Petroleum Research最新文献

{"title":"Synthesis and examination of graphene oxide grafted with copolymer of maleic acid and acrylic acid as a clay stabilizer for enhancing oil production","authors":"Momodou A. Jallow ,&nbsp;Abeer Alarawi ,&nbsp;Tawfik A. Saleh","doi":"10.1016/j.ptlrs.2025.09.003","DOIUrl":"10.1016/j.ptlrs.2025.09.003","url":null,"abstract":"<div><div>In oil and gas production operations, wellbore instability is primarily caused by shale hydration. Thus, a thermally stable inhibitor is essential to prevent shale hydration. This research focuses on synthesizing a copolymer of maleic acid and acrylic acid/graphene oxide (poly-(AAMA)-GO) via free radical polymerization as an effective and low-cost inhibitor. The combination of the copolymer and graphene oxide aims to produce a fluid inhibitor with high thermal stability. Additionally, the unmodified copolymer of acrylic acid and maleic acid poly-(AAMA) was synthesized for comparative analysis. The inhibitory properties of both compounds were evaluated using anti-swelling, immersion, and shale recovery tests, with potassium chloride (KCl) serving as the industry benchmark. Poly-(AAMA) and poly-(AAMA)-GO effectively inhibited sodium bentonite swelling, achieving anti-swelling ratios of 75% and 78%, respectively, compared to 58% for KCl. Characterization revealed that poly-(AAMA) and poly-(AAMA)-GO adhered to sodium bentonite particles through electrostatic interactions and hydrogen bonding, forming a thin film that enhanced hydrophobicity and limited water penetration into the interlayers. Poly-(AAMA)-GO exhibited excellent thermal stability up to 250 °C, demonstrating its potential for high-temperature well fluid. Despite their structural differences, both compounds exhibited similar inhibitory effectiveness due to their shared chemical characteristics.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 92-100"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556436","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":"Correlation-based EUR prediction of shale oil wells: A case of the Qingcheng Oil Field in the Ordos Basin","authors":"Suiyi Fu ,&nbsp;Lingbin Lai ,&nbsp;Zhengdong Lei ,&nbsp;Qingfu Feng ,&nbsp;Huizhu Xiang ,&nbsp;Bo Wang ,&nbsp;Xiulin Hou ,&nbsp;Ting Xue","doi":"10.1016/j.ptlrs.2025.06.001","DOIUrl":"10.1016/j.ptlrs.2025.06.001","url":null,"abstract":"<div><div>Shale reservoirs are characterized by low permeability and a weak capacity for natural seepage. These reservoirs are commonly developed using a combination of horizontal well drilling and fracturing. The production performance of shale oil wells is evaluated through single-well production decline analysis, with the estimated ultimate recovery (EUR) used as an important indicator of the development outcome. This study predicted the EUR of the X233 well zone in the Qingcheng Shale Oil Field in the Ordos Basin. It reviewed the applicability of production forecasting methods to unconventional reservoirs and put forward a correlation-based approach to EUR prediction. The latter was developed by integrating the characteristics of Qingcheng shale oil production with EURs predicted using empirical methods intended for typical wells. The correlation-based approach was also designed on the basis of the relationship between cumulative oil production and the empirically derived EURs. The results suggest that the proposed method rapidly predicts the EUR of a single well using cumulative oil production from the first one, two, and three years of production. The predictions closely align with the empirically derived values, demonstrating the strong practical effectiveness of the approach put forward in this work. To determine its applicability and limitations, this study examined the EUR distribution characteristics of different well classes (Classes I to III). This research provides a simple and effective approach to rapidly predicting the EURs of shale oil wells, significantly reducing computational time and labor costs.