Natural Gas Industry B最新文献

{"title":"Numerical assessment of gas production potential via depressurization: Impact of production interval and bottom hole pressure at site NGHP-01-10D of the Krishna-Godavari Basin hydrate reservoir","authors":"Shadman Hasan Khan ,&nbsp;Monika Gandhi ,&nbsp;Beatrice Castellani ,&nbsp;Pietro Di Profio ,&nbsp;Michele Ciulla ,&nbsp;Amit Arora ,&nbsp;C.B. Majumder","doi":"10.1016/j.ngib.2025.06.003","DOIUrl":"10.1016/j.ngib.2025.06.003","url":null,"abstract":"<div><div>The National Gas Hydrate Program expeditions (NGHP-01 and -02) have conclusively proven the presence of hydrate deposits on the eastern coast of India. The novelty of the present study lies in its investigation of the richest gas hydrate deposit (hydrate saturation [Sh] &gt; 0.75), NGHP-01-10D, in the Krishna-Godavari (KG) Basin, India. The study presents a first look at the long-term gas production viability using a single vertical well, subjected to variations in production interval and bottom hole pressure. Specifically, we compared the gas production at bottom hole pressures of 3–6 MPa and production intervals of 20–40 m. The results indicate production rates that are technically feasible but lower than commercially acceptable standards. Increasing the bottom hole pressure drawdown from 6 MPa to 3 MPa increased the gas production from 1297 m³/d to 4902 m³/d (i.e., more than tripling the average daily gas production). Meanwhile, while expanding the production interval from 20 m to 40 m led to an increase in gas production, it also resulted in higher water production. As a result, the average gas-to-water ratio (R_GW) decreased from 9.5 to 5.3 with the expansion of the production interval, thereby highlighting the need to optimize the interval length. Furthermore, the spatial evolution of certain thermodynamic parameters, including pressure, temperature, and phase saturation (methane, water, and hydrate), underscores the critical role of heat transfer from the UB. Our study findings offer valuable insights for long-term production forecasting, the delineation of phase evolution patterns, and the identification of potential flow barriers that may impede deliverability.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 482-500"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922816","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Permeability evolution mechanism in deep coalbed methane extraction: Considering the competitive effects of adsorption-induced swelling, creep, and aperture compression","authors":"Yanhui Yang ,&nbsp;Tao Zhang ,&nbsp;Jianchun Guo ,&nbsp;Xiuqin Lu ,&nbsp;Zongyuan Li ,&nbsp;Jie Zeng ,&nbsp;Zhihong Zhao ,&nbsp;Yiqun Wang ,&nbsp;Dan Guo ,&nbsp;Jingwen Li","doi":"10.1016/j.ngib.2025.08.004","DOIUrl":"10.1016/j.ngib.2025.08.004","url":null,"abstract":"<div><div>During gas extraction from deep coal, the rock endures high effective stress, with both the time-dependent deformation and anisotropic structure of the rock controlling the permeability evolution. To reveal this phenomenon, a numerical simulation framework of the finite volume method and transient embedded discrete fracture model is proposed to establish a new constitutive model that links poroelastoplastic deformation, adsorption-induced swelling, and aperture compression. From this model, anisotropic permeability tensors were derived to further achieve the simulation of coevolution. Meanwhile, our permeability model was verified against the measured permeability data, and the history match of the numerical model showed better results where the mismatch was less than 5 %. The results indicate that (1) the long-term permeability evolution clearly showed the competitive effects of multiple deformation mechanisms, which involves three stages: compaction-dominated decline, adsorption-dominated rebound, and creep-controlled loss. (2) The increased number of compressible cleats/fractures accelerated the initial permeability decline, while the increased desorption-induced strain promoted faster rebound and enhancement and higher viscosity coefficients enhanced the creep effect, which led to significant long-term permeability loss. (3) Massive hydraulic fracturing created a larger drainage area, accelerating methane desorption and causing sharp permeability rebound with reduced residual gas, which shows that the permeability remained higher than the initial values even after the extensive extraction via the fractured horizontal wells. The permeability evolution mechanisms displayed varying properties, such as coal rank and burial depth, and distinct characteristics. A precise understanding of multiple competitive stress effects is crucial for optimizing coalbed methane extraction techniques and improving recovery efficiency.