Petroleum Research最新文献

{"title":"Study on the phase behavior and mass transfer laws of CO2-shale oil in shale oil reservoirs","authors":"FuLin Yang,&nbsp;YingYing Chen","doi":"10.1016/j.ptlrs.2025.11.005","DOIUrl":"10.1016/j.ptlrs.2025.11.005","url":null,"abstract":"<div><div>Injecting CO₂ into shale oil reservoirs has the dual purpose of enhancing oil recovery rate and geological storage of CO₂. The phase behavior and mass transfer laws of the CO₂-shale oil are crucial for achieving highly efficient production shale oil and gas. Based on an improved vapor-liquid equilibrium (VLE) model in nanopores, which achieves a relative error of less than 3.16%, this study investigates the phase behavior and CO₂–oil mass transfer laws of two representative shale oils under CO₂ injection. Research results show that after CO₂ injection, the saturation pressure tends first to increase and then reduce. The CO₂ dissolution results in a significant reduction in the molecular weight and viscosity of Wolfcamp shale oil. During the multi-contact shale oil with CO₂ injection, both density and the interfacial tension (IFT) reduce at the forward contact edge, indicating forward-contact miscibility. Furthermore, the nanoconfinement effect reduces the density difference between the liquid and gas phases, leading to a reduction in the IFT, which is beneficial for gas-oil miscibility. The study results can provide a theoretical basis for understanding compositional variations in shale oils under CO₂ injection, offering promising improvements in miscibility and recovery efficiency.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 870-879"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949160","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Influence of dually modified tapioca starch on drilling fluid filtration and filter cake development on rock samples","authors":"Imtiaz Ali,&nbsp;Maqsood Ahmad,&nbsp;Shiraz Ahmad,&nbsp;Muhammad Yasir","doi":"10.1016/j.ptlrs.2026.01.009","DOIUrl":"10.1016/j.ptlrs.2026.01.009","url":null,"abstract":"<div><div>Degradation of biomaterials under high temperatures and saline conditions leads to deterioration and loss of performance in deep well drilling applications. This research focuses on examining the impact of colloidal and dually modified tapioca starch (CMITS) on filtration characteristics. Mud filtration properties under various conditions of temperatures were evaluated through API and HPHT filter presses. Different rock samples, including sandstone and limestone, each characterized by unique pore size distributions, porosity, and permeability, are utilized to simulate filtration processes. The thermal stability of drilling fluid additives and the interactions between rocks and filtrate are investigated in hot roll oven and aging cells. The findings evaluate the interaction between temperature and starch additives on mud filtration properties. Notably, in sandstone samples, at 200 °F, Bandera Brown exhibits the lowest filtrate volume (6.2 mL) with DS 0.66 starch, while Boise sandstone produced a higher volume (38.6 mL) due to its inherent permeability. As the temperature rises to 250 °F, the effects become more pronounced. At 250 °F, Indiana limestone with DS 0.66 starch shows minimal filtrate loss (5.4 mL), while Boise sandstone faces pore plugging issues resulting in higher filtrate volumes. At 300 °F, temperature continues to exert change, with Indiana limestone and Bandera Brown displaying minimal filtrate volumes.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 927-934"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949181","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A technical review of in situ conversion technologies for oil shale","authors":"Atif Zafar,&nbsp;Mishal Iqbal,&nbsp;Yumna Sami","doi":"10.1016/j.ptlrs.2026.01.013","DOIUrl":"10.1016/j.ptlrs.2026.01.013","url":null,"abstract":"<div><div>The global depletion of conventional oil and gas resources has led to the exploration of alternative energy resources. Among these resources, oil shale is a fine-grained sedimentary rock with a large amount of kerogen that has attracted increasing attention from the hydrocarbon industry and researchers due to the enormous global reserves of oil shale, which are larger than those of conventional crude oil. However, <em>in situ</em> conversion technologies (ICTs) constitute a practical and environmentally friendly technology for extracting hydrocarbons from oil shale formations without traditional surface mining. This study