Petroleum Research最新文献

{"title":"Use of graphs to assess well safety in drilling projects and during operations by identification of available barrier elements and consolidation of barrier envelopes","authors":"","doi":"10.1016/j.ptlrs.2024.02.002","DOIUrl":"10.1016/j.ptlrs.2024.02.002","url":null,"abstract":"<div><p>Two independent barrier envelopes are the usual requirement used in most well operations to avoid catastrophic accidents. These are classified as primary – concerning preventing the occurrence of a kick, and secondary – concerning controlling the kick to avoid a blowout. Barrier envelopes consist of barrier elements, thus verifying the quality of these elements is fundamental. Barrier elements may be either redundant or mandatory, and these relationships are what constitute the barrier envelopes. In this work, we present a methodology to evaluate well safety by identifying existing barrier elements and barrier envelopes and mapping their relationships through the usage of graphs technique. This technique explicitly states the relationship between barriers and between them and envelopes. It enables a simpler visualization for well designers and allows the development of computer programs to control the safety and integrity of wells, both in the design phase and during drilling. 12 graphs are provided for a 4-phase well (conductor, surface, production, and drill-in), considering both the primary and secondary envelopes. Reasoning for constructing each graph is thoroughly provided. If these graphs are used, reliability values can then be assigned to each barrier element, which results in the reliability of entire barrier envelopes. This can be further extended to analyze the safety of each operation by applying the system to operational sequences and even comparing well designs.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000255/pdfft?md5=99ec4494e7d1c016bf43f10c75fdb671&pid=1-s2.0-S2096249524000255-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140084462","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Research on slim-hole drilling technology for shale gas geological survey in China","authors":"","doi":"10.1016/j.ptlrs.2024.03.006","DOIUrl":"10.1016/j.ptlrs.2024.03.006","url":null,"abstract":"<div><p>Over the last 10 years, the China Geological Survey has deployed 137 slim-hole shale gas geological exploration wells for coring entire wellbores. These wells are primarily located in new blocks and geological formations where neighboring well data are insufficient, beyond the scope of developed oil fields in China, or outside of oil and gas company mining-right areas. The drilling rig equipment, coring tools, and core drill bits of slim-hole shale gas drilling technology are different from those associated with traditional petroleum drilling. Many studies have been conducted on non-coring slim-hole drilling technology. This paper focuses on coring technology and drilling safety, summarizing a set of high-efficiency shale gas drilling equipment and technology systems based on geological drilling equipment and techniques (that can be used for solid mineral exploration). We report on: 1) an improved vertical shaft drilling rig adapted to shale gas well control safety; 2) high-efficiency core drilling techniques, focusing on coring tools, and techniques incorporating an inverted tower drilling tool combination, air circulation follow-through technology, and expanded casing technology; 3) research progress on high-efficiency core drill bits, including non-planar tooth polycrystalline diamond compact bits and impregnated diamond core bits, along with their application effects. This research provides substantial advances in drill-core technology and improvements in exploration efficiency. Moreover, it provides a reference frame for well structural design and selection of construction technology for shale gas exploration drilling projects.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000322/pdfft?md5=644a46f277292c005d866fc0c42b587d&pid=1-s2.0-S2096249524000322-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140400036","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Empirical study of magnetohydrodynamic effect on fluid flow in clayey porous media","authors":"","doi":"10.1016/j.ptlrs.2024.03.010","DOIUrl":"10.1016/j.ptlrs.2024.03.010","url":null,"abstract":"<div><p>Enhancing oil recovery from clayey reservoirs is a significant challenge in petroleum industry due to complex interactions between fluids and rock surfaces, particularly clay swelling. This study presents the first empirical analysis of magnetic fields' impact on fluid flow in clayey porous media. Our core findings indicate that magnetic treatment of water increases oil recovery by an average of 15–30% in clayey media, with limited effectiveness in pure quartz media. Detailed experiments unraveled that improved recovery factor by magnetic treatment stem from both mitigated swelling and altered magnetic properties at clay surface; introducing 30% clay to porous medium decreased the recovery by 32% compared to pure quartz sand. Heating the clay to around 1000 °C to reduce its swelling property improved the recovery by only 16%, suggesting magnetic treatment is not solely attributed to clay swelling mitigation. Treating ferromagnetic films at clay surface with HCl to produce non-magnetic FeCl₃ resulted in a high recovery factor, similar to the clay-free medium. Moreover, it was determined that a magnetic