Petroleum Research最新文献

{"title":"Fracture facies estimation utilizing machine learning algorithm and Formation Micro-Imager (FMI) log","authors":"Hassan Bagheri ,&nbsp;Reza Mohebian","doi":"10.1016/j.ptlrs.2025.04.006","DOIUrl":"10.1016/j.ptlrs.2025.04.006","url":null,"abstract":"<div><div>Natural open fractures (NOFs) in reservoir rocks are critical factors influencing permeability. Identifying these fractures and fractured zones typically involves analyzing core samples and image logs. However, core data are limited topecific depths within the reservoir, and image log data are confined to a small number of wells. In this study, fracture facies in a carbonate reservoir (Kangan-Dalan Formation) were predicted using Formation Micro-Imager (FMI) logs, conventional well logs, and petrophysical parameters, with a machine learning algorithm. Initially, open fractures were identified in wells A and B using the FMI log. In well A, the open fractures exhibit an average dip of 61°, an azimuth of N79E, and a strike direction of N11W/S11E. In well B, the fractures have an average dip of 69°, an azimuth of N26E, and a strike direction of N64W/S64E. Subsequently, fracture density logs for wells A and B were calculated, with average values of 0.41 and 0.33, respectively. Conventional well logs, including density (RHOB), sonic (DT), and petrophysical parameters, specifically effective porosity (PHIE), were used as input data for a Multi-Resolution Graph-Based Clustering (MRGC) algorithm, which is one of the machine learning algorithms employed in this study. Additionally, a synthetic log called FLAG, derived from the fracture density log (with values of 0 and 1 indicating the presence or absence of fractures), was incorporated into the algorithm as an associated input log. This algorithm enabled the identification of fracture facies, representing open fractures or fractured zones, in well A. To evaluate the accuracy of the algorithm, the results obtained were compared with two other clustering algorithms: Ascendant Hierarchical Clustering (AHC) and Self-Organizing Maps (SOM). Well B was used as a blind test to validate the clustering model. In this test, the clustering algorithm was applied excluding the FLAG synthetic log derived from the FMI log. The results from well B demonstrated that the developed algorithm accurately identifies fracture facies in wells lacking image log and core data. The algorithm was subsequently extended to wells C and D, which lacked core or image log data. Fractured zones in these wells were successfully identified as fracture facies. Additionally, a two-dimensional map of fracture facies thickness was generated for the study area. The developed hybrid algorithm demonstrated strong potential for generalizing to other wells in the field, enabling fracture facies modeling in both 2D and 3D.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 764-781"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760649","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The application of radio-frequency identification (RFID) technology in the petroleum engineering industry: Mixed review","authors":"Ali Akbari","doi":"10.1016/j.ptlrs.2025.05.001","DOIUrl":"10.1016/j.ptlrs.2025.05.001","url":null,"abstract":"<div><div>Radio Frequency Identification (RFID) technology has emerged as a promising solution for real-time tracking and monitoring in the petroleum industry. This study systematically reviews recent advancements in RFID applications for petroleum asset management, logistics, and safety. The research is based on an extensive review of peer-reviewed literature, industry reports, and experimental case studies involving RFID deployment in refinery operations and pipeline monitoring. The study also examines practical implementation challenges, including signal interference due to metal surfaces, high initial costs associated with infrastructure setup, and integration complexities with existing digital systems such as SCADA and IoT platforms. Furthermore, issues related to data security and the potential for unauthorized access are discussed as critical concerns that need to be addressed for large-scale adoption. Despite these limitations, RFID technology demonstrates significant potential in optimizing supply chain management, enhancing real-time asset tracking, and improving workplace safety in petroleum engineering. The ability to automate inventory management, reduce operational downtime, and enhance predictive maintenance further underscores its strategic importance. Future research should focus on overcoming technical barriers through the development of advanced RFID tags with higher resistance to extreme environmental conditions and improved data encryption techniques. Additionally, cost-effective deployment strategies and interoperability standards must be established to facilitate broader industry adoption. Collaborative efforts between researchers, technology developers, and industry stakeholders will be essential in driving innovation and ensuring the successful integration of RFID into the petroleum sector.