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 63-71"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556507","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":"Enhancing oil recovery of gas flooding by regulating rock surface wettability","authors":"Chengxi Deng ,&nbsp;Min Chen ,&nbsp;Changsong Liu ,&nbsp;Yinfeng Xu ,&nbsp;Yonghui Du ,&nbsp;Hua Dong","doi":"10.1016/j.ptlrs.2025.07.005","DOIUrl":"10.1016/j.ptlrs.2025.07.005","url":null,"abstract":"<div><div>Rock surface wettability plays a crucial role in gas flooding for oil recovery. Natural rock surfaces are usually oleophilic, resulting in high flooding resistance and low recovery in gas flooding. This study explores the regulation of the wettability of sandstone rock surfaces by modifying them with 1H,1H,2H,2H-perfluorodecyltrimethoxysilane or its mixtures with hexyltrimethoxysilane to achieve oil contact angles ranging from 0° to 93.2°. Simulated gas flooding experiments, with N₂ as model gas, reveal that reducing the oleophilicity of rock surfaces improves gas flooding efficiency. Compared to the unmodified superoleophilic rocks, the final oil recoveries in the cores with neutral oil wettability significantly increases and the pressure differential for gas flooding significantly decreases. In cases of cores with permeability of 22 mD, 0.88 mD and 0.09 mD, the increases in oil recovery are from 28.5% to 37.5%, from 20.2 to 27.3% and from 9.1% to 15.4%, respectively; and the reductions of pressure differential for gas flooding are from 53 kPa to 41 kPa, from 323 kPa to 272 kPa, from 1054 kPa to 935 kPa, respectively. These results highlight the critical influence of wettability regulation on gas flooding efficiency, offering valuable insights for optimizing oil recovery strategies.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 84-91"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556435","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":"Characteristics, emissions, capture, storage, and utilization of carbon dioxide: A comprehensive review of challenges and technologies for greenhouse gas mitigation","authors":"Ali Akbari ,&nbsp;Hossein Sarvi ,&nbsp;Mehdi Maleki ,&nbsp;Sina Bahreyni ,&nbsp;Reza Azimi ,&nbsp;Alireza Radpour","doi":"10.1016/j.ptlrs.2025.07.001","DOIUrl":"10.1016/j.ptlrs.2025.07.001","url":null,"abstract":"<div><div>The capture, storage, and utilization of carbon dioxide (CO₂) are pivotal in combating climate change and mitigating greenhouse gas (GHG) emissions. This review offers a comprehensive and critically focused analysis of post-capture CO₂ handling methods, including storage, adsorption, and utilization, with a particular emphasis on emerging and innovative technologies. Distinctively, this study highlights advanced CO₂ conversion pathways—such as photocatalytic and photoelectrochemical reduction, membrane-based separations, and mineralization—by analyzing their mechanisms, energy demands, techno-economic feasibility, and integration potential with renewable energy sources. The review further explores the role of natural systems, especially microalgae and porous materials, in CO₂ bio-fixation and adsorption under industrial conditions. Unlike conventional reviews, this work provides an in-depth comparative assessment of major capture methods (e.g., cryogenic separation, chemical absorption, and mixed-matrix membranes), emphasizing recent advancements and material innovations that enhance selectivity, thermal stability, and operational efficiency. By integrating perspectives from material science, process engineering, and environmental policy, this review presents a novel synthesis of current challenges and future opportunities in circular carbon management. These insights aim to support the development of scalable, cost-effective, and sustainable CO₂ mitigation strategies for industrial deployment.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 116-138"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556421","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":"Deep learning supported uncertainty quantification of core saturation measurements","authors":"Klemens Katterbauer,&nbsp;Atul Godbole","doi":"10.1016/j.ptlrs.2025.06.004","DOIUrl":"10.1016/j.ptlrs.2025.06.004","url":null,"abstract":"<div><div>Core extraction and analysis are fundamental components of reservoir development. Core samples provide continuous vertical sections of the subsurface, enabling detailed visual assessment of depositional sequences and variations in reservoir characteristics. A thorough examination of these cores yields critical information significantly contributing to understanding and optimizing reservoir development. This data can include direct evidence of