative dating of hydrocarbon sources, complementing traditional index fossil methods.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100399"},"PeriodicalIF":0.0,"publicationDate":"2025-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143714938","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":"Gasbag phase-change carbon dioxide energy storage: Development and economic study","authors":"Ao Ren ,&nbsp;Yilin Liu ,&nbsp;Qiji Sun","doi":"10.1016/j.engeos.2025.100400","DOIUrl":"10.1016/j.engeos.2025.100400","url":null,"abstract":"<div><div>The Gasbag Phase-change Carbon Dioxide Energy Storage System leverages elastic gasbags to store carbon dioxide under varying geographical conditions. This approach utilizes the phase-change sensible heat effect to efficiently manage energy storage and release. This technology requires lower pressure and temperature control, resulting in reduced energy consumption and improved efficiency. Additionally, it is less restricted by geographical factors to a certain extent, enabling the formation of a closed-loop system. This contributes to the development of new energy utilization systems. The article examines and compares two experimental energy storage projects employing elastic gasbags to maintain a constant pressure supply of carbon dioxide on the low-pressure side. It further details the precise calculation methods for system cycle efficiency and energy storage density while analyzing energy losses incurred during the storage and release phases. Finally, an economic analysis is conducted using specific data, demonstrating that optimizing temperature and pressure parameters at various nodes enhances overall system efficiency while reducing energy consumption. Furthermore, the study highlights the system's high sensitivity to grid electricity prices. This research is anticipated to contribute to the development of more efficient and reliable energy storage solutions for power systems, addressing the growing energy demands and sustainability challenges.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100400"},"PeriodicalIF":0.0,"publicationDate":"2025-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143681702","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":"Review on assessment methodology for hydrothermal resources based on renewable energy attributes","authors":"Yifan Bao ,&nbsp;Fengnian Zhao ,&nbsp;Li Du ,&nbsp;Zhonghe Pang ,&nbsp;Yanlong Kong ,&nbsp;Fengtian Yang ,&nbsp;Chen Yang ,&nbsp;Jiachao Huang ,&nbsp;Chunhong Ma ,&nbsp;Minghui Wu ,&nbsp;Peiyao Dong","doi":"10.1016/j.engeos.2025.100397","DOIUrl":"10.1016/j.engeos.2025.100397","url":null,"abstract":"<div><div>Accurate and effective assessment of hydrothermal resources is crucial in the geothermal industry, given that the global installed capacity for direct use (173 303 MW) significantly exceeds that for geothermal power (16 260 MW). Despite the widespread application of various geothermal resource assessment methods, including the volumetric method, Monte Carlo method, analogy, statistical analysis, and numerical methods, there are still limitations faced in terms of data precision and model uncertainty assessment, fracture heterogeneity, boundary conditions, renewable energy attributes, integration of geothermal compensation mechanisms under the “extraction-injection” balance, diversification of economic evaluation metrics, and the establishment of standardized assessment criteria. This review outlines the various methods suitable for different stages of the hydrothermal resource assessment process, and proposes future technical approaches for sustainable development, including improving the accuracy of assessments and establishing standards for geothermal resource evaluation methods, in order to enhance the efficiency of geothermal resource utilization.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100397"},"PeriodicalIF":0.0,"publicationDate":"2025-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143714937","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":"Application of iso-frequency extractions and spectral frequency blending in hydrocarbon delineation of thin-pay and thick-pay reservoirs, Niger Delta Basin","authors":"David O. Anomneze ,&nbsp;Vivian O. Oguadinma ,&nbsp;Irewole J. Ayodele ,&nbsp;Norbert E. Ajaegwu","doi":"10.1016/j.engeos.2025.100396","DOIUrl":"10.1016/j.engeos.2025.100396","url":null,"abstract":"<div><div>Delineation of hydrocarbon-bearing sands and the extent of accumulation using seismic data is a reoccurring challenge for many fields. This study addressed the existing challenges of delineating a known hydrocarbon region for a thin-pay reservoir using conventional attributes extraction methods. The efficacy of applying iso-frequency extraction and spectral frequency blending in identifying thin-pay and thick-pay reservoirs on seismic was tested by utilizing 3D seismic data and well logs data of Terra field in the Western Niger Delta Basin. Well tops of all the reservoirs in the field were picked and two reservoirs that correspond to thin- and thick-pay reservoirs, namely A and F were identified respectively. The gross pay thickness of reservoir A is 18 ft while that of reservoir F is 96 ft. Conventional