field intensity of 43760–51740 A/m is optimal for fluid displacement in clayey media. Notably, the intensity of 47760 A/m increased recovery to 84.5% in a 30% clay medium, compared to 49.7% without treatment. Interestingly, it was observed that the maximum flow rate was associated with zero potential difference across the medium, providing a faster method to determine the optimum magnetic field intensity. Lastly, the concept of ‘Magnetic memory’ was investigated, referring to the persistence of magnetic field's influence after its removal. Our findings indicated that pressure build-up time stability lasted 10 days post-treatment, after which water behavior reverts, and clay swelling resumes. This insight into the temporal dynamics of magnetic field application provides a deeper understanding of its long-term impacts on fluid flow in clayey reservoirs.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000358/pdfft?md5=9de84d2e194b857775d50730214c4695&pid=1-s2.0-S2096249524000358-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140401132","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Harnessing deep transient testing for reservoir characterization and CO2 emission reduction in challenging geological settings","authors":"","doi":"10.1016/j.ptlrs.2024.01.014","DOIUrl":"10.1016/j.ptlrs.2024.01.014","url":null,"abstract":"<div><p>This paper provides a comprehensive overview of Deep Transient Testing (DTT), a cutting-edge technique for reservoir characterization that has revolutionized the oil and gas industry. The main aim of DTT is to characterize the reservoir with a deeper radius of investigation. The optimization of the radius of investigation with the DTT approach is studied in detail. Reveal is a commercial numerical simulation application used to simulate the DTT process and evaluate the pressure wave analysis in the porous media. The main aim of the simulation is to understand the impact of the reservoir quality on the pressure response and use it to address the noise-to-pule ratio, which is a determinantal parameter in testing duration. The tested wells with the DTT tool show that measured well productivity can deliver the minimum commercial rate. The has been delivered within 2 days compared to the potential test time of 21 days which saved the 19 rig days and contributed to CO2 emission reduction of (gas flaring 1340 + rig emission 600) 1940 Metric tons equivalent to 421 cars emission in a year. However, DTT also presents certain limitations, such as the requirement for specialized equipment and expertise, as well as the potential for formation damage during testing. This study provides a detailed description of the DTT technique, encompassing its history, theory, and practical applications. Furthermore, it discusses the benefits and limitations of DTT and presents case studies to illustrate its effectiveness across various reservoir types. Overall, this study serves as a valuable resource for reservoir engineers, geologists, and other professionals involved in the exploration and production of oil and gas.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000140/pdfft?md5=38d9766f99f359d5eb4728a8d7041478&pid=1-s2.0-S2096249524000140-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140523246","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A multi-mechanistic approach to the oil recovery study of a family of amphiphilic polysaccharides","authors":"Funsho Afolabi ,&nbsp;Syed M. Mahmood ,&nbsp;Lunech Mario ,&nbsp;Nur Asyraf Md Akhir ,&nbsp;Bennett Tackie-Otoo ,&nbsp;Hamid Sharifigaliuk","doi":"10.1016/j.ptlrs.2023.12.001","DOIUrl":"https://doi.org/10.1016/j.ptlrs.2023.12.001","url":null,"abstract":"<div><p>Chemical enhanced oil recovery (cEOR) remains one of the most potent tertiary recovery techniques. However, it is expensive and rarely environmentally friendly. Bio-based amphiphilic polymers have been suggested as an alternative to eradicating the challenges of conventional cEOR because of cost-effectiveness, and sustainability. Unfortunately, few in-depth studies exist in the literature to investigate the prospects of these materials. A new family of amphiphilic polysaccharides was synthesized by hydrophobic modification of cellulose sulphate, and the EOR functionalities were tested. The novel biopolymers exhibited the ability to alter rock wetting properties. In terms of recovery, one of the variants of the synthesized bio amphiphilic polymer (D-I) was able to reduce residual oil saturation to 12% at harsh conditions of 60,000 ppm salinity at 75 °C. Micromodel visual analysis revealed that the performance of the novel materials was due to the combination of mobility control, IFT lowering and emulsification, wettability alteration, and viscoelasticity. With a performance commensurate to that of a commercial hydrophobically modified polymer, it can be said that the novel amphiphilic polysaccharides can stand as a viable cEOR agent for oilfield applications.