provides a comprehensive analysis of the primary ICTs developed and evaluated in this field to date. Convection-based approaches, such as steam injections and modified thermal injection (MTI), conduction-based heating approaches, such as Shell’s <em>in situ</em> conversion process (ICP) and ExxonMobil’s Electrofrac™, and radiant heating techniques that utilize radio frequency and microwave energy, are critically evaluated in this study. Advanced innovations, such as near-critical water extraction, nitrogen-assisted <em>in situ</em> conversion process (NAICP), and terahertz spectroscopy (a diagnostic tool for reservoir evaluation), highlight the advanced direction of this field. Mechanistic insights into pore–fracture network formation, kerogen pyrolysis, and their function in improving permeability and hydrocarbon flow have also been analyzed. Challenges related to energy efficiency, operating costs, and environmental impacts still remain despite these technological advancements. Addressing these limitations by maximizing thermal delivery, catalytic enhancement, and integrated modeling will be crucial for realizing the large-scale viability of ICTs. Future research should focus on increasing the efficiency of energy recovery while maintaining environmental sustainability and economic competitiveness.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 848-869"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949159","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Performance evaluation of hybrid polymer-phosphonate scale inhibitors in oilfield water flooding operations","authors":"Azizollah Khormali,&nbsp;Soroush Ahmadi,&nbsp;Yousef Kazemzadeh","doi":"10.1016/j.ptlrs.2026.01.014","DOIUrl":"10.1016/j.ptlrs.2026.01.014","url":null,"abstract":"<div><div>The formation of inorganic scales such as calcium sulfate and barium sulfate during water injection in oilfields can severely impair productivity by clogging pores and reducing rock permeability. This study evaluates the performance of two industrial scale inhibitors—diethylenetriaminepenta (methylene phosphonic acid) (DTPMP) and polyphosphinocarboxylic acid (PPCA)—and their hybrid blends in mitigating scale formation under laboratory and simulated reservoir conditions. Laboratory assessments included scale prediction modeling, static bottle tests, dynamic tube blocking, turbidity, and coreflooding experiments to determine inhibition efficiency, retention behavior, and formation damage potential. Thermodynamic modeling using OLI Studio predicted the maximum scaling tendency at a mixture of 70% injection water and 30% formation water, which was used as the baseline brine for testing. The 50:50 PPCA:DTPMP blend achieved the highest inhibition efficiency (&gt;90%) for both calcium and barium sulfate scales at only 50 ppm, outperforming individual inhibitors. Under dynamic tube blocking conditions, the hybrid system maintained stable pressure profiles, effectively delaying scale nucleation and reducing pressure buildup. Turbidity analyses showed lower light transmittance values (5.6%–6.1%) for the blend, confirming its superior resistance to particle formation and growth. Coreflooding experiments further revealed that the hybrid inhibitor minimized permeability loss to only 5%, compared with 72% in the blank and 9–13% for the single-inhibitor cases. Adsorption/desorption experiments confirmed rapid adsorption (equilibrium in &lt;2 pore volumes) and sustained desorption over 20 pore volumes, indicating strong and prolonged retention. These results demonstrate a positive synergistic effect between the nucleation inhibition mechanism of PPCA and the crystal growth suppression mechanism of DTPMP. The 50:50 hybrid formulation offers a practical, efficient, and economically viable solution for long-term scale management under reservoir conditions.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 775-788"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949221","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Corrosion inhibitors in drilling mud: Advances, challenges, and future Directions","authors":"Precious Jumbo-Egwurugwu,&nbsp;Syahrir Ridha,&nbsp;Muhammad Hammad Rasool,&nbsp;Okorie Agwu Ekwe,&nbsp;Shwetank Krishna","doi":"10.1016/j.ptlrs.2026.02.004","DOIUrl":"10.1016/j.ptlrs.2026.02.004","url":null,"abstract":"<div><div>Corrosion remains a persistent challenge in drilling operations, particularly under high-pressure, high-temperature (HPHT) conditions, resulting in economic losses and safety risks. While