Petroleum Science最新文献

{"title":"Numerical analysis of dispersion, attenuation, and seismic effects in a porous rock saturated with three-phase immiscible fluids","authors":"Xin Luo ,&nbsp;Xue-Hua Chen ,&nbsp;Tong Li ,&nbsp;Gui-Rong Luo ,&nbsp;Peng Wang","doi":"10.1016/j.petsci.2025.04.024","DOIUrl":"10.1016/j.petsci.2025.04.024","url":null,"abstract":"<div><div>Multiphase flow in porous rock is of great importance in the application of many industrial processes, including reservoir delineation, enhanced oil recovery, and CO₂ sequestration. However, previous research typically investigated the dispersive behaviors when rock saturated with single or two-phase fluids and conducted limited studies on three-phase immiscible fluids. This study investigated the seismic dispersion, attenuation, and reflection features of seismic waves in three-phase immiscible fluid-saturated porous rocks. First, we proposed the calculation formulas of effective fluid modulus and effective fluid viscosity of multiphase immiscible fluids by taking into account the capillary pressure, reservoir wettability, and relative permeability simultaneously. Then, we analysed the frequency-dependent behaviors of three-phase immiscible fluid-saturated porous rock under different fluid proportion cases using the Chapman multi-scale model. Next, the seismic responses are analysed using a four-layer model. The results indicate that the relative permeability, capillary pressure parameter, and fluid proportions are all significantly affect dispersion and attenuation. Comparative analyses demonstrate that dispersion and attenuation can be observed within the frequency range of seismic exploration for a lower capillary parameter <em>α</em>₃ and higher oil content. Seismic responses reveal that the reflection features, such as travel time, seismic amplitude, and waveform of the bottom reflections of saturated rock and their underlying reflections are significantly dependent on fluid proportions and capillary parameters. For validation, the numerical results are further verified using the log data and real seismic data. This numerical analysis helps to further understand the wave propagation characteristics for a porous rock saturated with multiphase immiscible fluids.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 2828-2850"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144757536","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Enhancing shale oil recovery with water-alternating-CO2 injection through radial borehole fracturing","authors":"Jia-Cheng Dai ,&nbsp;Tian-Yu Wang ,&nbsp;Ye Zhang ,&nbsp;Zhi-Ping Zhang ,&nbsp;Chun-Lin Zeng ,&nbsp;Kang-Jian Tian ,&nbsp;Jing-Bin Li ,&nbsp;Shou-Ceng Tian ,&nbsp;Gen-Sheng Li","doi":"10.1016/j.petsci.2025.04.021","DOIUrl":"10.1016/j.petsci.2025.04.021","url":null,"abstract":"<div><div>This paper introduces a novel approach combining radial borehole fracturing with Water-Alternating-Gas (WAG) injection, enabling simultaneous WAG injection and shale oil production in a single vertical well. A numerical reservoir model incorporating the modified exponential non-Darcy law, stress sensitivity, and diffusion is established. The spatial distribution of permeability reduction shows that stress sensitivity enhances the non-Darcy effect, with apparent permeability decreasing to 0–92.1% of the initial value, highlighting the importance of maintaining reservoir pressure. Continuous CO₂ flooding leads to early gas breakthrough, while continuous water flooding has less displacement efficiency. A 30% water-to-gas injection time ratio improves oil production and delays gas breakthrough compared to continuous CO₂ injection. Optimal conditions for effective recovery are identified as an initial production period of 100 d and a well vertical spacing of 30 m. This study compares the production capacity of WAG operations under radial borehole fracturing and horizontal well fracturing. When the number of wells is two for both cases, the production capacity of radial borehole fracturing is comparable to that of five-stage horizontal well fracturing, indicating that radial borehole fracturing can serve as an alternative or supplement to horizontal well fracturing when the reservoir volume is limited. This study offers a new method and theoretical basis for the efficient development of shale oil.