hydrocarbons' presence, quantity, spatial distribution, and production potential. The analysis of core samples is vital for understanding the pore system properties within potential reservoir intervals. Insights derived from core data improve the ability to predict reservoir performance and inform the selection of strategies to maximize cost-effective hydrocarbon recovery. This study employs a representative dataset from the Arabian Peninsula, specifically within the United Arab Emirates, using the Costa model as a supporting framework. The analysis incorporates the largest and smallest available sample sizes to ensure the final results remain within an acceptable range of variation. Each input parameter—core length, diameter, weight, fluid volumes, oil density, brine salinity (ppm), and brine density—is systematically varied to evaluate its impact on key reservoir properties, including saturation, porosity, permeability, and grain density. Additionally, the study investigates the effects of various combinations of incorrect input parameters to assess their influence on overall measurement accuracy. This methodology underpins a novel, AI-driven approach to uncertainty estimation in reservoir analysis. This approach enables more accurate assessment and informed decision-making in reserve estimation and reservoir management by quantifying the uncertainty in core-derived measurements.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 101-115"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556437","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 review on advancing clay-based geopolymers for high-temperature oil well cements: Mechanisms, durability, and applications","authors":"Barima Money ,&nbsp;Rayan Hassan Modather ,&nbsp;David Abutu ,&nbsp;Norasyikin Ismail ,&nbsp;Augustine Agi ,&nbsp;Francis Nyah ,&nbsp;Siti Qurratu' Aini Mahat","doi":"10.1016/j.ptlrs.2025.08.005","DOIUrl":"10.1016/j.ptlrs.2025.08.005","url":null,"abstract":"<div><div>Geopolymers are promising alternatives to Portland cement due to their lower carbon footprint, superior mechanical strength, durability, and reduced shrinkage. However, inconsistent data and significant variations in experimental results highlight the uncertainty surrounding the reaction mechanisms of clay-based geopolymers (CBGs) in high-temperature oil wells. This review provides critical insights into these mechanisms and summarizes CBG synthesis methods. It explores the reaction processes of CBGs under high-temperature oil well conditions and analyzes the variables influencing these mechanisms. This review also examines the application of CBGs in oil wells, focusing on the challenges and potential solutions. Laboratory studies show that Portland cement degrades at temperatures above 300 °F (150 °C), while CBGs maintain their integrity and strength at temperatures up to 1500 °F (815 °C). This makes them particularly suitable for high-temperature geothermal wells and high-pressure, high-temperature oil well cementing. The dominant reaction mechanisms of CBGs include chemical reactivity, dissolution, gelation, polymerization, and growth. These findings highlight the potential of CBGs in addressing the challenges of high-temperature oil wells, thereby paving the way for further research in this area.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 274-296"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556510","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":"Diagenetic calcite-dolomite-pyrite in the organic-rich shales of the Early Silurian Longmaxi Formation in the Yangtze block, South China","authors":"Yuexiang Hao ,&nbsp;Yi Liu ,&nbsp;Yibo Zhou ,&nbsp;Jiexin Li ,&nbsp;Yumeng Jiang ,&nbsp;Chao Qian ,&nbsp;Xiangrong Yang","doi":"10.1016/j.ptlrs.2025.07.009","DOIUrl":"10.1016/j.ptlrs.2025.07.009","url":null,"abstract":"<div><div>Carbonate minerals (calcite and dolomite) and pyrite are important brittle minerals in organic-rich shales; however, the mechanism of their formation is still uncertain. This study examined the formation of pyrite and carbonate minerals (mainly calcite and dolomite) in the shales of Longmaxi (LMX) Formation through a combination of petrological and geochemical techniques. The results demonstrated that two types of carbonate minerals (calcite and dolomite) and multiple-types of pyrite were identified in the studied shales. The