conventional corrosion inhibitors have been effective to varying extents, their limitations, particularly in terms of toxicity, biodegradability, and compatibility with drilling fluid properties, necessitate exploring sustainable alternatives. Recent advances have focused on green inhibitors, notably plant-derived extracts, due to their biodegradability and low toxicity. However, a critical gap remains: few studies holistically evaluate both corrosion inhibition efficiency and the resultant impact on drilling fluid performance. To address this, the present review introduces an Integrated Screening and Corrosion Inhibition Modelling (I-SCIM) framework. This review comprehensively synthesizes recent research on corrosion inhibitors used in water-based, oil-based, and synthetic-based fluids. It categorizes inhibitors, evaluates their performance, and discusses their integration into complex mud systems. Key findings highlight that while conventional inhibitors achieve 70–85% efficiency, emerging green and hybrid formulations often exceed 90% inhibition. Furthermore, the paper explores the emerging class of smart and responsive inhibitors that adapt to environmental stimuli such as pH and temperature, highlighting their potential in dynamic wellbore conditions. By adopting the I-SCIM framework, this paper bridges the fragmented assessment approaches in current literature and proposes a unified strategy for evaluating corrosion inhibitors beyond inhibition efficiency alone. The review culminates in future research recommendations for inhibitors that are sustainable, efficient, and compatible with the evolving demands of HPHT drilling.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 974-994"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949266","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Large-scale visualized physical simulation of the occurrence and flow of condensate oil in fracture-vuggy condensate gas reservoir","authors":"Zhouhua Wang,&nbsp;Xin Zhou,&nbsp;Haoqi Liao,&nbsp;Jinchuan Wu,&nbsp;Xingliang Deng,&nbsp;Zhiliang Liu,&nbsp;Hanmin Tu,&nbsp;Ping Guo,&nbsp;Huang Liu","doi":"10.1016/j.ptlrs.2025.11.009","DOIUrl":"10.1016/j.ptlrs.2025.11.009","url":null,"abstract":"<div><div>The Tazhong No. 1 condensate gas reservoir in Tarim Basin shows complex storage spaces and strong heterogeneity. To intuitively assess the production performance characteristics of the condensate gas reservoir and understand the occurrence mechanism of condensate oil, an experimental device and method for visualized simulation of depletion exploitation in fracture-vuggy condensate gas reservoirs were established. The condensate oil precipitation characteristics and dynamic parameters of different reservoir types during depletion were tested. The research indicates that the condensate oil occurrence characteristics in the single-fracture-vuggy model are similar to those in the multi-fracture-vuggy model. Condensate oil that precipitates on the pore walls slides down as droplets under the influence of gravity, eventually gathering at the corners of the lower areas of the pores. Unlike porous reservoirs, fracture-vuggy condensate gas reservoirs exhibit significant retrograde vaporization during the late stages of depletion production. As the depletion rate increases, the recovery degree of condensate oil also rises. For the single-fracture-vuggy model, recovery increases by 7.68%, and for the multi-fracture-vuggy model, by 9.85%, when the depletion rate is 6 MPa/h compared to 3 MPa/h. The results of this research provide crucial insights for developing technical measures to enhance condensate oil recovery in the middle and late stages of fracture-vuggy condensate gas reservoir development.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 687-694"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949166","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Laboratory physical simulation study on water flooding EOR mechanisms and patterns in FM fault- fractured-vuggy reservoirs","authors":"Hanmin Tu,&nbsp;Jinchuan Wu,&nbsp;Zhouhua Wang,&nbsp;Xingliang Deng,&nbsp;Ping Guo,&nbsp;Zhiliang Liu,&nbsp;Haoqi Liao","doi":"10.1016/j.ptlrs.2026.01.002","DOIUrl":"10.1016/j.ptlrs.2026.01.002","url":null,"abstract":"<div><div>The FM fault-fractured-vuggy volatile oil reservoir exhibits significant heterogeneity and rapid production decline. Furthermore, there are notable differences in the effects of depletion development, and the impact of volatile oil degassing on water injection parameters