Natural Gas Industry B最新文献

{"title":"Predicting total organic carbon in Wufeng–Longmaxi shales by coupling machine learning with multiple intelligent optimization algorithms: A case study from structurally complex Northern Guizhou","authors":"Zeng-Run Yang,&nbsp;Yong Fu,&nbsp;Yu-Liang Mou,&nbsp;Feng Tian,&nbsp;Qian-Min Yang","doi":"10.1016/j.ngib.2026.07.006","DOIUrl":"10.1016/j.ngib.2026.07.006","url":null,"abstract":"<div><div>Total organic carbon (TOC) plays a crucial role in unconventional oil and gas exploration. The traditional ΔlogR method faces limitations under complex geological conditions, while conventional machine-learning models is sensitive to hyperparameter settings, validation design, and model interpretability. This study integrates core and well-log data from six wells in the structurally complex Wufeng–Longmaxi shale succession of northern Guizhou to develop a unified TOC prediction framework. Four metaheuristic optimization algorithms are combined with five machine-learning models. Recursive feature elimination with cross-validation is used for variable selection, and model performance and interpretability are assessed using stratigraphically withheld interval validation and SHapley Additive exPlanations (SHAP). The findings indicate: (1) eight logging parameters are retained as model inputs, and the GWO-CatBoost model demonstrates the best predictive performance, achieving a test-set <em>R</em>² of 0.930 and an RMSE of 0.373 wt%, outperforming the traditional ΔlogR method; (2) stratigraphically withheld interval validation in well A1 results in an <em>R</em>² of 0.82, indicating stable predictive performance across various intervals of the Wufeng–Longmaxi succession; (3) the model applied to uncored intervals produces continuous TOC curves and effectively identifies organic-rich shale intervals; and (4) SHAP analysis identifies uranium content and compensated neutron log as the most influential variables governing TOC predictions. The reproducible and interpretable TOC prediction framework developed in this study offers reliable technical support for continuous quantitative TOC evaluation and identification of organic-rich intervals in the structurally complex Wufeng–Longmaxi shale succession of northern Guizhou.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 469-488"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810616","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Recent advances in multi-physics coupled simulation of matrix acidizing and acid fracturing: New insights from CT-based digital rock physics","authors":"Chao Wang,&nbsp;Nianyin Li,&nbsp;Jiajie Yu,&nbsp;Yu-ning He,&nbsp;Yu Tian,&nbsp;Peng Hu,&nbsp;Yue Li,&nbsp;Yuan Wang,&nbsp;Zhibo Gong","doi":"10.1016/j.ngib.2026.07.002","DOIUrl":"10.1016/j.ngib.2026.07.002","url":null,"abstract":"<div><div>Matrix acidizing and acid fracturing are crucial technologies for enhancing production in carbonate reservoirs. However, accurately predicting acidizing performance remains challenging due to strong reservoir heterogeneity and the complex coupling among flow, reactive transport, and acid-rock reactions. This paper comprehensively reviews recent advancements in digital rock physics (DRP) applied to carbonate acidizing. The focus is on digital core reconstruction, physical field characterization, numerical modeling approaches, and multi-physics coupled simulations. The review reveals that: (1) DRP enables high-fidelity reconstruction of pore structures and physical fields, significantly enhancing the understanding of pore-scale acid-rock interactions and wormhole development; (2) complementary numerical models have significantly advanced the simulation of reactive transport, wormhole evolution, and acid-induced fracture propagation, offering a more comprehensive framework for investigating carbonate acidizing mechanisms; and (3) despite these advances, current DRP-based simulations still face significant challenges, including reconstruction uncertainty, inadequate multi-physics coupling capability, limited multiscale integration, and high computational costs. Overall, DRP is poised to bridge pore-scale mechanistic understanding with engineering-scale acidizing applications, laying a fundamental basis for intelligent acidizing design and reservoir stimulation optimization.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 560-592"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810675","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Spatiotemporal evolution of lower-middle Triassic strata, Sichuan Basin, Southwestern China: Insights into the deformation mechanism of the Luzhou paleo-uplift and gas exploration","authors":"Zhengshuo Miao,&nbsp;Nan Su,&nbsp;Han Liang,&nbsp;Ben Feng,&nbsp;Yang Qin,&nbsp;Yangwen Pei","doi":"10.1016/j.ngib.2026.05.003","DOIUrl":"10.1016/j.ngib.2026.05.003","url":null,"abstract":"<div><div>The Sichuan Basin experienced profound structural changes during the Triassic, generating debate regarding the deformation mechanism of the Luzhou paleo-uplift and complicating future gas exploration efforts. Understanding the spatiotemporal evolution of lower-middle Triassic strata is crucial for resolving these controversies. In this study, we integrated seismic interpretation, detailed stratigraphic contact delineation, and erosion amount calculations to reconstruct the spatiotemporal evolution of the lower-middle Triassic strata. This reconstruction enables a reassessment of the uplift's deformation mechanism and its impacts on gas migration and