attribute extraction such as RMS amplitude, minimum amplitude, and average energy can be used to identify the hydrocarbon-bearing region in reservoir F but was not applicable for identifying the thin-pay reservoir A. This prompted the interest of using iso-frequency extractions and spectral frequency blending of three iso-frequency cubes of 12 Hz, 30 Hz, and 70 Hz to get a spectral frequency RGB cube. The 12 Hz iso-frequency can be used to partially identify hydrocarbon-bearing region in reservoir A while the 30Hz iso-frequency can be used to partially identify hydrocarbon-bearing region in reservoir F. The results show that time slices from the spectral frequency blended cube were able to delineate both the thin-pay and thick-pay hydrocarbon-bearing regions as high amplitude. The extractions also conformed to the structure of the two reservoirs. However, there seems to be a color difference in the amplitude display for both reservoirs. The thick-pay reservoir showed a red color on the time slice while the thin-pay reservoir showed a green color. This study has shown that spectral frequency blending is a more effective tool than conventional attributes extractions in identifying hydrocarbon-bearing region using seismic data. The methodology utilized in this study can be applied to other fields with similar challenges and for identifying prospective hydrocarbon bearing areas.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100396"},"PeriodicalIF":0.0,"publicationDate":"2025-03-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143637498","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":"Unlocking the potentials of depleted gas fields: A numerical evaluation of underground CO2 storage and geothermal energy harvesting","authors":"Amrou Al-Alawi ,&nbsp;Mingjie Chen ,&nbsp;El Hadi Mazouz ,&nbsp;Tartil Al-Abri ,&nbsp;Usman Taura ,&nbsp;Mohammad Reza Nikoo ,&nbsp;Ali Al-Maktoumi","doi":"10.1016/j.engeos.2025.100395","DOIUrl":"10.1016/j.engeos.2025.100395","url":null,"abstract":"<div><div>Using partial underground CO₂ storage as a working agent to harvest geothermal energy is a promising carbon capture, utilization, and storage (CCUS) method. It is particularly economically feasible to use or retrofit the existing infrastructure of a hydrocarbon field. Although technical advantages of integrated CO₂ sequestration and CO₂-circulated geothermal harvest using depleted hydrocarbon reservoirs have been reported, quantitative evaluations of economic benefits using existing wells of realistic reservoirs are rare. In this study, a 3-D hydrothermal flow model is built for the Triassic Argilo-Gréseux Supérieur (TAGS) Formation of the Toual gas field, Algeria using Schlumberger Petrel and CMG-STARS software. A three-phase operational scheme is proposed for sequential CO₂ sequestration and CO₂-circulated geothermal extraction over 100 years. The first phase is injecting CO₂ for 30 years, followed by concurrent cold CO₂ injection and hot CO₂ extraction in the developed CO₂ plume (circulation) for 40 years as the second phase. In the third phase, producing wells in the second phase are converted to injection wells while outer wells start to extract hot CO₂ for another 30 years. Scenario 1 is simulated using the selected nine existing wells of the field, while an optimized Scenario 2 is designed and simulated by adding seven newly drilled wells in addition to the existing wells. Scenario 3 shares the same numerical simulation of Scenario 1, but assumes the selected nine existing wells are newly drilled for the economic evaluation. Levelized Cost of Energy (<em>LCOE</em>), Net Present Value (<em>NPV</em>), and Return on Investment (<em>ROI</em>) are used as economic indicators. The results demonstrate that Scenario 2, which combines the use of existing and newly drilled wells, yields improved economic metrics compared to Scenario 1: 0.97 USD/MWh vs. 1.54 USD/MWh for <em>LCOE</em> and $2.9M vs. $1.1M for <em>NPV</em>. Both scenarios represent profitable endeavors, with <em>ROI</em> values of 1.3 % and 1.5 %, respectively. In contrast, Scenario 3 represents the worst-case scenario, with the highest <em>LCOE</em> at 2.90 USD/MWh and the lowest <em>NPV</em> and <em>ROI</em> at -$0.4M and -0.2 %, respectively. The negative <em>NPV</em> and <em>ROI</em> in Scenario 3 indicates that CO₂-circulated geothermal harvesting in aquifers or giant depleted hydrocarbon fields, without leveraging existing infrastructure, is economically infeasible.