remains unclear. This paper established artificial cores that replicate both single-fractured-vuggy and multi-fractured-vuggy full-diameter systems, reflecting a typical reserves ratio of pores, fractures, and caves in the FM oilfield. Concurrently, water injection experiments were conducted for both single-well and multi-well units after natural energy depletion had occurred. The results indicated favorable development when single-well units opened the lower part of the fracture-vuggy zone, allowing for depletion below bubble pressure at an early stage. Due to dissolved gas flooding at the top of reservoirs, crude oil depletion recovery reached over 67%. The filling of fractures and caves led to delayed degassing: single-phase seepage before degassing was influenced by reservoir physical properties. In contrast, multiphase seepage after degassing was affected by fluid viscosity. The single-well units employed large-volume water injection huff-<em>n</em>-puff techniques, resulting in a pronounced gravity oil displacement effect. This method improved cumulative crude oil recovery by more than 5%. Additionally, it was recommended that multi-well units adopt a deep injection and shallow production development strategy, with continuous water flooding enhancing oil recovery by over 40%. However, during the asynchronous injection-production stage, the recovery improvement was limited to only 1%.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 761-774"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949220","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of random forest model optimized with genetic algorithm for determination of minimum miscibility pressure in CO2 flooding","authors":"Siyi Zheng,&nbsp;Mengping Liu,&nbsp;Yuan Zhang,&nbsp;Jinghong Hu","doi":"10.1016/j.ptlrs.2026.01.015","DOIUrl":"10.1016/j.ptlrs.2026.01.015","url":null,"abstract":"<div><div>CO₂ flooding is an efficient technique for enhancing oil recovery and carbon sequestration, where accurate estimation of the minimum miscibility pressure (MMP) is crucial. Conventional experiment and numerical simulations are time-cost and often inaccurate. Therefore, it is essential to develop an efficient and accurate model for MMP prediction. In this work, we introduced a genetic algorithm-optimized random forest (GA-RF) model using 260 samples with eight input features, including reservoir temperature (T_R), molecular weight of C₅₊ pseudo-components (MWC₅₊), ratio of the mole percent of volatile to intermediate fractions (vol./int.), and mole fractions of injected gas (CO₂, H₂S, CH₄, C₂–C₄, and N₂). Four algorithms-random forest (RF), multilayer perceptron (MLP), support vector regression (SVR), and gradient boosting decision tree (GBDT) are compared. RF performs best and is further optimized by GA. The resulting GA-RF model outperforms traditional methods, with prediction accuracy of 0.99 and a root mean square error of 0.74. The model was applied to CO₂-hydrocarbons system from different low-permeability reservoirs in China. Results show that the GA-RF model demonstrated an average relative error of 3.43%. These findings highlight that the GA-RF model has great potentials for predicting MMP during CO₂ flooding and improving CO₂ miscible flooding efficiency.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 838-847"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949157","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Data-driven real-time prediction of cutting's transport index in directional wellbores","authors":"Mohammed Al-Shargabi,&nbsp;Shadfar Davoodi,&nbsp;David A. Wood,&nbsp;Mohammad Mehrad,&nbsp;Mohammed Al-Rubaii","doi":"10.1016/j.ptlrs.2025.11.010","DOIUrl":"10.1016/j.ptlrs.2025.11.010","url":null,"abstract":"<div><div>The drilling of non-vertical wellbores requires effective real-time monitoring techniques to improve drilling efficiency. This study innovatively develops nine robust hybrid machine learning (HML) models to develop a real-time surrogate model for the drilling cuttings transport index (DCTI). The DCTI, a comprehensive indicator of hole-cleaning efficiency, is typically calculated with a 2–4 h delay due to its dependency on laboratory-measured fluid properties. Our hybrid ML models overcome this limitation by accurately emulating the DCTI value using only real-time, surface-recorded drilling data. A 6818-record dataset was collected from three oil and gas fields (Eastern Province of Saudi Arabia), comprising three offshore and two onshore wells. Following a