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 2950-2966"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144757538","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"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 multi-scale and multi-mechanism coupled model for carbon isotope fractionation of methane during shale gas production","authors":"Jun Wang ,&nbsp;Fang-Wen Chen ,&nbsp;Wen-Biao Li ,&nbsp;Shuang-Fang Lu ,&nbsp;Sheng-Xian Zhao ,&nbsp;Yong-Yang Liu ,&nbsp;Zi-Yi Wang","doi":"10.1016/j.petsci.2025.03.034","DOIUrl":"10.1016/j.petsci.2025.03.034","url":null,"abstract":"<div><div>Prediction of production decline and evaluation of the adsorbed/free gas ratio are critical for determining the lifespan and production status of shale gas wells. Traditional production prediction methods have some shortcomings because of the low permeability and tightness of shale, complex gas flow behavior of multi-scale gas transport regions and multiple gas transport mechanism superpositions, and complex and variable production regimes of shale gas wells. Recent research has demonstrated the existence of a multi-stage isotope fractionation phenomenon during shale gas production, with the fractionation characteristics of each stage associated with the pore structure, gas in place (GIP), adsorption/desorption, and gas production process. This study presents a new approach for estimating shale gas well production and evaluating the adsorbed/free gas ratio throughout production using isotope fractionation techniques. A reservoir-scale carbon isotope fractionation (CIF) model applicable to the production process of shale gas wells was developed for the first time in this research. In contrast to the traditional model, this model improves production prediction accuracy by simultaneously fitting the gas production rate and <em>δ</em>¹³C₁ data and provides a new evaluation method of the adsorbed/free gas ratio during shale gas production. The results indicate that the diffusion and adsorption/desorption properties of rock, bottom-hole flowing pressure (BHP) of gas well, and multi-scale gas transport regions of the reservoir all affect isotope fractionation, with the diffusion and adsorption/desorption parameters of rock having the greatest effect on isotope fractionation being <em>D</em>∗/<em>D</em>, <em>P</em>_L, <em>V</em>_L, <em>α</em>, and others in that order. We effectively tested the universality of the four-stage isotope fractionation feature and revealed a unique isotope fractionation mechanism caused by the superimposed coupling of multi-scale gas transport regions during shale gas well production. Finally, we applied the established CIF model to a shale gas well in the Sichuan Basin, China, and calculated the estimated ultimate recovery (EUR) of the well to be 3.33 × 10⁸ m³; the adsorbed gas ratio during shale gas production was 1.65%, 10.03%, and 23.44% in the first, fifth, and tenth years, respectively. The findings are significant for understanding the isotope fractionation mechanism during natural gas transport in complex systems and for formulating and optimizing unconventional natural gas development strategies.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 2719-2746"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144757590","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Hybrid deep learning framework with spatiotemporal pattern extraction for decant oil solid content soft sensor development in fluid catalytic cracking units","authors":"Nan Liu,&nbsp;Chun-Meng Zhu,&nbsp;Yu-Hui Li,&nbsp;Yun-Peng Zhao,&nbsp;Xiao-Gang Shi,&nbsp;Xing-Ying Lan","doi":"10.1016/j.petsci.2025.04.006","DOIUrl":"10.1016/j.petsci.2025.04.006","url":null,"abstract":"<div><div>Coking at the fractionating tower bottom and the decant oil circulation system disrupts the heat balance, leading to unplanned shutdown and destroying the long period stable operation of the Fluid Catalytic Cracking Unit (FCCU). The FCCU operates through interconnected subsystems, generating high-dimensional, nonlinear, and non-stationary data characterized by spatiotemporally correlated. The decant oil solid content is the crucial indicator for monitoring catalyst loss from the reactor-regenerator system and coking risk tendency at the fractionating tower bottom that relies on sampling and laboratory testing, which is lagging responsiveness and labor-intensive. Developing the online decant oil solid content soft sensor using industrial data to support operators in conducting predictive maintenance is essential. Therefore, this paper proposes a hybrid deep learning framework for soft sensor development that combines spatiotemporal pattern extraction with interpretability, enabling accurate risk identification in dynamic operational conditions. This framework employs a Filter-Wrapper method for dimensionality reduction, followed by a 2D Convolutional Neural Network (2DCNN) for extracting spatial patterns, and a Bidirectional Gated Recurrent Unit (BiGRU) for capturing long-term temporal dependencies, with an Attention Mechanism (AM) to highlight critical features adaptively. The integration of SHapley Additive exPlanations (SHAP), Complementary Ensemble Empirical Mode Decomposition with Adaptive Noise (CEEMDAN), 2DCNN, and expert knowledge precisely quantifies feature contributions and decomposes signals, significantly enhancing the practicality of risk identification. Applied to a China refinery with processing capacity of 2.80 × 10⁶ t/a, the soft sensor achieved the <em>R</em>² value of 0.93 and five-level risk identification accuracy of 96.42%. These results demonstrate the framework's accuracy, robustness, and suitability for complex industrial scenarios, advancing risk visualization and management.