Petroleum Research最新文献

{"title":"Application of hybrid numerical reservoir simulation and artificial neural network for evaluating reservoir performance under waterflooding","authors":"Paul Theophily Nsulangi ,&nbsp;John Mbogo Kafuku ,&nbsp;Guan Zhen Liang","doi":"10.1016/j.ptlrs.2025.02.001","DOIUrl":"10.1016/j.ptlrs.2025.02.001","url":null,"abstract":"<div><div>In the current study, an artificial neural network (ANN) and a numerical reservoir simulation (NRS) technique are used to analyse reservoir performance under waterflooding in the ZH86 block of the Zhaozhouqiao oilfield, China. Using five input datasets extracted from the history-matched NRS model, an NRS-ANN hybrid is trained using a trial-and-error approach. NRS-ANN hybrid model #46 (which has 5, 10, 10, 6, 6, and 1 neurons in the input layer, four hidden layers, and output layer, respectively) is found to produce the minimal root mean square error on the test dataset. On the validation data, the prediction performance of the selected NRS-ANN hybrid model achieves a minimal root mean square error of 0.0274 m³/day and maximal coefficient of determination and coefficient of correlation values of about 0.9999. The correlation between the block liquid production rate (BLPR, m³/day), block water production rate (BWPR, m³/day), block water cut (BWCT, %), block water injection rate (BWIR, m³/day), and block reservoir pressure (BRP, bar) as input variables and the simulated oil production rate (SOPRH) as the output variable is investigated. There is a positive correlation between SOPRH and BLPR, BWIR, and BWCT, and a negative correlation between SOPRH and BRP and BWPR. Segment B of ZH86 block experiences a 3.8% increase in BLPR, while segments A and C show declines of 1.3% and 1.6%, respectively. These variations in the liquid production rate correspond to changes in SOPRH of 4.3%, 1.9%, and 9.7% for segments A, B, and C, respectively. The prediction performance of the NRS-ANN hybrid model is compared with that of a simple NRS model. The accuracy of the NRS-ANN hybrid model in predicting oil production is found to be 1125 times that of the NRS model. Based on these results, it is concluded that the proposed NRS-ANN hybrid provides an accurate and useful tool for analysing reservoir performance under the waterflooding oil recovery technique.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 564-576"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120657","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":"Study on electrochemical corrosion of P110 tubing during air injection oil flooding","authors":"Lijuan Pan ,&nbsp;Xue Han ,&nbsp;Junwei Fang ,&nbsp;Haifu Yuan ,&nbsp;Zhongfu Cheng ,&nbsp;Miaopeng Zhou ,&nbsp;Xin Shi ,&nbsp;Dezhi Zeng","doi":"10.1016/j.ptlrs.2024.12.001","DOIUrl":"10.1016/j.ptlrs.2024.12.001","url":null,"abstract":"<div><div>This article addresses the corrosion problem of P110 tubing during the process of enhancing oil recovery by injecting air. The effects of changes in oxygen content and tensile stress on the corrosion of P110 tubing were studied using electrochemical testing methods. The results show that with an increase in oxygen content (0, 10000 ppm, 20000 ppm, 30000 ppm, 40000 ppm), the product film on the surface of P110 tubing is loose and porous, the film resistance and charge transfer resistance decrease, the self-corrosion current density increases, and the corrosion intensifies. With an increase in tensile stress (0, 20%Ϭs, 50%Ϭs, 70%Ϭs, 100%Ϭs), the corrosion tendency of P110 tubing increases,the stability and protection of the product film are destroyed, the film resistance and charge transfer resistance decrease, the electrochemical activity of the steel surface increases, the self-corrosion current density increases, and the corrosion intensifies.Based on this, considering the effects of oxygen content and tensile stress on the corrosion of P110 tubing, anti-corrosion suggestions are given to provide a reference basis for corrosion control of air-injected tubular columns.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 543-551"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120659","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":"Performance evaluation of fracturing-huff-n-percolation-puff (FHnPP) processes in a hydrocarbon reservoir","authors":"Yanan Ding ,&nbsp;Haiwen Wang ,&nbsp;Maoxian Wang ,&nbsp;Chen Zhang ,&nbsp;Daoyong Yang","doi":"10.1016/j.ptlrs.2025.02.002","DOIUrl":"10.1016/j.ptlrs.2025.02.002","url":null,"abstract":"<div><div>Due to its superior performance on the efficient exploitation of a small fault-block reservoir, a novel technique of fracturing-huff-<em>n</em>-percolation-puff (FHnPP) has received increasing attentions in recent years. In order to clearly identify and understand the associated mechanisms, reservoir simulations have been conducted to evaluate performance of an FHnPP process in a hydrocarbon reservoir. A series of simulation scenarios are designed to evaluate and identify dominant factors based on both single-factor and orthogonal schemes. The FHnPP performance can be understood as follows, i.e., created (micro-)fractures are extended from the surrounding water-zone deeper into formation during water injection, this process rebuilds the pressure field, enabling more trapped oil to be subsequently driven backwards the well after such (micro-)fractures are closed or partially-closed. Surfactants effectively reduce the water/oil interfacial tension (IFT), but it only increases oil production at early times. The existence of secondary fractures slightly enhances oil recovery at early puff-period after which such a positive impact is gradually vanished. A