Petroleum Research最新文献

{"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}

{"title":"Morphometry, bathymetry, gravity analyses and active tectonics of the petroliferous Gulf of Mannar in the Indian sector","authors":"Kutubuddin Ansari ,&nbsp;Mery Biswas ,&nbsp;Adrija Raha ,&nbsp;M.L. Shilpashree ,&nbsp;Soumyajit Mukherjee","doi":"10.1016/j.ptlrs.2025.03.003","DOIUrl":"10.1016/j.ptlrs.2025.03.003","url":null,"abstract":"<div><div>The Gulf of Mannar has been producing natural gas in the Sri Lankan portion. This indicates that a detail geoscientific study is to be undertaken from the Indian section of the gulf, which can have a far-reaching implication in the Indian petroleum geoscience. In this work, morphometric and gravity studies were made from the gulf/basin near the onshore area, and bathymetric studies from the offshore portion of the Mannar basin within the Indian sector. Five watersheds were delineated based on study of eight geomorphic parameters on remote sensing images form the onshore area. Out of these watersheds 4 and 5 are found to be presently tectonically most active. Well-bore stability issue is to be considered while drilling these portions in future. We further prepared a regional contour map for the offshore study area, analysed the free air gravity data from the onshore area, and deduced the First Vertical Derivative (FVD) and Tilt Derivative Ratio (TDR). Bathymetric height gradually increases along the north-south trend from the coast region of the study area towards the central region, while the gravity magnitudes display a very sharp gradient (around 150 mGal). The gravity anomaly shows positive values at continental shelf (0–160 mGal), which includes parts of watersheds 1 and 3 and attains negative magnitude (up to −20 mGal) towards the basin area. Negative gravity anomaly in the offshore area may indicate presence of hydrocarbon but more studies are needed for confirmation. Apparently, almost a negative correlation (except watershed 1) between surface elevation and free air gravity magnitudes has been found.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 667-678"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120661","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":"Achieving low-carbon future through CO2 storage: A comprehensive review of global projects and policies","authors":"Malik Muhammad Ali Awan ,&nbsp;Farzain Ud Din Kirmani","doi":"10.1016/j.ptlrs.2025.04.004","DOIUrl":"10.1016/j.ptlrs.2025.04.004","url":null,"abstract":"<div><div>Climate change mitigation efforts require innovative solutions to reduce GHG emissions. CCUS is a crucial technology for achieving a low-carbon economy. However, significant research gaps exist in understanding the intersection of CCUS policy and the United Nations' SDGs. This review article addresses these gaps by comprehensively analyzing CO₂ storage projects across six global regions, examining 53 notable CCUS projects, and assessing CCUS policies in 15 leading countries. The primary objectives of this study are to (1) analyze regional trends, challenges, and technological advancements in CO₂ storage projects across diverse geological formations; (2) investigate the integration of CCUS into national strategies across leading economies, including the US, Canada, Brazil, China, Japan, India, the UK, France, the Netherlands, Germany, Australia, KSA, the UAE, and Qatar. The integration of CCUS with renewable energy sources and BECCS is explored, emphasizing its potential to achieve harmful emissions and support net-zero ambitions. Future perspectives focus on advancing CCUS efficiency and economic viability through innovations in sorbents, membranes, and process optimizations. The findings demonstrate significant alignment between CCUS policies and SDG targets, emphasizing the importance of integrated approaches to achieve a low-carbon future. This review serves as a valuable resource for policymakers, researchers, and industry stakeholders involved in the development of CO₂ storage solutions, providing insights into future perspectives and opportunities for CCUS.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 636-658"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120707","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":"Machine learning approach for modelling and predicting interfacial tension and rheology of crude oil nanoemulsions stabilized by rhamnolipid biosurfactant","authors":"Andaç Batur Çolak ,&nbsp;Sagheer A. Onaizi","doi":"10.1016/j.ptlrs.2025.02.005","DOIUrl":"10.1016/j.ptlrs.2025.02.005","url":null,"abstract":"<div><div>Forecasting the properties of nanoemulsions without engaging in expensive and time-consuming experimental research can yield significant benefits across multiple applications. This study examines the capability of machine learning to precisely forecast the interfacial tension and viscosity of crude oil-water nanoemulsions stabilized by rhamnolipid biosurfactant. Four artificial neural network models were created and assessed for nanoemulsions composed of different concentrations of crude oil and biosurfactants. The performance evaluation of the artificial neural network models demonstrated mean squared error values below 2.26E-03 and coefficients of determination greater than 0.999, signifying exceptional predictive accuracy. The mean overall deviation for all models was determined to be around 0.004%, indicating a negligible divergence from experimental results. The findings indicate that the developed artificial neural network models can accurately and reliably predict interfacial tension and viscosity values, providing an efficient alternative to experimental methods, with potential applications in optimizing nanoemulsion formulations for industrial purposes.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 3","pages":"Pages 474-484"},"PeriodicalIF":4.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120678","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}