carbonate minerals comprise (1) subhedral to euhedral calcite and dolomite with large diameters (&gt;10 μm), along with low Fe (&lt;2%) and Mn (&lt;0.2%) contents, and (2) calcite and dolomite cement, along with high Fe (&gt;2%) and Mn (&gt;0.2%) contents. The pyrite is primarily composed of framboidal pyrite, infilled framboidal pyrite, pyritic masses, and euhedral pyrite. This study suggests that depositional and diagenetic processes had significant influences on the formation of calcite-dolomite-pyrite in organic-rich shales. In the synsedimentary stage, the expansion of anoxic seawater contributed to the enrichment of organic matter in the shales of lower LMX Formation. In the early diagenesis stage, both the microbial sulfate reduction (MSR) and sulfate-driven anaerobic oxidation of methane (SD-AOM) would generate abundant CO₂, which together with the consumption of SO₄²⁻ further contribute to the precipitation of carbonate minerals (calcite and dolomite). In addition, the MSR would also release ³²S-enriched H₂S and result in the formation of framboidal pyrite/infilled framboids/pyritic masses with low δ³⁴S values (&lt;0‰). However, the SD-AOM would result in the precipitation of euhedral pyrite with high δ³⁴S values (&gt;20‰) and high Co contents (&gt;700 μg/g). In the late diagenesis stage, carbonate cements with high Fe and Mn contents formed due to the diagenetic fluids (high HCO₃⁻ Mg²⁺, Fe²⁺, Mn²⁺ concentrations). Overall, the sulfate-driven anaerobic oxidation of methane (AOM) during early diagenesis in sediments constitutes a key process influencing methane release, in which case extensive methane release during this period may have contributed to Early Silurian global warming.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 1-16"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556511","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":"Numerical simulation of microbial biohydrogen production under high-pressure, high-temperature conditions for enhanced recovery from depleted reservoirs","authors":"David Abutu ,&nbsp;Peter Ikechukwu Nwaichi ,&nbsp;Chika Umunnawuike ,&nbsp;Francis Nyah ,&nbsp;Barima Money ,&nbsp;Hafizuddin Wan Yussof ,&nbsp;Augustine Agi","doi":"10.1016/j.ptlrs.2025.07.006","DOIUrl":"10.1016/j.ptlrs.2025.07.006","url":null,"abstract":"<div><div>The growing demand for sustainable energy has intensified interest in biohydrogen production under extreme environmental conditions. This study presents a numerical simulation of hydrogen production in a high-temperature, high-pressure batch bioreactor system designed to mimic depleted hydrocarbon reservoir environments. The model captures microbial fermentation dynamics using dual substrates glucose and <em>n</em>-hexadecane under varying temperature (35–70 °C), pressure (1–40 atm), salinity (0–50 g/L NaCl), and surfactant-enhanced availability (α = 1–12). Monod kinetics with product (Hydrogen) and salinity inhibition terms govern biomass growth and substrate consumption. Gas accumulation is modeled using Henry's and ideal gas laws, while thermal behavior is represented using lumped heat transfer and Arrhenius-based growth scaling. Initial conditions include 10 mmol/L glucose, 1 mmol/L hexadecane, and 0.1 g/L biomass in a 1.0 L batch system at 55 °C. Over 24 h, the model predicts a maximum hydrogen accumulation of 4.34 L, with a final H₂ purity of 89.6% and biomass concentration of 1.20 g/L. Parametric simulations reveal that 55 °C yields the highest hydrogen output (3.31 mol/mol substrate), while increasing salinity and pressure reduce biomass and gas evolution. Surfactant addition significantly improves hydrocarbon utilization, reducing hexadecane from 1.0 to 0.12 mmol/L at α = 12, with up to 72.8% yield enhancement. Glucose drives early hydrogen evolution, while hexadecane contributes to sustained production under co-metabolic conditions. All equations were solved using Python with parametric looping and ODE integration. This simulation framework provides a robust tool for evaluating microbial-enhanced hydrogen recovery (MEHR) and optimizing reactor design conditions for biohydrogen generation in repurposed subsurface reservoirs.