higher matrix permeability yields a higher ultimate oil recovery, but such a yielded positive effect from fracturing is then degraded. Moreover, the residual permeability of fractures during production (i.e., the puff process) negatively affect oil recovery, while a longer length of fracture results in more produced oil. Also, both injection rate and soaking time positively affect the oil recovery though the latter is insignificant. The orthogonal analysis indicates that, sensitivity of the dominant factors affecting oil recovery varies from each other, while the sensitivity of FHnPP's advantages to those factors is found also unequal. In the target reservoir with the optimized FHnPP parameters, significant oil increment (i.e., a recovery factor (<em>RF</em>) of 3.59% (i.e., 609.1 m³ oil)) can be achieved compared with that of the traditional huff-<em>n</em>-puff (THnP) process. This numerical study not only proves the feasibility and advantages of the FHnPP technique, but also deepens our understanding of its performance and identifies the dominating factors.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 458-473"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120705","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":"Hydrogen energy system and underground hydrogen storage in depleted reservoirs","authors":"Arash Ebrahimi ,&nbsp;Kamand Ghasemi ,&nbsp;Ali Akbari ,&nbsp;Yousef Kazemzadeh ,&nbsp;Reza Azin","doi":"10.1016/j.ptlrs.2025.04.002","DOIUrl":"10.1016/j.ptlrs.2025.04.002","url":null,"abstract":"<div><div>In a situation where the increase in greenhouse gas emissions in the atmosphere has unfavorably led to global warming, the production of energy from renewable and clean sources, instead of fossil fuels, has become very attractive worldwide. To replace traditional energy sources, hydrogen (H₂), as the most abundant element in the environment, has emerged as a recently developed energy carrier with a high calorific value. Due to its diverse applications, such as internal combustion engines and electric turbines, hydrogen is poised to become a cornerstone of global financial management in the current century. By examining and understanding hydrogen energy, realize that transitioning to a hydrogen-based economy will require an efficient, safe, and high-capacity storage system. This is why the most attractive hydrogen storage system globally is the underground storage system (USS), especially within depleted oil and gas reservoirs. Due to the unique features of hydrogen, such as high reactivity, slow kinetics, and the challenge of hydrogen adsorption/desorption temperatures, hydrogen storage faces numerous challenges. Therefore, in this study, a comprehensive review of the individual features of H₂, hydrogen storage systems, and other influencing factors has been conducted. By accurately identifying existing mechanisms, capacities, and barriers, this study aims to inspire further research and contribute to the progress of the hydrogen economy. Additionally, this study presents, for the first time, a thorough review of H₂ sources and hydrogen storage mechanisms, providing a comprehensive overview of all critical stages of this industry.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 501-528"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120821","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":"Influence of solvent-to-oil mass ratios on high-pressure asphaltene precipitation","authors":"Aly ElMasry ,&nbsp;Hamed Rahnema ,&nbsp;Milad Rahnema","doi":"10.1016/j.ptlrs.2025.03.005","DOIUrl":"10.1016/j.ptlrs.2025.03.005","url":null,"abstract":"<div><div>Asphaltene precipitation during solvent-based enhanced oil recovery under reservoir conditions impedes production efficiency and degrades oil quality. This study aims to optimize solvent-to-oil mass ratios to mitigate asphaltene issues and enhance oil upgrading. Experiments using a high-pressure cell simulating reservoir environments were conducted with solvent-to-oil ratios of 3:1, 5:1, 7:1, and 9:1 at temperatures of 120 °C and 250 °C. Increasing the ratio from 3:1 to 7:1 significantly enhanced in-situ asphaltene precipitation, but further increase to 9:1 offered minimal additional benefit, indicating a plateau. Concurrently, the asphaltene content in upgraded oil decreased with higher ratios, stabilizing beyond 7:1. At 250 °C, a substantial reduction in total asphaltene content—averaging a 5.8 wt% decrease-was observed. The discovery of the plateau at 7:1 and the reduced asphaltene precipitation at elevated temperatures provides a novel perspective on balancing solvent use with operational efficiency. These findings contribute to cost-effective and environmentally sustainable practices in enhanced oil recovery operations. These findings identify an optimal solvent-to-oil ratio and temperature under reservoir conditions for maximizing asphaltene precipitation and minimizing asphaltene content in upgraded oil. Optimizing these parameters is crucial for effective asphaltene management and improving the efficiency of solvent-based enhanced oil recovery processes.