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100395"},"PeriodicalIF":0.0,"publicationDate":"2025-03-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143681703","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":"Hybrid CO2 thermal system for post-steam heavy oil recovery: Insights from microscopic visualization experiments and molecular dynamics simulations","authors":"Ning Lu ,&nbsp;Xiaohu Dong ,&nbsp;Haitao Wang ,&nbsp;Huiqing Liu ,&nbsp;Zhangxin Chen ,&nbsp;Yu Li ,&nbsp;Deshang Zeng","doi":"10.1016/j.engeos.2025.100394","DOIUrl":"10.1016/j.engeos.2025.100394","url":null,"abstract":"<div><div>The hybrid CO₂ thermal technique has achieved considerable success globally in extracting residual heavy oil from reserves following a long-term steam stimulation process. Using microscopic visualization experiments and molecular dynamics (MD) simulations, this study investigates the microscopic enhanced oil recovery (EOR) mechanisms underlying residual oil removal using hybrid CO₂ thermal systems. Based on the experimental models for the occurrence of heavy oil, this study evaluates the performance of hybrid CO₂ thermal systems under various conditions using MD simulations. The results demonstrate that introducing CO₂ molecules into heavy oil can effectively penetrate and decompose dense aggregates that are originally formed on hydrophobic surfaces. A stable miscible hybrid CO₂ thermal system, with a high effective distribution ratio of CO₂, proficiently reduces the interaction energies between heavy oil and rock surfaces, as well as within heavy oil. A visualization analysis of the interactions reveals that strong van der Waals (vdW) attractions occur between CO₂ and heavy oil molecules, effectively promoting the decomposition and swelling of heavy oil. This unlocks the residual oil on the hydrophobic surfaces. Considering the impacts of temperature and CO₂ concentration, an optimal gas-to-steam injection ratio (here, the CO₂: steam ratio) ranging between 1:6 and 1:9 is recommended. This study examines the microscopic mechanisms underlying the hybrid CO₂ thermal technique at a molecular scale, providing a significant theoretical guide for its expanded application in EOR.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100394"},"PeriodicalIF":0.0,"publicationDate":"2025-03-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143620504","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":"Mechanisms of CO2 enhanced gas recovery in tight-sand gas reservoirs","authors":"Zhongqun Liu,&nbsp;Jun Niu,&nbsp;Yabing Guo,&nbsp;Ying Jia,&nbsp;Maolei Cui","doi":"10.1016/j.engeos.2025.100393","DOIUrl":"10.1016/j.engeos.2025.100393","url":null,"abstract":"<div><div>Experimental results from the Daniudi gas field enhance our understanding of mechanisms behind CO₂ injection for enhanced recovery from tight-sand gas reservoirs. The results reveal that the diffusion coefficients of CO₂ in tight reservoirs range from 10⁻⁸ m²/s to 10⁻⁹ m²/s, correlating negatively with pore pressure and positively with pore radius. In these reservoirs, CO₂ manifests a significantly higher adsorption capability compared to CH₄, suggesting a competitive adsorption advantage. Further, the amount of adsorbed gas correlates negatively with core permeability and positively with pore pressure. In the late-stage depletion-drive development of tight-sand gas reservoirs, CO₂ injection alleviates water locking and enhances gas-water flow, facilitating the recovery of trapped gas. The long-core CO₂ flooding experiment results in a 14.11 % increase in gas recovery efficiency. The effectiveness of CO₂-enhanced gas recovery (EGR) is primarily related to reservoir properties. Higher average permeability correlates with more effective CO₂-EGR. Although the rate and mode of injection have limited impacts on ultimate recovery efficiency, they influence CO₂ breakthrough time. Specifically, a higher injection rate leads to earlier breakthrough, and the breakthrough under pulsed CO₂ injection occurs later than that under continuous injection.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100393"},"PeriodicalIF":0.0,"publicationDate":"2025-03-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143706215","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":"Prediction on rock strength by mineral composition from machine learning of ECS logs","authors":"Dongwen Li ,&nbsp;Xinlong Li ,&nbsp;Li Liu ,&nbsp;Wenhao He ,&nbsp;Yongxin Li ,&nbsp;Shuowen Li ,&nbsp;Huaizhong Shi ,&nbsp;Gaojian Fan","doi":"10.1016/j.engeos.2025.100386","DOIUrl":"10.1016/j.engeos.2025.100386","url":null,"abstract":"<div><div>Rock strength evaluation is critical in oil and gas exploration, but traditional methods, such as empirical formulas, laboratory tests, and numerical simulations, often struggle with accuracy, generalizability, and alignment with field conditions. This study proposes the use of Random Forest and Transformer algorithms to predict rock strength from Elemental Capture Spectroscopy (ECS) logs. By utilizing the dry weight of minerals as input, the model predicts key mechanical properties, including Young's modulus, Poisson's ratio, bulk modulus, shear modulus, and uniaxial compressive strength. The findings demonstrate that mineral compositions, such as clay, quartz-feldspar-mica, carbonate, anhydrite, and pyrite, significantly influence rock strength. Specifically, clay content impacts Young's modulus, bulk modulus, and shear modulus, while quartz-feldspar-mica affects Poisson's ratio, and anhydrite is the primary factor influencing compressive strength. Positive correlations were observed between rock strength and the dry weight of anhydrite and carbonate minerals, while negative correlations emerged with clay, pyrite, and quartz-feldspar-mica. The Random Forest model outperformed the Transformer model in terms of predictive accuracy and computational efficiency. Its training time is only one three hundredth of the latter and its prediction time is just one tenth of the later, making it highly suitable for well-logging interpretation. Although the Transformer model was less computationally efficient, it exhibited strengths in predicting subsurface strength parameters, particularly in capturing spatial variations and forecasting these parameters across different spatial locations. This study introduces a novel AI-driven approach to rock strength evaluation, bridging the gap between mineral composition and mechanical properties, with significant implications for resource extraction and reservoir management.