accumulation. First, the spatiotemporal evolution of the lower-middle Triassic strata indicates that the distribution pattern of its paleo-highs and -lows was established during the late Triassic and subsequently inherited by overlying younger strata. Second, significant structural relief observed in the middle-Triassic Leikoupo Formation indicates the initial development of the Luzhou paleo-uplift during the late Triassic, reflecting a contraction-related origin driven by regional stress transfer, detachment-controlled shortening, and gypsum-related deformation in eastern Sichuan. Finally, gas resources likely migrated vertically via fault systems that acted as conduits between source rocks and reservoirs. Therefore, gas exploration targets should be identified by considering the spatial interplay of gas generation capacity, paleo-high and -low distribution, and fault systems. Particularly, preserved flanks or adjacent highs of inherited paleo-uplifts are likely more favorable than strongly denuded uplift crests.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 454-468"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810570","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Numerical analysis of hydraulic fracture initiation and propagation in elastoplastic hydrate-bearing sediments","authors":"Kaixiang Shen,&nbsp;Youkeren An,&nbsp;Jinshan Wang,&nbsp;Yiqun Zhang,&nbsp;Chengyu Hui","doi":"10.1016/j.ngib.2026.05.002","DOIUrl":"10.1016/j.ngib.2026.05.002","url":null,"abstract":"<div><div>Hydrate-bearing sediments (HBS) exhibit pronounced plastic deformation, complicating both hydraulic fracture initiation and propagation. Conventional models typically assume purely elastic behavior and neglect energy dissipation at fracture tips, leading to significant deviations in predicted fracture responses. To address these limitations, this study developed a fluid-solid coupled numerical model within the extended finite element method (XFEM), utilizing the Mohr-Coulomb yield criterion to simulate fracture initiation and propagation in elastoplastic HBS. The model was validated against true triaxial hydraulic fracturing experiments, predicting fracture initiation pressures within 5% of measured values. Results indicate that fracture initiation is strongly controlled by localized plastic strain at fracture tips. This plastic strain acts as a primary mechanism of energy dissipation, increasing initiation pressure by up to 1.92 MPa compared with purely elastic predictions. During fracture propagation, plastic yielding leads to the development of short, wide fractures with increased opening but limited length. Increasing hydrate saturation shifts fracture propagation from ductile-dominated to brittle-dominated behavior. In addition, in-situ stress and fracturing fluid properties influence fracture initiation and propagation by influencing plastic deformation. These findings clarify the controlling role of elastoplastic behavior in fracture initiation and propagation in HBS, offering guidance for hydraulic fracturing design in marine hydrate reservoirs.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 489-503"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810617","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimization of acid fracturing process in naturally fractured tight sandstone reservoirs","authors":"Jianping Zhou,&nbsp;Yaozeng Xie,&nbsp;Dingdong Mo,&nbsp;Xinqi Zeng,&nbsp;Jiang Xiao,&nbsp;Dingfeng Xia","doi":"10.1016/j.ngib.2026.06.009","DOIUrl":"10.1016/j.ngib.2026.06.009","url":null,"abstract":"<div><div>Naturally fractured tight sandstone reservoirs in the Keshen Gas Field of the Tarim Basin are featured by low porosity and low permeability. Widespread calcite filling within natural fractures limits the inherent productivity, which necessitates optimized fracture-network acid fracturing for reservoir stimulation. In this paper, a fully coupled stress-flow-reaction numerical model is established based on the extended finite element method (XFEM). The model couples calcite dissolution in mineral-filled fractures by hydrochloric acid preflush with acid-rock reactions of hydrofluoric acid-based main acid in sandstone formations, enabling quantitative simulation of the whole evolution of complex fracture network propagation, acid transport, mineral dissolution and secondary precipitation. Systematic single-factor sensitivity analyses are performed on six key parameters, including preflush viscosity, preflush volume, injection rate, natural fracture density, acid system type and main acid volume, to quantitatively compare and evaluate the stimulation performance of various acid fracturing parameters and acid systems. The results indicate that the established multi-stage acid flow-reaction coupled model supports quantitative comparison and mechanistic analysis of different acid systems within a unified computational framework. It clarifies the control mechanisms of geological and operational parameters on natural fracture activation, fracture network growth and secondary precipitation-induced formation damage, thereby providing theoretical support and technical guidance for the optimization of acid fracturing treatments in fractured tight sandstone reservoirs of the Keshen Gas Field.