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 416-431"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922801","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Damage location prediction of cement-sandstone combinations under axial force: Three-dimensional structure reconstruction and stress distribution simulation based on μ-CT","authors":"Zhong Li ,&nbsp;Zhiming Yin ,&nbsp;Xingquan Zhang ,&nbsp;Tao Gu ,&nbsp;Fubin Xin ,&nbsp;Zhiqiang Huang","doi":"10.1016/j.ngib.2025.08.001","DOIUrl":"10.1016/j.ngib.2025.08.001","url":null,"abstract":"<div><div>Effective isolation between the cement sheath and the sandstone is crucial for the development and production of oil and gas wells in sandstone formations. In this study, a cement-sandstone composite (CSC) was prepared, and based on μ-CT three-dimensional reconstruction imaging and finite element analysis (FEA) techniques, the stress distribution and potential failure mechanism at the cement-sandstone bonding interface under axial loading were analyzed. The key findings are as follows: (1) stress concentrations are highly likely to form at the gap between the cement and sandstone interface and around interfacial voids, with Von Mises stress reaching critical levels of 18.0–20.0 MPa at these locations, significantly exceeding the stress magnitudes in well-bonded regions; (2) the phenomenon of local stress concentration driven by interfacial defects can be identified as the main basis for predicting damage location in interfacial debonding and continuous shear under axial load; (3) ensuring tight cementation at the cement-sandstone interface and minimizing interfacial voids are paramount for preventing stress-induced failure; (4) the critical Von Mises stress value of 20 MPa at the interface defect can be used as a benchmark for material selection and designed to ensure long-term integrity in oil and gas well applications subjected to similar axial loads. These findings contribute to a more accurate understanding of the failure mechanism of the cement-sandstone interface and to the precise design of material properties, thereby ensuring the long-term integrity of oil and gas well applications subjected to similar axial loads.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 405-415"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922800","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quantitative identification method for pores in shale inorganic components based on pixel information","authors":"Shitan Ning ,&nbsp;Xianglu Tang ,&nbsp;Liang Xu ,&nbsp;Wei Wu ,&nbsp;Xuewen Shi ,&nbsp;Zhenxue Jiang ,&nbsp;Xinyue Zhang ,&nbsp;Xinlei Wang","doi":"10.1016/j.ngib.2025.06.001","DOIUrl":"10.1016/j.ngib.2025.06.001","url":null,"abstract":"<div><div>The types and structures of inorganic pores are key factors in evaluations of the reservoir space and distribution characteristics of shale oil and gas. However, quantitative identification methods for pores of different inorganic components have not yet been fully developed. For this reason, a quantitative characterization method of inorganic pores using pixel information was proposed in this study. A machine learning algorithm was used to assist the field emission scanning electron microscopy (FE-SEM) image processing of shale to realize the accurate identification and quantitative characterization of inorganic pores on the surface of high-precision images of shale with a small view. Moreover, large-view image splicing technology, combined with quantitative evaluation of minerals by scanning electron microscopy (QEMSCAN) image joint characterization technology, was used to accurately analyze the distribution characteristics of inorganic pores under different mineral components. The quantitative methods of pore characteristics of different inorganic components under the pixel information of shale were studied. The results showed that (1) the Waikato Environment for Knowledge Analysis (WEKA) machine learning model can effectively identify and extract shale mineral components and inorganic pore distribution, and the large-view FE-SEM images are representative of samples at the 200 μm × 200 μm view scale, meeting statistical requirements and eliminating the influence of heterogeneity; (2) the pores developed by different mineral components of shale had obvious differences, indicating that the development of inorganic pores is highly correlated with the properties of shale minerals themselves; and (3) the pore-forming ability of different mineral components is calculated by the quantitative method of single component pore-forming coefficient. Chlorite showed the highest pore-forming ability, followed by (in descending order) illite, pyrite, calcite, dolomite, albite, orthoclase, quartz, and apatite. This study contributes to advancing our understanding of inorganic pore characteristics in shale.