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 912-922"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760697","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Dolomitization history and fracture development of Lower Cambrian Longwangmiao Formation in the NE Sichuan Basin, SW China","authors":"Shuyuan Shi ,&nbsp;Yongjie Hu ,&nbsp;Jinxiong Luo ,&nbsp;Zhuangzhuang Bai ,&nbsp;Wenliang Shang","doi":"10.1016/j.ptlrs.2025.09.010","DOIUrl":"10.1016/j.ptlrs.2025.09.010","url":null,"abstract":"<div><div>The deeply buried dolostone reservoir hosts economically significant hydrocarbon reserves. The Cambrian Longwangmiao Formation at the Nanjiang outcrop in northern Sichuan Basin is investigated using an integrated approach combing petrographic, paleo-thermometric, and geochemical analyses to yield a better understanding of dolomitization history and reservoir evolution. Petrographic observations identify five distinct types of host dolostone and three types of dolomite cement. Well-preserved sedimentary textures, fluid inclusions data and seawater-like δ¹³C-δ¹⁸O values suggest that most host dolostone (excluding zebra dolostone), along with fine-crystalline dolomite cement, were formed through reflux dolomitization in near-surface to shallow-burial settings. Subsequently, burial dolomitization likely led to the precipitation of medium-to coarse-crystalline dolomite cement during the Triassic. Saddle dolomite, representing the final phase of dolomite formation, is characterized by high homogenization temperatures (150–230 °C), significantly depleted δ¹⁸O values (−9.9 ± 0.3‰), and elevated radiogenic ⁸⁷Sr/⁸⁶Sr ratios (0.7133). The upward-decreasing trend in ⁸⁷Sr/⁸⁶Sr ratios in saddle dolomite is likely attributable to a diminishing volume of hydrothermal fluids during upward migration. Three types of fractures are recognized. The first type of fracture is cross-cut by stylolite and is likely formed during near-surface environments. The second and third types of fracture cross-cut stylolite and are partially filled by medium-to coarse-crystalline dolomite cement as well as saddle dolomite. The second and third types are likely formed under shallow to intermediate burial conditions. Both outcrop and core data reveal well-developed fractures, which significantly enhance reservoir quality by improving permeability and connectivity. This study offers important insights into the genesis and reservoir characteristics of deeply buried dolostone systems.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 725-737"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760646","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Mechanistic study on the effect of seepage force on fracture propagation behavior in multi-cluster fracturing of horizontal wells","authors":"Haiyang Wang ,&nbsp;Yufei Wang ,&nbsp;Xu Su ,&nbsp;Chen Lu ,&nbsp;Desheng Zhou ,&nbsp;Qingqing Wang","doi":"10.1016/j.ptlrs.2025.05.002","DOIUrl":"10.1016/j.ptlrs.2025.05.002","url":null,"abstract":"<div><div>During multi-cluster fracturing of horizontal wells, low-viscosity fracturing fluid permeates extensively along the fracture walls into the rock pores, exerting seepage forces on the rock skeleton. However, the mechanism of how seepage forces influence multi-cluster fracture propagation behavior remains unclear. In this study, we analyze the response relationship between the pore pressure field and the seepage field under transient seepage conditions. We established a numerical simulation model of multi-cluster fracture propagation in horizontal wells considering seepage forces based on the discrete element particle flow method. Using this model, we examined the mechanisms by which seepage forces affect the dynamic evolution of the induced stress field and fracture propagation behavior under various combinations of fracturing fluid viscosity, injection rate, in-situ stress, and cluster spacing. Numerical simulation results indicate that the infiltration of fracturing fluid into rock pores and the resulting seepage forces significantly alter the propagation patterns of inter-cluster fractures and the distribution of the induced stress field. Under the influence of seepage forces, hydraulic fractures suppressed by stress shadows are redirected and captured by adjacent fractures. Selecting appropriate fracturing fluid viscosity and injection rate can effectively utilize seepage forces to mitigate the inhibitory effects of the high compressive stress zones within stress shadows on intermediate fracture propagation, thereby increasing the likelihood of inter-fracture communication and the formation of a complex fracture network. This study not only underscores the importance of considering seepage forces in the design of multi-stage fracturing treatments but also provides critical theoretical insights for optimizing fracturing operation parameters.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 803-817"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760652","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Smart additives for fluid loss control in water-based drilling fluid: A review of recent developments","authors":"Husam Al-Ziyadi,&nbsp;Amit Verma","doi":"10.1016/j.ptlrs.2025.06.005","DOIUrl":"10.1016/j.ptlrs.2025.06.005","url":null,"abstract":"<div><div>Drilling fluids play a vital role in the success of oil and gas operations, ensuring cooling, lubrication, cuttings transport, and wellbore stability. Driven by environmental regulations, water-based muds (WBMs) have emerged as a sustainable alternative to oil-based systems; however, achieving effective fluid loss control in WBMs remains a significant technical challenge. This review critically examines the recent evolution of additive strategies, including polymeric materials, nanoparticles, and waste-derived resources targeted at improving the WBM performance. Polymeric additives enhance fluid retention and filter cake structure through gelation mechanisms, nanoparticles offer superior pore-throat plugging and mechanical reinforcement, and waste materials provide eco-efficient solutions without compromising operational efficacy. Furthermore, synergistic integrations of these additives have demonstrated compounded benefits in rheological enhancement and filtration reduction. This review provides a comprehensive analysis of mechanisms, performance trends, and practical implementation considerations, offering clear pathways to advance water-based mud design in response to the industry's dual demands for technical efficiency and environmental sustainability.