Petroleum Research最新文献

{"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}

{"title":"High-resolution sequence stratigraphic framework and target sand bodies correlation of tight oil reservoirs in the Upper Triassic Yanchang Formation, Ordos Basin","authors":"Xiulin Hou,&nbsp;Mingqiu Hou,&nbsp;Qingfu Feng,&nbsp;Yuxiang Xiao,&nbsp;Zhengdong Lei,&nbsp;Lingbin Lai,&nbsp;Siyang Li,&nbsp;Hongyu Tian","doi":"10.1016/j.ptlrs.2025.05.003","DOIUrl":"10.1016/j.ptlrs.2025.05.003","url":null,"abstract":"<div><div>In this study, we developed a high-resolution stratigraphic framework for the Yanchang Formation in the Huachi Block of the Qingyang Oilfield, located in the Ordos Basin, northwest China. Using well log and seismic data, we traced and correlated sweet-spot sand bodies in tight oil reservoirs. Three long-term base-level cycles were identified in the Yanchang Formation, and five medium-term base-level cycles were delineated from the Chang 72 sub-Member to the Chang 4 + 5 Members, corresponding to five distinct oil groups. The primary production layer, Oil Group 3, was further divided into short-term and very short-term base-level cycles to facilitate the prediction of hydrocarbon target zones. Sweet-spot sand bodies were traced and correlated within very short-term cycles. The sweet-spot sand bodies are mainly sublacustrine channel deposits in the delta front, which were mainly developed in the five single layers (3-1-2, 3-1-3, 3-1-4, 3-2-2, 3-2-3 and 3-2-5) of the small layers 3-1 and 3-2 during the regression periods of base-level cycles. The sweet spot sand bodies within the small layer 3-2 are derived from three sets of sources in the northeast, northwest, and south of the basin. The Class I sweet spot is distributed within the single layer 3-2-5, with an average thickness of about 6 m, covering about 25% of the study area. The Class II sweet spot is developed in all five single layers, with the thickest and largest sweet-spot sand body in the Single layer 3-2-3, covering about 90% of the study area. This study highlights the critical importance of establishing a high-resolution sequence stratigraphic framework for the refined delineation of sweet-spot sand bodies within a deltaic-lacustrine depositional system. Additionally, sublacustrine fan deposits formed during the regressive semi-cycle were identified as key sweet spots in the study area.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 749-763"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760648","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":"Starch nanoprecipitation with ethanol for the formulation of ultralow salinity formation water-tapioca starch nanoparticles potentially for enhanced oil recovery application","authors":"Suriatie Yusuf ,&nbsp;Akhmal Sidek ,&nbsp;Shaziera Omar ,&nbsp;Sairoz Norazlan Sharbini ,&nbsp;Hasanain Ali Al-Jaber","doi":"10.1016/j.ptlrs.2025.05.009","DOIUrl":"10.1016/j.ptlrs.2025.05.009","url":null,"abstract":"<div><div>The present study evaluated commercial starch behavior and tapioca starch nanoparticles (TSNP) with 100 ppm ultralow salinity formation water as a potential alternative for enhanced oil recovery (EOR). Generally, starch exhibits excellent properties as a conventional viscosifier substitute in the petroleum industry. This study proposed a conventional polymer substitute, which is typically hydrolyzed polyacrylamide (HPAM) or oxide nanoparticles, for chemical flooding EOR employment. The TSNP was successfully synthesized via nanoprecipitation with ethanol as the precipitant medium. Two TSNP of different sizes, 1% and 3%, are successfully synthesized, which demonstrated chemical and physical attributes almost identical to raw tapioca starch (TS), corroborating their composition similarities. The 1% TSNP was significantly smaller compared to the 3% TSNP, but both samples possessed distinct angular, polygonal, and truncated shapes with sharp edges. Although the structure of the TSNP synthesized was a C-type crystal, their crystallinity was slightly lower. Fourier-transform infrared (FTIR) and energy dispersive X-ray (EDX) analyses confirmed similar chemical compositions of the raw TS and TSNP assessed. The EOR formulations employed in the study were prepared with various TS and TSNP concentrations, ranging from 0 ppm to 2000 ppm. The formulations were assessed at various temperatures between 25 °C and 75 °C. Rheological results indicated that TS and TSNP formulations coupled with low salinity formation water yielded non-Newtonian shear thickening behavior with respect to starch types, concentrations, temperatures, and shear rates. The 1% TSNP formulation exhibited favorable solution viscosifying criteria than the 3% TSNP sample within evaluated parameters. Surface tension, IFT, and wettability alteration measurements revealed indirect and inconclusive trend regarding TSNP concentrations and temperatures. Nonetheless, adding 1% and 3% TSNP considerably influenced IFT reduction and wettability alteration in several favorable combinations, indicating feasibility for EOR applications.