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 447-461"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922814","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A simulation study of natural gas injection and storage in a partially depleted oil reservoir for seasonal underground energy storage","authors":"Manal AlShafi,&nbsp;Abdulsalam Abd,&nbsp;Ahmad Abushaikha,&nbsp;Yusuf Bicer","doi":"10.1016/j.ngib.2025.06.004","DOIUrl":"10.1016/j.ngib.2025.06.004","url":null,"abstract":"<div><div>The supply of energy is a severe challenge for every country, particularly those that are industrially developed and highly populated. Natural gas is among the most essential energy sources due to its reasonably low cost and high heating value. One of the elements of a sustainable energy supply is underground gas storage (UGS). UGS systems consist of a cushion gas (base gas) and a working gas. The cushion gas is injected into a reservoir to sustain the pressure and remain there until the period of storage ends, while the working gas is the main gas to be stored and produced. Unlike prior studies on fully depleted fields, our research emphasizes the potential of UGS in the presence of remaining oil and integrates key concepts, such as enhanced oil recovery and CO₂ sequestration. A simulation study was conducted using Qatari Advanced Simulator for Reservoirs software to determine the feasibility of a UGS system in a partially depleted oil reservoir. N₂ and CO₂ gases were considered and analyzed over short, medium, and long injection/withdrawal cycles to investigate their potential as cushion gases for natural gas storage in a partially depleted oil reservoir. It was found that using CO₂ as a cushion gas produces 32 %, 57 %, and 90 % of CH₄ according to short-, medium-, and long-term energy storage scenarios, respectively, with the CH₄ production higher than when using N₂. This study sheds light on the feasibility of implementing underground gas storage systems in partially depleted oil reservoirs.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 501-514"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922673","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A microfluidic study on the influence of naturally fractured porous media on the phase behavior of condensate gas depletion","authors":"Kuiqian Ma ,&nbsp;Shuoshi Wang ,&nbsp;Lei Zhang ,&nbsp;Haojun Wu ,&nbsp;Jintao Wu ,&nbsp;Ping Guo ,&nbsp;Lei Huang ,&nbsp;Qixuan Zhang ,&nbsp;Limiao Wang","doi":"10.1016/j.ngib.2025.08.002","DOIUrl":"10.1016/j.ngib.2025.08.002","url":null,"abstract":"<div><div>There are limited quantitative studies on condensate gas using microfluidics under high-pressure and high-temperature conditions. This study employed microfluidics chips based on real porous media structures to conduct constant volume depletion experiments and investigate the microscopic mechanisms of condensate gas recovery. The aim of the experiments was to reveal the phase-behavior differences between bulk-phase gas and gas contained in porous media. The results revealed that condensate oil recovery in microfluidics experiments was higher than that in PVT cell tests, and nonuniform condensation and evaporation were exclusively observed in the microfluidics experiments. Furthermore, lower pore connectivity resulted in higher depletion recovery, while more developed fractures led to reduced recovery. Specifically, the chip with fewer fractures achieved the highest recovery (71.15 %), whereas the highly fractured chip exhibited the lowest recovery (56.11 %). These findings demonstrate that oil saturation during the process of constant volume depletion (CVD) of gas condensate within porous media is lower than that observed in the PVT cell, thus providing experimental evidence for optimizing condensate gas development in field applications.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 432-446"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922789","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Characterization of premixed laminar flow combustion with hydrogen doping of the associated gases","authors":"Jiang Bian ,&nbsp;Jiao Zhou ,&nbsp;Xuewen Cao ,&nbsp;Yi Wu ,&nbsp;Rui Zhang ,&nbsp;Bo Yu","doi":"10.1016/j.ngib.2025.08.003","DOIUrl":"10.1016/j.ngib.2025.08.003","url":null,"abstract":"<div><div>Hydrogen doping in associated gas combustion presents a promising strategy for mitigating carbon emissions from typically flared or vented gases. To support this idea, this study employed Chemkin Pro to model the laminar premixed combustion of associated gases and conducted a sensitivity