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 882-893"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760694","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The role of thermophysical analysis in laboratory petrophysical core studies: An example from Saurashtra Basin rocks, India","authors":"E. Chekhonin ,&nbsp;M. Kalinina ,&nbsp;Y. Popov ,&nbsp;M. Spasennykh ,&nbsp;I. Bayuk ,&nbsp;R. Romushkevich ,&nbsp;V. Solomatin ,&nbsp;A. Mukhametdinova ,&nbsp;A. Morkovkin ,&nbsp;R.R. Yadav ,&nbsp;R. Kumar ,&nbsp;S. Lakhera ,&nbsp;M. Lal","doi":"10.1016/j.ptlrs.2025.05.008","DOIUrl":"10.1016/j.ptlrs.2025.05.008","url":null,"abstract":"<div><div>Evaluating the physical properties of rocks and their spatial variations is essential for understanding reservoir characteristics and developing reliable hydrodynamic or basin models. This paper summarizes the findings of a comprehensive laboratory study on the thermophysical, elastic, and electric properties of 62 core samples from the Saurashtra Basin (India). The results of experiments, conducted under atmospheric conditions with various pore-filling fluids, enrich the petrophysical database within the area. The advanced thermophysical core analysis extends past its conventional uses of providing reliable input data for numerical heat transfer modeling and it can aid also in characterizing heterogeneous and anisotropic rocks. High-quality data on thermal conductivity and porosity enable the differentiation of sandstone into distinct groups, which is challenging with other standard approaches. Findings from microscopic analysis, NMR measurements, and rock physics modeling support this differentiation. Significant correlations were established among thermal conductivity, electrical conductivity, elastic wave velocities, density, and porosity within each group. This study demonstrates for the first time that the principal axes of thermal conductivity are connected with the polarization directions of slow and fast shear wave velocities in sandstones. Additionally, the paper discusses thermophysical monitoring as an efficient, non-contact method for identifying and controlling changes in core sample microstructure during laboratory studies, complemented by rock physics modeling. Thus, the demonstrated applications of thermophysical core analysis go beyond its common use and provide new insights to enhance understanding of a reservoir.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 936-953"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760699","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of biosynthesized nanoparticles in chemical enhanced oil recovery: Main mechanisms, recent advances, challenges, and opportunities","authors":"Godfrey Osemudiamhen Eseigbe ,&nbsp;Sunday Sunday Ikiensikimama","doi":"10.1016/j.ptlrs.2025.04.005","DOIUrl":"10.1016/j.ptlrs.2025.04.005","url":null,"abstract":"<div><div>Nanoparticles are increasingly used in chemical enhanced oil recovery (CEOR) due to their ability to improve oil recovery by altering reservoir rock and fluid properties. These nanoparticles, which have unique physical and chemical traits, can be synthesized chemically or biologically. Biological synthesis, involving fungi, bacteria, algae, yeast, or plant materials are more stable, efficient, cost-effective, and environmentally friendly. With rising global energy demand and a shift towards greener solutions, the focus has moved from hazardous chemical synthesis to green synthesis for CEOR. Although some research exists on green nanoparticles for oil recovery, a comprehensive review of these studies and the mechanisms (such as wettability alteration, interfacial tension reduction, and stability enhancement) is needed. This paper reviews recent advances in the biosynthesis of nanoparticles and nanocomposites for oil recovery, highlighting successful examples like SiO₂/Montmorillonite/Xanthan and Fe₃O₄/SiO₂/Xanthan, which improved recovery by altering wettability, reducing interfacial tension, and enhancing dispersion and thermal stability. The study also notes the preference for plant-based green synthesis over microbial synthesis due to complexity and cost. The findings provide insights into the impact of novel greenly synthesized nanoparticles in CEOR.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 818-836"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760692","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"New approach for decline curve analysis of unconventional fractured reservoirs: Rate-normalized flow rate derivative concept","authors":"Salam Al-Rbeawi ,&nbsp;Jalal Owayed","doi":"10.1016/j.ptlrs.2025.02.003","DOIUrl":"10.1016/j.ptlrs.2025.02.003","url":null,"abstract":"<div><div>This manuscript introduces a new decline curve analysis (DCA) technique to analyze and predict the potentials of hydraulically fractured unconventional resources. The new approach relies on the rate-normalized flow rate derivative (RNFD) concept. It uses the significant constant behavior of the RNFD that identifies the power-law type flow regime models of fractured reservoirs. This technique merges the RNFD with a new numerical model for the flow rate derivative (flow rate noise-reducing derivative model). The concept of the RNFD <span><math><mrow><mo>[</mo><mrow><mfrac><mn>1</mn><mi>q</mi></mfrac><mrow><mo>(</mo><mrow><mi>t</mi><mi>x</mi><msup><mi>q</mi><mo>′</mo></msup></mrow><mo>)</mo></mrow></mrow><mo>]</mo></mrow></math></span> is developed based on the power-law type analytical models of the flow regimes that can be characterized from the production history of gas or oil-producing wells. The production rate, cumulative