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 206-216"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556354","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":"Sensitivity analysis of effective parameters in water saturation estimation by using Monte Carlo simulation","authors":"Rahman Norouzi ,&nbsp;Hossein Mosaddegh ,&nbsp;Ali Kadkhodaie ,&nbsp;Vali Mehdipour","doi":"10.1016/j.ptlrs.2025.07.003","DOIUrl":"10.1016/j.ptlrs.2025.07.003","url":null,"abstract":"<div><div>Water saturation is one of the primary and influential parameters in evaluating the reservoir quality of hydrocarbon formations and is typically calculated by the Archie equation. This equation employs porosity, cementation factor, saturation exponent, tortuosity factor, formation water resistivity and true reservoir resistivity for water saturation calculation. It should be noted that uncertainty in these values can directly affect water saturation calculation, so the correct water saturation calculation in hydrocarbon reservoirs is essential, and any mistakes in its calculation leads to optimistic or pessimistic consideration of interval of interest. In this study, the Monte Carlo simulation method based on well-logging data were used to investigate the uncertainty of effective parameters in water saturation in the framework of Archie's equation. In this regard, the water saturation is calculated in three wells for the Sarvak reservoir in one of southwestern Iran's giant oilfields. The Monte Carlo simulation was implemented using MATLAB software for each parameter causing uncertainty in the water saturation model, and the distribution function is obtained for each parameter. Water saturation is as a distribution for each depth by investigating the uncertainty of each parameter affecting the Archie equation and is calculated in optimistic, probable and pessimistic cases. The results show that using well-logging data, the mentioned method can calculate the uncertainty of water saturation.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 139-149"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556422","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":"Experimental investigation of tea leaf extract as thinning agent and lubricity enhancer for water-based drilling fluid","authors":"Majedul Islam Khan,&nbsp;M. Farhad Howladar,&nbsp;Ahsanul Hoque Emon,&nbsp;Omar Faruk Nadim,&nbsp;Pranta Das,&nbsp;Omar Faruque","doi":"10.1016/j.ptlrs.2025.08.004","DOIUrl":"10.1016/j.ptlrs.2025.08.004","url":null,"abstract":"<div><div>This study aims to develop a low-cost and environmentally friendly multifunctional thinning agent for water-based mud (WBM) from tea leaf extract (TLE). Matured tea leaves that are not used for tea production were collected, processed, and boiled in distilled water to release the extracts and prepare the liquid thinning agent. The resultant TLE was characterized using Fourier Transform Infrared spectroscopy (FTIR). Rheological properties were measured at two temperature conditions (35 °C and 70 °C) with varying concentrations of TLE, and the findings were compared with the widely used thinning agent potassium lignite (PL) under all test conditions. In addition, the density, pH, filtration control, and lubricating properties were evaluated under ambient conditions. The findings revealed that TLE, under all test conditions, exhibited better thinning performance than potassium lignite. At the temperature of 35 °C, when used at 1% concentration, TLE reduced apparent viscosity, plastic viscosity, yield point, initial and final gel strength by 23.94%, 21.57%, 27%, 76.99%, and 24.44%, respectively, compared to 12.89%, 16.34%, 8.44%, 39.82%, and 7.94% using the same concentration of potassium lignite. Compared to the ambient condition, the effectiveness of TLE in controlling rheology was found to be more pronounced at higher temperatures. Moreover, TLE at different concentrations significantly improved the filtration and lubricating properties of the mud. The addition of TLE reduced the mud cake thickness by a maximum of 44.44% and the coefficient of friction by a maximum of 40.7%. The comprehensive investigation and comparison with potassium lignite suggest that TLE can be effectively used as a multifunctional, non-toxic, and low-cost thinning agent for water-based drilling fluids.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"11 1","pages":"Pages 263-273"},"PeriodicalIF":4.0,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147556441","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}