analysis of key combustion factors. The results demonstrated that increasing the hydrogen-doping ratio accelerated flame propagation and reduced combustion product accumulation time, while also elevating flame instability and inducing cracks or folds on the flame front at higher ratios. Notably, flame speed exhibited a 40 % increase per 10 % rise in the hydrogen-doping ratio, which directly enhanced combustion efficiency. Flame temperature peaked at an equivalence ratio of 1, whereas flame speed enhancement was maximized at a ratio of 1.3. Higher premix temperatures increased flame speed, and elevated combustion pressures raised flame temperature (stabilizing above 1 atm), with flame speed peaking at 0.06 atm. Critically, hydrogen doping below 15 % minimally altered flame morphology, but 30 % doping caused significant flame retraction toward the nozzle, which increased the flashback risk and raised NOx emissions by nearly one third. These findings provide insights for optimizing hydrogen-doped combustion processes to balance efficiency gains while ensuring operational safety and emission control.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 515-526"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922674","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Reconstruction of the geothermal field of the Xihu Depression in the East China Sea Basin and its controlling effect on hydrocarbon generation and distribution","authors":"Hui Diao ,&nbsp;Qiwen Yao ,&nbsp;Wei Zou ,&nbsp;Wu Zhang ,&nbsp;Jian Chang","doi":"10.1016/j.ngib.2025.06.002","DOIUrl":"10.1016/j.ngib.2025.06.002","url":null,"abstract":"&lt;div&gt;&lt;div&gt;The Xihu Depression, situated in the northeastern East China Sea Basin, represents the most significant natural gas-producing region in Eastern China. An insufficient understanding of reservoir heterogeneity in petroleum geological conditions—particularly within structural zones beyond the well-explored Pinghu Slope and Ningbo Anticline Belt—has hindered comprehensive hydrocarbon exploration across the sag. Critical knowledge gaps persist in characterizing the geothermal field, reconstructing thermal evolution histories, and constraining hydrocarbon generation phases. These limitations directly impede systematic evaluations of basin selection criteria, reservoir delineation, and their dynamic relationships within petroleum systems. This study analyzes the present geothermal gradient at a unified depth (4000–5000 m), the geothermal heat flow, the geothermal temperature at a unified depth (3000–6000 m), and the plan distribution characteristics of the geothermal temperatures of the exploration strata in the key study area in the Xihu Depression—the Western Slope and the Central Anticlinal Belt. The research in this study is based on present bottom-hole temperature measurements and temperature data for testing for oil, using a one-dimensional steady-state heat conduction equation and the Bullard method. The results indicate that the present geothermal gradient in the Xihu Depression, between a unified depth of 4000 m and 5000 m, ranges from 16.7 °C/km to 44.6 °C/km, with an average of 30.6 °C/km. The present geothermal heat flow is between 32.23 mW/m&lt;sup&gt;2&lt;/sup&gt; and 90.13 mW/m&lt;sup&gt;2&lt;/sup&gt;, with an average of 52.03 mW/m&lt;sup&gt;2&lt;/sup&gt;, indicating a typical cold basin. The formation temperature gradually increases with burial depth, from 3000 m to 6000 m. In the plane, the formation temperature gradually increases from the south to the north and from the edge of the depression to the center of the depression. The burial history and thermal evolution of the key plays of the Xihu Depression were reconstructed using apatite fission tracks and zircon U–Th/He data, combined with vitrinite reflectance, which revealed that the tectonic uplift that occurred during the Late Miocene Longjing Movement was a critical event in trap formation and hydrocarbon filling. The thermal-hydrocarbon generation history indicates that the Xihu Depression has mostly entered a high maturity stage, with gas condensate and condensate charging occurring between 16.4 Ma and 13 Ma and natural gas filling occurring at 5.3 Ma up to now. Hydrocarbon generation and expulsion in the Xihu Depression occurred early in the north and late in the south, with two stages in the north and one stage in the south. A study of the burial history–thermal history–hydrocarbon generation history based on the reconstruction of geothermal fields demonstrates the matching relationship between hydrocarbon generation, distribution, and accumulation in the Xihu Depression—an understanding that is vital","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 4","pages":"Pages 