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 3042-3055"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144758088","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pressure characterization study in the jet influence zone of riser based on HHT analysis","authors":"Zhi-Hang Zheng ,&nbsp;Jun-Nan Ma ,&nbsp;Zi-Han Yan ,&nbsp;Chun-Xi Lu","doi":"10.1016/j.petsci.2025.04.015","DOIUrl":"10.1016/j.petsci.2025.04.015","url":null,"abstract":"<div><div>By large-scale cold mold experiments, pressure pulsation signals within the jet influence zone of riser reactor are processed by using Hilbert-Huang analysis (HHT) in this study. Effects of different jet forms and operating conditions on the intrinsic mode function (IMF) energy and Hilbert-Huang spectrum are compared. Results show that the IMF energy and Hilbert-Huang spectrum of pressure pulsation signals show significant differences under the influence of upward and downward jets. Moreover, the change of jet velocity will also lead to significant changes in IMF energy and Hilbert-Huang spectrum. Among them, energy values and energy proportions corresponding to high-frequency pressure pulsations show a good correlation with the jet velocity. On this basis, energy value and energy proportion data in the high frequency range of the original pressure signal are clustered and analyzed by using the K-means clustering algorithm. Based on clustering results, the jet influence zone of riser can be defined into three regions. From partitioning results, it is found that the introduction of downward inclined jets could effectively improve the gas-solid mixing in the feed injection zone of riser.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 3056-3067"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144758090","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Natural fractures controlled by strike-slip faults in ultradeep carbonate reservoirs: A case study of the Middle and Lower Ordovician in the Tarim Basin, China","authors":"Dong-Sheng Cao ,&nbsp;Jun Han ,&nbsp;Lian-Bo Zeng ,&nbsp;Cheng Huang ,&nbsp;Paul Dirk Bons ,&nbsp;Guo-Ping Liu ,&nbsp;Ying-Tao Yao ,&nbsp;Zhe Mao ,&nbsp;Wen-Ya Lyu ,&nbsp;Isaac Naaman ,&nbsp;Ling-Ping Zeng","doi":"10.1016/j.petsci.2025.05.012","DOIUrl":"10.1016/j.petsci.2025.05.012","url":null,"abstract":"<div><div>Natural fractures controlled by faults in ultradeep carbonate strata play substantial roles as both fluid migration channels and storage spaces. However, characterizing the heterogeneous distribution of underground fractures within the complex three-dimensional geometry of strike-slip fault zones remains challenging. This study investigates the characteristics of natural fractures controlled by strike-slip faults in the fractured Middle and Lower Ordovician reservoirs of the central and northern Tarim Basin, China. Seismics, cores, and image logs were integrated to quantitatively analyze the intensity and dip angle of natural fractures and findings were verified using published sandbox simulations. The carbonate reservoir contains three main types of natural fractures: tectonic fractures, abnormal high-pressure-related fractures, and stylolites. Strike-slip faults control the distribution and characteristics of tectonic fractures across various scales. Generally, both fracture intensity and porosity exhibit a decreasing trend as the distance from the main fault surface increases. Compared with those in non-stepover zones along a strike-slip fault, natural fractures and faults in stepover zones are more developed along the fault strike, with significantly greater development intensity in central stepover regions than that at its two ends. Furthermore, strike-slip faults influence the dip angles of both natural fractures and secondary faults. The proportion of medium-to-low-dip angle fractures and faults in the stepover zone is greater than that in the non-stepover zone. Additionally, the proportion of medium-to low-dip angle fractures and faults in the middle of the stepover is greater than that at both ends. Therefore, strike-slip fault structures control the dip angle of natural fracture and the heterogeneity of secondary fault and fracture intensity. The linking damage zone in the stepover contains a larger volume of fractured rocks, making it a promising petroleum exploration target. The development of stepovers and the orientation of present-day in-situ stress substantially influence the productivity of fractured reservoirs controlled by strike-slip faults. The analysis in this study reveals that reservoir productivity increases as the angle between the strike-slip fault segment and the maximum horizontal principal stress decreases. This study provides valuable insights for quantitatively evaluating fracture heterogeneity in fractured reservoirs and establishing optimized selection criteria for favorable targets in fault-related fractured reservoirs.