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000893/pdfft?md5=caa216e66c07749c33c7e8eb3e6adbe0&pid=1-s2.0-S2096249523000893-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141423105","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Identification of carbonate sedimentary facies from well logs with machine learning","authors":"Xianmu Hou ,&nbsp;Peiqing Lian ,&nbsp;Jiuyu Zhao ,&nbsp;Yun Zai ,&nbsp;Weiyao Zhu ,&nbsp;Fuyong Wang","doi":"10.1016/j.ptlrs.2024.01.007","DOIUrl":"10.1016/j.ptlrs.2024.01.007","url":null,"abstract":"<div><p>Sedimentary facies identification is critical for carbonate oil and gas reservoir development. The traditional method of sedimentary facies identification not only be affected by the engineer's experience but also takes a long time. Identifying carbonate sedimentary facies based on machine learning is the trend of future development and has the advantages of short time consuming and reliable results without engineers' subjective influence. Although many references reported the application of machine learning to identify lithofacies, but identifying sedimentary facies of carbonate reservoirs is much more challenging due to the complex sedimentary environment and tectonic movement. This paper compares the performance of the carbonate sedimentary facies identification using four different machine learning models, and the optimal machine learning with the highest prediction accuracy is recommended. First, the carbonate sedimentary facies are classified into the lagoon, shallow sea, shoal, fore-shoal, and inter-shoal five tags based on the well loggings. Then, five well log curves including spectral gamma ray (SGR), uranium-free gamma ray (CGR), photoelectric absorption cross-section index (PE), true formation resistivity (RT), shallow lateral resistivity (RS) are used as the input, and the manual identified carbonate sedimentary facies are used as the output of the machine learning model. The performance of four different machine learning algorithms, including support vector machine (SVM), deep neural network (<span>DNN</span>), long short-term memory (<span>LSTM</span>) network, and random forest (RF) are compared. The other two wells are used for model validation. The research results show that the RF method has the highest accuracy of sedimentary facies prediction, and the average prediction accuracy is 78.81%; the average accuracy of sedimentary facies prediction using SVM is 77.93%. The sedimentary facies predictions using DNN and LSTM are less satisfying compared with RF and SVM, and the average accuracy is 69.94% and 73.05%, respectively. The predicted carbonate sedimentary facies by LSTM are more continuous compared with other machine learning models. This study is helpful for identifying compelx sedimentary facies of carbonate reservoirs from well logs.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000073/pdfft?md5=4ecc1f769bf586c8fbae3c73c4a35aa9&pid=1-s2.0-S2096249524000073-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139538637","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Exploring the potential of drill cuttings for reservoir characterization: A case study from the Volga-Ural basin, Russia","authors":"Ibrahem Yousef,&nbsp;V.P. Morozov","doi":"10.1016/j.ptlrs.2024.01.012","DOIUrl":"10.1016/j.ptlrs.2024.01.012","url":null,"abstract":"<div><p>The research objectives are to assess the possibility of using drill cutting analysis to obtain information about the mineralogical and geochemical properties of the reservoir rocks. Drill cutting samples were collected from a vertical well that penetrated the Domanik sediments (Semiluksk Formation) in one of the oil fields in the Volga-Ural petroleum province. Thin sections from drill cuttings were examined using an optical polarizing microscope (Axio Imager A2). X-ray diffraction (XRD) analyses were performed using a Brucker D2 Phaser X-ray powder diffractometer. Thermophysical properties were studied using an STA 449 F3 Jupiter instrument. The pyrolytic studies were performed using the Rock-Eval method. Visual inspection showed that the studied sediments are alternations of carbonates and siliceous-carbonate rocks. Thin section examinations revealed that the carbonates are mainly limestone (mudstone and wackestone) and are characterized by a dense texture and up to 30 % organic residues. The siliceous-carbonate rocks are dominated by siliceous mudstones and are characterized by dark colours, layered structure, and an enrichment in organic matter. XRD analyses showed that the carbonate rocks are mainly composed of calcite, dolomite, quartz, feldspar, and mica, which are minor components. The siliceous-carbonate rocks are dominated by quartz, followed by calcite, although they also contain feldspars, mica, dolomite, and pyrite as impurities. According to the simultaneous thermal analysis, the average total hydrocarbon in the carbonate and siliceous-carbonate rocks is 13.6 % (for the core samples) and 11.5 % (for the drill cutting samples). The content of heavy hydrocarbons in the rocks is higher than the content of light hydrocarbons, indicating the immature nature of organic matter. Kerogen is found sporadically in siliceous-carbonate rocks. According to the pyrolytic studies, average S1 is 4.4 mg/g and average S2 is 19.8 mg/g (for the core samples); average S1 is 2.1 mg/g and average S2 is 17.8 mg/g (for the drill cutting samples), which indicated that the studied sediments have very good to excellent generation potential. The average <em>T</em>_<em>max</em> of 425.7 °C (for the drill cutting samples) and 427.9 °C (for the core samples) indicate immature organic matter that generated only heavy oils. Comparing the results of the analysed drill cutting samples with the results of the analysed core analysis from the same reservoir interval in the neighbouring wells showed a good correlation, which proves that this technique is a valid tool that provides an alternative, cost-effective method to determine the rock's characteristics from drill cuttings.