462-481"},"PeriodicalIF":6.5,"publicationDate":"2025-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144922815","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An iteration-free approach for determining the average reservoir pressure and original gas in place by production data analysis: Methodology and field cases","authors":"Yang Wang ,&nbsp;Shilong Yang ,&nbsp;Hang Xie ,&nbsp;Naichao Feng ,&nbsp;Haiyang Yu","doi":"10.1016/j.ngib.2025.05.006","DOIUrl":"10.1016/j.ngib.2025.05.006","url":null,"abstract":"<div><div>Current gas well decline analysis under boundary-dominated flow (BDF) is largely based on the Arps' empirical hyperbolic decline model and the analytical type curve tools associated with pseudo-functions. Due to the nonlinear flow behavior of natural gas, these analysis methods generally require iterative calculations. In this study, the dimensionless gas rate (<em>q</em>_g/<em>q</em>_gi) is introduced, and an explicit method to determine the average reservoir pressure and the original gas in place (OGIP) for a volumetric gas reservoir is proposed. We show that the dimensionless gas rate in the BDF is only the function of the gas PVT parameters and reservoir pressure. Step-by-step analysis procedures are presented that enable explicit and straightforward estimation of average reservoir pressure and OGIP by straight-line analysis. Compared with current techniques, this methodology avoids the iterative calculation of pseudo-time and pseudo-pressure functions, lowers the multiplicity of type curve analysis, and is applicable in different production situations (constant/variable gas flow rate, constant/variable bottom-hole pressure) with a broad range of applications and ease of use. Reservoir numerical simulation and field examples are thoroughly discussed to highlight the capabilities of the proposed approach.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 3","pages":"Pages 328-338"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501784","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Characteristics of shale reservoir development under the influence of sedimentary differentiation: A case study of the Cambrian Qiongzhusi Formation in the Deyang-Anyue rift trough of the Sichuan Basin","authors":"Wenyi Chen ,&nbsp;Bo Wang ,&nbsp;Zhenxue Jiang ,&nbsp;Dandan Wang ,&nbsp;Hui Long ,&nbsp;Wenlei Liu ,&nbsp;Dadong Liu","doi":"10.1016/j.ngib.2025.05.001","DOIUrl":"10.1016/j.ngib.2025.05.001","url":null,"abstract":"<div><div>The Cambrian Qiongzhusi Formation in the Sichuan Basin harbors significant potential for shale gas harvesting. However, systematic disparities in mineral composition and reservoir architecture have been observed between intra- and extra-trough reservoirs within the Deyang–Anyue Rift Trough. These variations were primarily determined by divergences in the sedimentary environments developed during the evolution of the rift trough, which were a main factor in fostering the heterogeneous distribution of shale gas enrichment found today. However, the genetic mechanisms that govern reservoir heterogeneity across distinct structural domains (intra-trough, trough margin, and extra-trough) remain poorly understood, particularly regarding the coupling relationships between depositional environments, reservoir characteristics, and gas-bearing properties. This study adopts a multidisciplinary approach to investigating this issue that integrates core analysis, well-log interpretations, and geochemical data. Through systematic comparisons conducted using X-ray diffraction mineralogy, organic carbon quantification, and spontaneous imbibition experiments, we characterize the mineral assemblages, organic geochemical signatures, and pore structures found across the three structural domains of the Deyang–Anyue Rift Trough. The key findings are as follows: (1) The depositional environment is the main influence on reservoir distribution and organic matter enrichment, with intra-trough shales exhibiting a higher abundance of organic matter than their trough-margin and extra-trough counterparts. (2) Enhanced brittleness in intra-trough zones correlates with the predominance of biogenic silica therein. (3) Synergistic organic-inorganic interactions govern pore system development. (4) Gas-bearing capacity is jointly determined by effective porosity and organic matter content. These findings establish the rift trough as a preferential exploration target, providing critical geological guidance for optimizing shale gas exploration strategies in the Cambrian Qiongzhusi Formation.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"12 3","pages":"Pages 251-263"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144502416","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}