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 2760-2776"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144757529","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"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 comprehensive fracture characterization method for shale reservoirs","authors":"Chen Zhang ,&nbsp;Zong-Quan Hu ,&nbsp;Xiang-Ye Kong ,&nbsp;Bo Gao ,&nbsp;Jia-Yi Liu ,&nbsp;Yu-Han Huang ,&nbsp;Hua-Dong Chen","doi":"10.1016/j.petsci.2025.03.022","DOIUrl":"10.1016/j.petsci.2025.03.022","url":null,"abstract":"<div><div>Opening-mode fractures play a crucial role in shale reservoirs, as they serve as flow channels and provide storage space for hydrocarbons. The shale reservoirs in the Permian Lucaogou Formation of the Junggar Basin, NW China, record multi-stage tectonic and diagenetic processes that created multi-stage natural fractures, thereby contributing to the oil content differentiation within the formation. Effective identification and characterization of natural fractures is vital for the efficient recovery of shale oil in the Jimsar Sag. We combine outcrop observations, drill core analyses, thin section examinations, and well log analyses to determine the characteristics of fractures in the shale reservoirs and their modes of development. We also establish multi-parameter evaluation index criteria and an evaluation system for fractures using statistical analyses. The shale reservoirs of the Lucaogou Formation in the Jimsar Sag host three main types of fracture: tectonic fractures, diagenetic fractures, and overpressure fractures. Conventional well logging, imaging logging, and core observations demonstrate that the fractured shale reservoir section has gamma-ray counts (GR) of &gt;75 API, shallow laterolog resistivities of &lt;80 Ω·m, neutron densities of &lt;2.40 g/cm³, neutron porosities of &gt;27%, and interval transit times of &gt;23.77 μs/m, fracture density exceeding 3 fractures/m, and average porosity ranging from 0.2% to 0.3% in the lower sweet spots. The lower sweet spot (P₂l₁²) of the Lucaogou Formation exhibits the highest degree of fracture development. Our detailed characterization reveals high fracture permeabilities and porosities in the upper and lower sweet spots (P₂l₂² and P₂l₁²), with higher values in the latter. In addition, we present a novel rose diagram method to represent various fracture parameters. The best-developed tectonic fractures in the Lucaogou Formation strike ENE–WSW, have an average linear density of 1.65 fractures/m, an average aperture of 0.25 mm, an average length of 8.7 cm, and the highest proportion of unfilled fractures. Our study shows that a combination of field observations, drill core analyses, microscopic observations, and well logging provides a solid foundation for investigating the mechanisms of fracture formation in shale reservoirs.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 2660-2676"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144757587","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Multichannel seismic resolution enhancement via spectral fitting for thin reservoir characterization","authors":"Si-Yuan Wang ,&nbsp;Hui Chen ,&nbsp;Ying Hu ,&nbsp;Xu-Ping Chen","doi":"10.1016/j.petsci.2025.04.008","DOIUrl":"10.1016/j.petsci.2025.04.008","url":null,"abstract":"<div><div>As seismic signals propagate underground, the subsurface media absorb high–frequency components, decreasing seismic resolution and limiting the identification and characterization of thin reservoirs. To address the limitation, this paper proposes a multichannel spectral fitting (MSF) method. The MSF method aims to enhance seismic resolution by considering the spectral characteristics and the correlations between adjacent seismic traces. The key to the MSF method involves utilizing the amplitude spectrum of the attenuated Ricker wavelet to construct an objective function for spectral fitting, leading to improved seismic resolution. Furthermore, the MSF method establishes the correlation between adjacent seismic traces as a constraint to stably solve the target parameters based on the entire seismic spectrum, which helps obtain horizontally consistent and more realistic seismic signals. Synthetic and field seismic examples demonstrate that the proposed method not only provides higher-resolution seismic signals but also reveals more fine details of thin reservoirs compared to the time-variant spectral whitening method. It is concluded that the MSF method is a promising tool for seismic signal processing.