production, and the calculated RNFDs from the production history are used for this purpose. The constant RNFD values and the flow rate derivative's numerical model can be used to simulate the production history or predict future performance. The impact of the skin factor is introduced to the approach by developing new RNFD models that could replace the constant pattern of RNFD when this impact does not exist. For a severe condition of skin factor, the RNFD shows a linear relationship with time instead of the constant value. The proposed approach gives an excellent match with the production history of the case studies examined in this study. The transition between flow regimes does not impact the application of the RNFD, i.e., the calculations move very smoothly throughout the flow regime. The novelty of the proposed technique is represented by introducing an approach for the DCA that considers the observed flow regimes during the production history and the impact of the skin factor. The approach proposes new numerical flow rate and cumulative production models to predict future performance as well as new models for estimating the impact of skin factors on production history, especially for early time flow regimes.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 837-853"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760596","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Efficacy of functionalized MWCNT-based polymeric nanofluids for enhancing oil recovery in reservoirs","authors":"Weeam Al Shidi ,&nbsp;Tarek Ganat ,&nbsp;Najeebullah Lashari ,&nbsp;Usman Taura ,&nbsp;Hamoud Al-Hadrami","doi":"10.1016/j.ptlrs.2025.04.008","DOIUrl":"10.1016/j.ptlrs.2025.04.008","url":null,"abstract":"<div><div>Polymer-based enhanced oil recovery boosts production in depleted oil fields. However, harsh reservoir conditions, such as high salinity and temperature, often reduce its effectiveness. This study explores the use of a new aqueous polymeric nanofluid to overcome these challenges. The polymer we evaluated was partially hydrolyzed polyacrylamide (HPAM) with 40% hydrolysis and a molecular weight of 10 MD. The objective of this investigation was to enhance the efficacy of HPAM by incorporating multiwalled carbon nanotubes functionalized with COOH (MWCNT-COOH). Various tests were conducted to evaluate the polymeric nanofluid, including Fourier transform infrared spectroscopy for bonding detection, viscoelastic behavior analysis under static and dynamic shear rates, interfacial tension measurements using the spinning drop technique, and wettability alteration studies through contact angle measurements. The efficiency of the new nanofluid in enabling oil recovery was compared to that of conventional polymers through core flooding experiments. The optimized polymeric nanoparticle injection resulted in a 10% increase in recuperation. This suggests that polymeric nanofluids may be a plausible solution for enhancing oil recovery—a solution that could boost oil production in reservoirs.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 902-911"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760695","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A new method for minimum distance separation factor calculation based on particle swarm optimization algorithm","authors":"Hu Yin ,&nbsp;Rui Liu ,&nbsp;Qiang Wei ,&nbsp;Tao Fan ,&nbsp;Xiuwen Zhao","doi":"10.1016/j.ptlrs.2025.03.004","DOIUrl":"10.1016/j.ptlrs.2025.03.004","url":null,"abstract":"<div><div>Anti-collision technology for wellbores is integrated into both the pre-drilling design and real-time drilling monitoring of cluster wells, infill wells, and directional wells. This technology encompasses well separation distance, position uncertainty analysis, and the separation factor method. Because the separation factor method comprehensively accounts for the first two approaches, its evaluation results serve as a crucial foundation for wellbore anti-collision design and construction. The accuracy of a separation factor method depends on how the error ellipsoid's posture is handled during position uncertainty analysis. Existing methods—including the traditional separation factor method, central vector method, perpendicular line method, and oriented separation factor method—each exhibit accuracy limitations. The traditional separation factor method and the perpendicular line method tend to be overly conservative, whereas the central vector method and the oriented separation factor method often yield overly optimistic results. The minimum distance separation factor method proposed by the Industry Steering Committee on Wellbore Survey Accuracy (ISCWSA) provides a more precise assessment of wellbore separation, but its calculation model has not been explicitly published. Some researchers have attempted to address the minimum distance calculation problem for ellipsoids using constrained optimization theory. However, this approach faces challenges related to convergence and low computational efficiency. To overcome these issues, this paper proposes a minimum distance separation factor calculation method based on the particle swarm optimization algorithm. By iteratively determining the minimum distance between error ellipsoids in three-dimensional space, this method achieves higher computational efficiency and greater accuracy, making it particularly suitable for dense cluster well design and anti-collision analysis. Additionally, due to the simplicity and minimal parameter requirements of the particle swarm optimization algorithm, this approach is more practical for field applications.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 854-863"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760613","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}