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100386"},"PeriodicalIF":0.0,"publicationDate":"2025-03-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143620503","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":"A model for predicting marine shale gas sweet spots based on relative sea-level changes and its application","authors":"Hongyan Wang ,&nbsp;Zhensheng Shi ,&nbsp;Xi Yang ,&nbsp;Qun Zhao ,&nbsp;Changmin Guo","doi":"10.1016/j.engeos.2025.100392","DOIUrl":"10.1016/j.engeos.2025.100392","url":null,"abstract":"<div><div>Gas-bearing shales have become a major source of future natural gas production worldwide. It has become increasingly urgent to develop a reliable prediction model and corresponding workflow for identifying shale gas sweet spots. The formation of gas-bearing shales is closely linked to relative sea-level changes, providing an important approach to predicting sweet spots in the Wufeng-Longmaxi shale in the southern Sichuan Basin, China. Three types of marine shale gas sweet spots are identified in the shale based on their formation stages combined with relative sea-level changes: early, middle, and late transgression types. This study develops a prediction model and workflow for identifying shale gas sweet spots by analyzing relative sea-level changes and facies sequences. Predicting shale gas sweet spots in an explored block using this model and workflow can provide a valuable guide for well design and hydraulic fracturing, significantly enhancing the efficiency of shale gas exploration and development. Notably, the new prediction model and workflow can be utilized for the rapid evaluation of the potential for shale gas development in new shale gas blocks or those with low exploratory maturity.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100392"},"PeriodicalIF":0.0,"publicationDate":"2025-02-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143549712","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":"Control of volcanic lithofacies on play fairways: A case study of the Huoshiling Formation in the Dehui faulted depression, southern Songliao Basin, China","authors":"Jijun Li ,&nbsp;Chenghong Luo ,&nbsp;Tianhong Yang ,&nbsp;Tongyao Zhang ,&nbsp;Peng Hao ,&nbsp;Bo Wang ,&nbsp;Yan Cheng ,&nbsp;Libin Song ,&nbsp;Kexin Jia ,&nbsp;Lili Li ,&nbsp;Chao Liu","doi":"10.1016/j.engeos.2025.100391","DOIUrl":"10.1016/j.engeos.2025.100391","url":null,"abstract":"<div><div>Volcanic reservoirs demonstrate strong heterogeneity and substantial variations in productivity due to the complexity of volcanic eruption and lithology. The main types of reservoir space are not clear, and the dominant lithofacies distribution, particularly the favorable areas for high-quality reservoirs, remains to be determined. In this paper, the Huoshiling Formation in the Dehui faulted depression, Songliao Basin is taken as an example to carry out the multi-scale joint characterization of its pore throat structure, establish a reservoir evaluation standard that considers both the gas content and seepage capacity, and perform reservoir evaluation and play fairway mapping under facies control. The results show that the storage space types of the gas-bearing reservoirs in the faulted depression can be ascribed into three categories and six subcategories according to the pore throat and pore characteristics. In terms of pore sizes, volcaniclastic lava rank the first, followed by volcaniclastic rocks, sedimentary volcaniclastic rocks and volcanic lava. The comprehensive evaluation parameter (<span><math><mi>Φ</mi><mo>∙</mo><mi>K</mi><mo>∙</mo><msub><mi>S</mi><mi>g</mi></msub></math></span>, where <span><math><mrow><mi>Φ</mi></mrow></math></span> is porosity, <em>K</em> permeability, and <em>S</em>_g gas saturation) of high-quality reservoirs are all greater than 0.1. The volcanic reservoirs in the Stage-Ⅲ strata are the highest in quality and largest in area of play fairways. The thermal debris flow sub-facies developed at Stage Ⅲ are mainly seen along the western strike-slip fault zone in the Debei sub-sag and the southwest Nong'an tectonic belt, while those developed at Stage I are distributed along the central and eastern fault zones in the southeastern Baojia sub-sag. The favorable layer evaluation and favorable area delineation under facies control will be of certain reference significance for subsequent exploration and development of volcanic gas reservoirs.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100391"},"PeriodicalIF":0.0,"publicationDate":"2025-02-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143549714","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}