meticulous dataset preprocessing, a non-dominated sorting genetic algorithm (NSGA-II) was applied with a multi-layer perceptron neural network (MLPNN), identifying seven key features influencing DCTI – inclination angle (ANG), rate of penetration, flow in, depth, torque, stand-pipe pressure (SPP), and revolutions per minute. Extreme learning machine (ELM), MLPNN, and radial basis function neural networks (RBFNN) were hybridized with particle swarm optimization (PSO) and a growth optimizer in two stages: (1) to determine the optimal model structure, and (2) to fine-tune the model hyperparameters to precisely estimate DCTI based on the selected features. The HML models achieved better estimation performance and generalizability than the standalone models. Achieving the lowest root mean square error (RMSE = 0.00344), the RBFNN-PSO model exhibited the best DCTI estimation performance. Analytical scoring, robustness, and Monte Carlo simulation confirmed this model's superior performance, robustness, and high generalization. Shapley additive explanations (SHAP) feature influence analysis revealed that ANG exerted the most influence on the RBFNN-PSO estimations, while SPP had the least impact. During drilling operations, the proposed data-driven approach practically enables drilling crews to diagnose and monitor hole-cleaning performance in real time and improve the rate of penetration. Furthermore, SHAP analysis transforms the model into a prescriptive tool, identifying the primary real-time parameters affecting hole cleaning. This enables drillers to make targeted operational decisions, such as adjusting the rate of penetration or flow rate, to mitigate developing issues.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 895-911"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949161","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Design and analysis of a micro hydraulic reamer-while-drilling tool","authors":"Xiaofeng Sun,&nbsp;Zuhai Qin,&nbsp;Wenhao Wang,&nbsp;Tie Yan","doi":"10.1016/j.ptlrs.2026.01.011","DOIUrl":"10.1016/j.ptlrs.2026.01.011","url":null,"abstract":"<div><div>Casing window sidetracking is a key technique for tapping remaining oil in small-scale enriched zones, such as minor anticlines and thin interbeds. While reaming-while-drilling (RWD) technology can mitigate issues like wellbore necking and stuck pipe caused by narrow sidetracked holes, conventional RWD tools are often excessively long, failing to meet the demands of high-curvature window sidetracking operations. To address this challenge, this study systematically investigates the structural principles and mechanical performance of hydraulic RWD tools. Through theoretical analysis, structural design, and numerical simulation, a novel micro hydraulic RWD tool activated by differential pressure was developed, followed by prototype fabrication and laboratory testing. The research results demonstrate that: Cutter stress analysis reveals that axial stress on arm is proportional to the cutting arc angle, while cutting resistance inversely correlates with it. An optimal 35° cutting arc angle minimizes resistance and prevents tool failure caused by locking ball bearing damage. The locking mechanism employs a line-line contact design between ball, housing, and sliding sleeve, effectively avoiding stress concentration and plastic strain. Based on hydrodynamic theory, the influence of the sliding sleeve's inner diameter on flow velocity, pressure differential, and total head loss was investigated, establishing a design methodology to ensure stable tool activation while minimizing energy dissipation. Applying thick-walled cylinder elastic theory, an interference-fit length calculation model was developed for the sleeve-housing interface. This methodology effectively prevents premature tool triggering while guaranteeing reliable arm retraction performance. Laboratory tests confirm successful tool activation/deactivation at theoretical flow rates, validating the design methodology. This study provides theoretical foundations for slimhole RWD tool design, enabling customized reaming applications. Its technical solutions hold significant economic and practical value for precisely exploiting residual reserves in mature wells and enhancing reservoir recovery efficiency.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 3","pages":"Pages 935-948"},"PeriodicalIF":3.8,"publicationDate":"2026-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148949216","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}