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 543-559"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810674","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Development geology of unconventional natural gas: Enrichment mechanisms, sweet spot evaluation, and development response","authors":"Yong Li,&nbsp;Caineng Zou,&nbsp;Yun Li,&nbsp;Rongze Yu,&nbsp;Hanlin Liu,&nbsp;Xiaokang An","doi":"10.1016/j.ngib.2026.07.004","DOIUrl":"10.1016/j.ngib.2026.07.004","url":null,"abstract":"<div><div>Unconventional natural gas has become an important contributor to the growth of global natural gas reserves and production expansion. However, pronounced heterogeneity among different reservoir types results in substantial variations in enrichment mechanisms, sweet-spot formation, and development responses, thereby hindering the establishment of a unified framework for unconventional gas development geology. This study systematically compares shale gas, tight gas, shallow coalbed methane (CBM), and deep CBM within an integrated framework that links enrichment mechanisms, sweet-spot evaluation, and development response. The results reveal distinct geological controls among these unconventional systems. The shale gas is characterized by source–reservoir integration, nanoscale storage, and favorable preservation conditions; the tight gas is controlled by near-source charging and permeability-limited flow; the shallow CBM is dominated by adsorption-controlled enrichment; and the deep CBM exhibits a coupled accumulation mode involving both free and adsorbed gas. Sweet spots are defined as reservoir intervals where favorable geological enrichment conditions can be effectively converted into engineering recoverability. Their identification requires the integrated evaluation of geological conditions, engineering parameters, and production performance rather than relying on individual indicator anomalies. Development responses reflect the evolution of enrichment characteristics during stimulation and production. Shale gas productivity is primarily governed by fracture-network conductivity and matrix gas supply, whereas tight gas development depends on reservoir connectivity and geological heterogeneity. Shallow CBM production is controlled by drainage-induced desorption and subsequent gas transport processes, whereas deep CBM production is characterized by an initial stage dominated by free-gas recovery followed by increasing adsorbed gas contributions. This study demonstrates that effective unconventional gas development requires an integrated understanding of enrichment mechanisms, sweet-spot evaluation, and production responses. Future research should focus on the quantitative characterization of enrichment processes, dynamic prediction of sweet-spot distribution, and cross-scale production modeling to improve the efficiency of unconventional gas development under complex geological conditions.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 437-453"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810569","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Erratum regarding incomplete Declaration of Competing Interest statements in previously published articles","authors":"","doi":"10.1016/j.ngib.2026.07.001","DOIUrl":"10.1016/j.ngib.2026.07.001","url":null,"abstract":"","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 606-616"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810619","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Accurate quantification of multiple sulfur compounds in natural gas: Preparation and evaluation of a thioether-functionalized covalent organic framework-based gas chromatography capillary column","authors":"Zixun Chen,&nbsp;Yang Zhang,&nbsp;Li Zhou,&nbsp;Huige Zhang,&nbsp;Pu Zhang,&nbsp;Wenjuan Lv,&nbsp;Huadong Zhu,&nbsp;Hongli Chen","doi":"10.1016/j.ngib.2026.07.003","DOIUrl":"10.1016/j.ngib.2026.07.003","url":null,"abstract":"<div><div>Accurate quantification of sulfur compounds, such as hydrogen sulfide and mercaptans, is crucial for natural gas quality control and ensuring the safe supply of energy sources, given their high reactivity and corrosiveness toward gas pipelines and equipment. In this study, a thioether-functionalized covalent organic framework (COF-LZU8) was selected for its potential specific interactions with sulfur compounds via thioether groups and straight channels, and was synthesized and uniformly immobilized onto the inner surface of a capillary column via in-situ growth. This column was employed as a stationary phase for gas chromatography (GC) to qualitatively separate and quantitatively detecte several sulfur compounds in natural gas. The key findings are as follows: (1) The column exhibited high separation efficiency and good linearity over two orders of magnitude, attributed primarily to S–S and hydrogen bonding interactions between COF-LZU8 and the sulfur compounds, as indicated by simulation results. (2) The limits of detections (LODs) for the seven sulfur compounds ranged from 0.017 mg/m³ (methyl mercaptan) to 0.746 mg/m³ (methyl sulfide). (3) At a concentration of 10.1 mg/m³, the relative standard deviations for peak area and retention time, determined from replicate injections, were 0.01%–1.43% and 0–0.14% for intra-day precision (n = 5), and 1.29%–3.37% and 0.05%–0.23% for inter-day precision (n = 5), respectively. Satisfactory accuracy was further confirmed by the small absolute errors observed for standard gases. (4) The determined concentrations of sulfur compounds obtained with the COF-LZU8-coated capillary column were consistent with those of multiple commercial columns for standard gases with small absolute errors and analysis of an actual natural gas sample also showed agreement between the COF-LZU8-coated capillary column and a commercial GC column (DB-SULFUR) within 0.5 mg/m³. This study presents a competitive GC capillary column that shows potential as an alternative to commercial stationary phases, providing a promising platform for applying covalent organic frameworks (COFs) as GC stationary phases for the simultaneous detection of multiple sulfur compounds in the natural gas industry.