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 2818-2827"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144758093","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Research on the semi-empirical model for predicting the geometrical deformation of the sealing discs of pipeline inspection gauge","authors":"Xiao-Xiao Zhu ,&nbsp;Hao-Kun Wang ,&nbsp;Yi-Chen Zhang ,&nbsp;Chun-Ming Fu ,&nbsp;Li-Yun Lao","doi":"10.1016/j.petsci.2025.05.013","DOIUrl":"10.1016/j.petsci.2025.05.013","url":null,"abstract":"<div><div>Pipeline Inspection Gauge (pig) is an important equipment for oil and gas pipelines during different stages of their operations to perform functions such as dewatering, cleaning, and inspection. Owing to the hyperelasticity, time and temperature-dependent material behaviour of the sealing disc attached on the pig, the contact between the pig and the pipeline expresses complex behaviour, leading to an uncertainty in the prediction of the pig's frictional force. Knowing the deformation of the sealing discs well is essential and can be highly meaningful for predicting the pig motion, as well as reducing the pigging risks. In this study, the geometrical deformation of the sealing discs with different sizes are investigated through experiments and numerical simulations. The effects of the four nondimensionalized parameters (interference, thickness per pipeline inner diameter, and clamping ratio) of the sealing discs on the deformation behaviour were observed and discussed, and an improved mathematical model for predicting the geometrical deformation of the sealing discs was proposed and verified. With the auxiliary angle <em>α</em> added in the improved mathematical model, the relative error declines to 1.87% and 3.18% respectively for predicting deformation of the sealing discs in size of 2-inch and 40-inch pig. The results of this study can help better understand the frictional force of a pig with sealing discs, as well as its motion.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 3005-3014"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144758083","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Multidimensional data-driven porous media reconstruction: Inversion from 1D/2D pore parameters to 3D real pores","authors":"Peng Chi ,&nbsp;Jian-Meng Sun ,&nbsp;Ran Zhang ,&nbsp;Wei-Chao Yan ,&nbsp;Huai-Min Dong ,&nbsp;Li-Kai Cui ,&nbsp;Rui-Kang Cui ,&nbsp;Xin Luo","doi":"10.1016/j.petsci.2025.03.046","DOIUrl":"10.1016/j.petsci.2025.03.046","url":null,"abstract":"<div><div>Subsurface rocks, as complex porous media, exhibit multiscale pore structures and intricate physical properties. Digital rock physics technology has become increasingly influential in the study of subsurface rock properties. Given the multiscale characteristics of rock pore structures, direct three-dimensional imaging at sub-micrometer and nanometer scales is typically infeasible. This study introduces a method for reconstructing porous media using multidimensional data, which combines one-dimensional pore structure parameters with two-dimensional images to reconstruct three-dimensional models. The pore network model (PNM) is stochastically reconstructed using one-dimensional parameters, and a generative adversarial network (GAN) is utilized to equip the PNM with pore morphologies derived from two-dimensional images. The digital rocks generated by this method possess excellent controllability. Using Berea sandstone and Grosmont carbonate samples, we performed digital rock reconstructions based on PNM extracted by the maximum ball algorithm and compared them with stochastically reconstructed PNM. Pore structure parameters, permeability, and formation factors were calculated. The results show that the generated samples exhibit good consistency with real samples in terms of pore morphology, pore structure, and physical properties. Furthermore, our method effectively supplements the micropores not captured in CT images, demonstrating its potential in multiscale carbonate samples. Thus, the proposed reconstruction method is promising for advancing porous media property research.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"22 7","pages":"Pages 2777-2793"},"PeriodicalIF":6.1,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144758089","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}