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 537-542"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120660","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 intelligent optimization method for drilling parameters of extended reach wells based on mechanical specific energy and machine learning","authors":"Xuyue Chen,&nbsp;Rong Wang,&nbsp;Jin Yang,&nbsp;Deli Gao,&nbsp;Gengchen Li,&nbsp;Pengbo Li","doi":"10.1016/j.ptlrs.2025.03.002","DOIUrl":"10.1016/j.ptlrs.2025.03.002","url":null,"abstract":"<div><div>Extended reach wells (ERWs) can efficiently develop offshore satellite oilfields, reduce development costs and improve economic benefits. However, owing to the complex geological conditions, it is difficult to determine the drilling parameters of extended reach drilling, which greatly restricts the rate of penetration (ROP) and increases the cost of drilling operations. In this paper, a new intelligent optimization method for drilling parameters of ERWs based on mechanical specific energy (MSE) and machine learning is proposed. Unlike conventional approaches, this method combines an ensemble regression (ER) model for predicting ROP with the non-dominated sorting genetic algorithm-II (NSGA-II) to optimize multiple objectives, including MSE, ROP, and unit footage cost (UFC). The results show that through the intelligent optimization of drilling parameters for extended reach drilling wells in Block M of Bohai Oilfield, the two decision variables of the weight on bit (WOB) and rotations per minute (RPM) are increased, MSE is constantly converging or even equal to the confined compressive strength (CCS) of the rock, UFC is reduced by nearly 51.57%, and ROP is increased by approximately 31.88%. The findings demonstrate the effectiveness of the approach in enhancing drilling efficiency and reducing operational costs, offering an innovative solution for the optimization of drilling parameters in ERWs.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 485-500"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120677","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":"Investigation on phase behavior of shale condensate gas under multi-interface effect","authors":"Chuangtao Niu ,&nbsp;Tianjie Huang ,&nbsp;Chen Li ,&nbsp;Yuan Zhang ,&nbsp;Jinghong Hu","doi":"10.1016/j.ptlrs.2025.02.006","DOIUrl":"10.1016/j.ptlrs.2025.02.006","url":null,"abstract":"<div><div>Shale condensate reservoirs, as a significant unconventional resource, have been gaining increasing interest in recent times. Researchers have developed a variety of models to analyze interfacial effects in nanopores, including capillary condensation, capillarity, and adsorption effects. However, there are few studies on these interface effects. Therefore, we developed a phase equilibrium model considering the multi-interface effects in nanopores. The model is first built by modifying the Peng Robinson-equation of state (PR-EOS). The gas adsorption in vacant solution (FHVSM) model is utilized to describe adsorption. The calculated results show good agreements with experimental data of this model are more consistent with the adsorption characteristics of mixed gases in the porous media. After that, the phase behavior of a typical shale condensate gas is analyzed. Results indicate that the multi-interface effects will result in incremental dew-point pressure and retrograde condensate saturation. Moreover, the injection of CO₂ and N₂ was also studied, illustrating that CO₂ reduces the dew-point pressure, while N₂ increases the dew-point pressure. Both CO₂ and N₂ reduce the retrograde condensate saturation. Finally, the change in the adsorption of mixed gases was also evaluated, which shows a decreasing trend as the reservoir pressure depleted. This work provides deeper understandings in the phase behavior of hydrocarbons in the shale condensate gas reservoirs.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 529-536"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120662","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":"Influence of stress sensitivity on pore structure of tight reservoirs: A Digital core based analysis","authors":"Hong He ,&nbsp;Xuefei Yang ,&nbsp;Yuexiang Hao ,&nbsp;Yizhen Li ,&nbsp;Benqiang Wang ,&nbsp;Yi Liu ,&nbsp;Yuanlin Wang","doi":"10.1016/j.ptlrs.2025.02.008","DOIUrl":"10.1016/j.ptlrs.2025.02.008","url":null,"abstract":"<div><div>During the development of tight reservoirs, as the formation pressure decreases, the effective stress on the rock matrix increases. This leads to rock deformation and, consequently, changes in the physical parameters of the reservoirs, affecting reservoir productivity. Therefore, it is crucial to identify the influence of stress variation on the pore structure of tight reservoirs at the pore scale. Based on 3D grayscale images of representative samples under different confining pressures using micrometer computed tomography, this study obtained corresponding 3D digital cores through binary segmentation using the maximum class spacing algorithm. Based on digital cores with the same physical size under different confining pressures, the binary data volume was subtracted using a Boolean algorithm to obtain the pore variation space under different confining pressures. The pore variation and permeability damage rate under different confining pressures were then determined. Pore network models of digital cores under different confining pressures were extracted using the maximal ball algorithm, and the corresponding pore-throat radius distribution, coordination number distribution, length/diameter ratio, and shape factor distribution were calculated. The results show that as the confining pressure increases, the pore-throat distribution curve shifts to the direction of smaller pore-throats, the average coordination number decreases, and the throat length/diameter ratio distribution curve and shape factor distribution curve shift to the direction of larger pore-throats. This is because compaction reduces pores and throats, decreases the overall pore-throat connectivity, narrows the throats, and makes the cross-sections of the pore-throats more circular. This research serves as a basic platform for efficient development under stress sensitivity in tight reservoirs, and its findings have important academic significance and practical application value.