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 864-881"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760693","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":"Treatment of water disposal injection process by oilfield chemicals: Maintaining injectivity and environmental effects","authors":"Peyman Abbasi ,&nbsp;Mohammad Madani ,&nbsp;Shokoufah Abbasi","doi":"10.1016/j.ptlrs.2025.04.007","DOIUrl":"10.1016/j.ptlrs.2025.04.007","url":null,"abstract":"<div><div>Oil production from hydrocarbon reservoirs is invariably accompanied by water production, which poses significant challenges to both production and injection systems, particularly due to the formation of mineral scales. While scale formation in production wells has been extensively studied, its impact on water disposal wells which is critical for managing produced water and ensuring environmental compliance, remains underexplored. This research gap is especially important because disposal wells face unique challenges, such as injectivity loss, environmental risks from wastewater release, and the need for sustainable scale management practices. This study addresses these challenges by investigating mineral scale formation in a water disposal well in southern Iran. Unlike previous research focused on production wells, this work emphasizes the unique operational and environmental implications of scale precipitation in disposal wells. For this purpose, field information including well schematic, disposal injection system data and acidizing jobs processes performed in well A is investigated. Analyzing and simulation of the composition of the water disposal sample resulted that maximum amount of scale precipitation in surface pipeline is equal to 92 mg/l owing to CaSO₄ precipitation. Also, CaSO₄ and CaCO₃ are precipitated within near wellbore area. CaSO₄ is the dominate scale type and maximum amount of this scale is 656 mg/l and CaCO₃ is minor scale type with 54.42 mg/l in near wellbore condition. Furthermore, based on the injection pressure and injection rate data assessment in the time interval between two consecutive acidizing jobs, the formation of scales and the reduction of injectivity in well A are proved. Also, from operation point of view and according to ASTM-0374 method, scale inhibitor should be injected continuously at a concentration of 40 ppm from the surface to cover the entire injection system. The results show that scale inhibitor is an effective solution in prevention of scale precipitation, with 95.2% efficiency in scale formation inhibition. By focusing on disposal wells, this study provides novel insights into scale management strategies tailored to the unique requirements of water disposal operations. The findings highlight the effectiveness of chemical inhibitors in preventing scale formation and offer a sustainable alternative to conventional acidizing methods. This research contributes to advancing environmentally responsible practices in oilfield water disposal, addressing a critical gap in the field.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 894-901"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760696","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":"Clay mineral content and their impact on reservoir quality: Insight into the carbonate reservoirs oil fields, Central-Eastern Russia","authors":"Dmitriy A. Martyushev ,&nbsp;Shadfar Davoodi ,&nbsp;Anastasia D. Anickaeva ,&nbsp;Zhao Zhi","doi":"10.1016/j.ptlrs.2025.04.003","DOIUrl":"10.1016/j.ptlrs.2025.04.003","url":null,"abstract":"<div><div>Clay minerals are widespread in both sandstone and carbonate reservoirs. Previous studies have emphasized that clay minerals influence oil filtration in sandstones; however, very few studies to date have examined the influence of clay minerals in carbonates on oil production. To address this, scanning electron microscopy images, X-ray diffraction, nuclear magnetic resonance, and filtration experiments with low-salinity water flooding are used in this study to investigate the presence of clay minerals. Based on the XRD data, the mineralogy of cement in the carbonate reservoirs of the two fields (Perm Krai, Russia) is characterized by the presence of both non-clay minerals (quartz, feldspar, anhydrite, and halite) and clay minerals (illite/smectite, fibrous illite, and kaolinite). Illite/smectite flakes occur mainly as small platelets (&lt;0.2 μm), which are distributed over the surface of the calcite crystals. However, individual illite/smectite flakes were identified, reaching 50 μm in width and ∼5 μm in thickness. The NMR results indicate a significant amount of clay-bound water is present in core samples containing illite/smectite flakes and isolated examples of fibrous illite. Kaolinite and fibrous illite readily disperse when interacting with low-salinity water, allowing clay particles to migrate into small pores after dispersion. The dispersion and migration of kaolinite and fibrous illite contribute to a significant decrease in permeability compared to rocks containing only illite/smectite. Thus, studying the mineralogy and chemical composition of clay minerals is an urgent task for hydrocarbon production from carbonate reservoirs. The presence of clay minerals must be determined when selecting process fluids during operations and water for injection in reservoir pressure maintenance systems.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 4","pages":"Pages 791-802"},"PeriodicalIF":4.0,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145760651","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}