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 593-605"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810620","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Research advances in nonlinear flow mechanisms and productivity prediction for horizontal wells in ultra-low-permeability gas reservoirs","authors":"Ruidong Wu,&nbsp;Chunguang Zhang,&nbsp;Wenjuan Zhu,&nbsp;Qilan Luo,&nbsp;Fengjiao Wang,&nbsp;Yikun Liu,&nbsp;Guanli Yan","doi":"10.1016/j.ngib.2026.07.007","DOIUrl":"10.1016/j.ngib.2026.07.007","url":null,"abstract":"<div><div>Natural gas plays a prominent role in China's transition toward a low-carbon energy system. Ultra-low-permeability gas reservoirs hold substantial natural gas reserves, but their efficient development remains challenging, primarily because of complex nonlinear flow behavior. This paper systematically reviews three core flow mechanisms in ultra-low-permeability reservoirs—stress sensitivity, dynamic threshold pressure gradient, and time-dependent relative permeability—and examines their coupled and synergistic effects. It also compares the applicability and limitations of analytical, numerical simulation, and machine learning approaches to productivity prediction for conventional, multistage fractured, and multilateral horizontal wells. Three major gaps in existing studies are identified: inadequate cross-scale characterization of reservoir media, an incomplete understanding of pore-scale gas–water two-phase flow, and the tension between predictive accuracy and physical interpretability in numerical modeling. Future work should emphasize high-resolution microscale physical simulation, integrated cross-scale models linking microfractures and large hydraulic fractures, and physics–data hybrid methods such as physics-informed neural networks (PINNs). These developments will enable more accurate characterization of flow across scales and throughout the production life cycle and provide a robust theoretical basis for optimizing horizontal-well development in ultra-low-permeability gas reservoirs.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 525-542"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810673","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrated bio-stimulation framework for microbially enhanced coalbed methane recovery in dual-porosity reservoirs","authors":"Dmitry A. Popov,&nbsp;Edka B.L. Vasquez,&nbsp;Mohammed Al-Shargabi,&nbsp;Ivan V. Matveev,&nbsp;Gleb Y. Shishaev,&nbsp;Valeriy S. Rukavishnikov,&nbsp;Shadfar Davoodi","doi":"10.1016/j.ngib.2026.07.005","DOIUrl":"10.1016/j.ngib.2026.07.005","url":null,"abstract":"<div><div>Predicting microbially enhanced coalbed methane (MECBM) extraction accurately presents a significant challenge, largely because current models fail to adequately integrate microbial kinetics with the intricate and dynamic physical processes occurring within coal reservoirs. To bridge this critical gap, this study introduces a novel field-scale simulation framework specifically designed for evaluating MECBM performance. A key innovation of this work is the explicit integration of a biogenic methane (CH₄) proxy model—derived from the Conus model, which was originally developed to characterize CH₄ formation during organic substrate decomposition—with the commercial tNavigator simulator. This integration effectively couples microbial gas generation with the complex flow and adsorption processes within coal reservoirs. The implementation involved a concise three-stage workflow, incorporating static geological data, coal-specific Langmuir parameters, diffusion coefficients, and dual-porosity physics. This was complemented by simulating nutrient-tracer propagation using organic substrates, such as glucose from molasses and lignin, and the automated injection of microbially generated gases via dummy wells. The framework was applied to a 1.8 × 1.8 km fractured coal seam, featuring 25 hydraulically fractured wells, under three distinct scenarios: depletion, carbon dioxide (CO₂) injection, and bio-stimulation. Numerical results indicate that primary depletion yields ∼616 million m³ of CH₄ (∼60% recovery), whereas CO₂ injection increases recovery to ∼74% by effectively maintaining reservoir pressure. In stark contrast, bio-stimulation contributes a negligible amount of CH₄ (&lt;1% gain), primarily because ∼66% of the microbially generated CO₂ becomes adsorbed within the coal matrix, preventing it from reaching the production wells. Furthermore, a sensitivity analysis revealed that the CH₄ Langmuir volume is the predominant factor controlling recovery, while operational parameters like nutrient injection rate and duration have only a minimal impact. This framework successfully links laboratory-scale microbial behavior with field-scale reservoir dynamics, offering a practical tool for optimizing MECBM strategies, facilitating concurrent CH₄ production and CO₂ sequestration, and valorizing organic substrates including glucose and lignin.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"13 4","pages":"Pages 504-524"},"PeriodicalIF":5.0,"publicationDate":"2026-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148810618","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}