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 659-666"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120708","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 the performance of reservoirs depleted by long horizontal wellbores with closed sections","authors":"Salam Al-Rbeawi ,&nbsp;Jalal Farhan Owayed","doi":"10.1016/j.ptlrs.2025.02.004","DOIUrl":"10.1016/j.ptlrs.2025.02.004","url":null,"abstract":"&lt;div&gt;&lt;div&gt;This paper introduces a new approach for reservoir performance where long horizontal wellbores are extended in the porous media with the existence of closed sections. It focuses on the impact of these sections on the pressure behavior, flow regimes, and productivity index considering different characteristics for the closed sections in terms of the length and petrophysical properties. The methodology used in this approach includes different tasks. The first is developing analytical models for the pressure drop caused by the production at a constant sandface flow rate from a horizontal wellbore where a part of it is closed. These models are developed based on the fact that the porous media with the existence of the closed sections in the horizontal wellbores consists of three regions. The first represents the porous media in the vicinity of the open section of the wellbore and extends to a distance equal to half the formation thickness while the second is the porous media of the open section that extends beyond the first region and reaches the reservoir boundary. The third region represents the porous media of the closed sections that extend from the wellbore to the reservoir boundary. In the second task, the proposed models are solved for different reservoir configurations, wellbore lengths, and closed and open section characteristics. The impact of closed sections on transient and stabilized pseudo-steady state productivity indices are demonstrated in third tacks while the analytical models of the observed flow regimes in the porous media are presented in the fourth task with a major focus given to those impacted by the closed sections. The outcomes of this study can be summarized in the following points: 1) The pressure behavior, flow regimes, and productivity index are significantly influenced by the existence of closed sections. This influence is significant during early production time, but it decreases during intermediate production, however, it is not seen at late production time. 2) The impact of closed sections becomes more severe when the petrophysical properties of the closed sections are greatly different from those of open sections. 3) The pressure behavior of early production time is not affected by the petrophysical properties of the closed section porous media while pseudo-steady state flow is significantly impacted by these properties. 4) The pressure and pressure derivative behaviors of long horizontal wellbores with long closed sections are similar to those developed in reservoirs depleted by hydraulic fractures. 5) Reaching pseudo-steady state flow may need a longer time when there is a great difference in the petrophysical properties between closed and open sections, however, the length of the closed sections may not have such impact. The novel point that has reached in this study is observing a new bi-linear flow regime instead of a linear flow regime. This flow regime represents a simultaneous linear flow from the","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 602-621"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120658","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 comparative experimental study on the prediction of renewable oils properties using RGB and HSV image processing techniques","authors":"Aditya Kolakoti ,&nbsp;Ruthvik Chandramouli","doi":"10.1016/j.ptlrs.2025.02.009","DOIUrl":"10.1016/j.ptlrs.2025.02.009","url":null,"abstract":"<div><div>In this study, renewable oil properties of Flash Point (⁰C), Fire Point (⁰C), Density (kg/m³), Cloud Point (⁰C), Pour Point (⁰C), and Viscosity (cST) are predicted using image processing techniques of Red Green Blue (RGB) and Hue Saturation Value (HSV). Eleven types of renewable oils are chosen for experimentation, and their surface images are captured with a high-resolution digital camera. For better accuracy, around 150 surface images are captured for each oil sample, and their average pixel data is extracted using RGB and HSV techniques. The digital pixel information (metadata) of all the oil samples is mapped to their experimental oil properties, and the accuracy of the developed metadata is validated with Fiji software due to its better image analysis and also complex data quantifying capabilities. The minimum, maximum, mean, mode and standard deviation results of RGB and HSV agree with Fiji. In addition, the developed dataset has been validated with Neural Network classification and TreeBagger algorithms. The results of TreeBagger reveal that the trained dataset is highly accurate (91.9% for RGB and 95.3% for HSV). Similarly, 95.6% (RGB) and 97.3% (HSV) accuracy is achieved for Neural Network classification. Finally, two new oil surface images are trained using the developed dataset. Both RGB and HSV accurately predict the oil properties. Therefore, it is evident that predicting the significant oil properties helps optimize the production process by reducing experimental costs and time.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 622-635"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120706","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}