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000127/pdfft?md5=d708ca679302a7496309c9e1204ac5e7&pid=1-s2.0-S2096249524000127-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140520919","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Development of bismuth-based solutions for well plugging and abandonment: A review","authors":"Lewaa Hmadeh,&nbsp;Marcelo Anunciação Jaculli,&nbsp;Behzad Elahifar,&nbsp;Sigbjørn Sangesland","doi":"10.1016/j.ptlrs.2024.01.003","DOIUrl":"10.1016/j.ptlrs.2024.01.003","url":null,"abstract":"<div><p>Plugging and abandonment (P&amp;A) is a crucial step of the well life cycle. Regardless of how long one stretches the productive life of a well, P&amp;A operations will have to be carried out eventually. The current panorama of our industry includes many wells to be plugged and abandoned, with steep requirements to abide by both regulations and societal pressure. In this context, we must guarantee that no leakage occurs with an eternal perspective in mind. Cement has been the prime material for this task, but recent studies have indicated the potential of degradation over time – especially in corrosive environments – and the creation of leaking paths due to its shrinkage. This has opened up a path toward the usage of alternative materials. One of the emerging candidates is bismuth, a metal with the unique characteristic of expanding when solidified. Such a trait could improve the overall sealability of wellbores and especially during P&amp;A. This article discusses the current status of bismuth sealing technologies, introducing the basics of bismuth, the ongoing efforts to qualify it as a barrier material, its potential applications, and the challenges that still need to be overcome. The latest research indicates promising results in terms of its usage as a barrier element.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000036/pdfft?md5=2f8b22bcf397921390078ff8c7456667&pid=1-s2.0-S2096249524000036-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139636880","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Corrosion testing of X52 and X80 steels immersed in stimulated emulsions using a real petroleum sample","authors":"L.M. Quej-Ake,&nbsp;J.L. Alamilla,&nbsp;A. Contreras","doi":"10.1016/j.ptlrs.2024.01.002","DOIUrl":"10.1016/j.ptlrs.2024.01.002","url":null,"abstract":"<div><p>The aim of this study is to evaluate the internal corrosion process on X52 and X80 steels/real petroleum interfaces containing condensed hydrocarbon plus oilfield-produced water, which were subjected to stimulated emulsions using 50/50 vol ratio mixtures at 45 °C, different hydrodynamic conditions, 1 h, and 24 h. A washing process by using deionized water was proposed to simulate and identify the corrosiveness of the hydrocarbon phase after 24 h of exposure time. The characterization by electrochemical impedance spectroscopy and the monitoring of the polarization curves indicated that X80 steel/oilfield-produced water interfaces were more susceptible to corrosion than X52 steel exposed to oilfield-produced water. The combined speed rotation of 600 rpm using a magnetic stirrer + 600 rpm using a rotating disk electrode decreased the corrosion rate on X52 steel. The stimulated emulsions made of hydrocarbon + oilfield-produced water and hydrocarbon + deionized water at 24 h increased the corrosion rate on X80 steel (0.34 mm/year and 0.43 mm/year, respectively), promoting the formation of erosion and pitting corrosion. These types of corrosion depended mainly on the physicochemical properties of the hydrocarbon, oilfield-produced water, exposure times, and hydrodynamic systems in which the hydrocarbon was studied.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000024/pdfft?md5=50dab8f7d69571753a875691db537421&pid=1-s2.0-S2096249524000024-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139540798","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Predicting density log from well log using machine learning techniques and heuristic optimization algorithm: A comparative study","authors":"Mehdi Rahmati ,&nbsp;Ghasem Zargar ,&nbsp;Abbas Ayatizadeh Tanha","doi":"10.1016/j.ptlrs.2024.01.008","DOIUrl":"10.1016/j.ptlrs.2024.01.008","url":null,"abstract":"<div><p>In the petroleum industry, the analysis of petrophysical parameters is critical for efficient reservoir management, production optimization, development strategies, and accurate hydrocarbon reserve estimations. Over recent years, the integration of machine learning methodologies has revolutionized the field, addressing challenges in geology, geophysics, and petroleum engineering, even when confronted with limited or imperfect data. This study focuses on the prediction of density logs, a pivotal factor in evaluating reservoir hydrocarbon volumes. It is important to note that during well logging operations, log data for specific depths of interest may be missing or incorrect, presenting a significant challenge. To tackle this issue, we employed the Adaptive Neuro-Fuzzy Inference System (ANFIS) and Artificial Neural Networks (ANN) in combination with advanced optimization algorithms, including Particle Swarm Optimization (PSO), Imperialist Competitive Algorithms (ICA), and Genetic Algorithms (GA). These methods exhibit promising performance in predicting density logs from gamma-ray, neutron, sonic, and photoelectric log data. Remarkably, our results highlight that the Genetic Algorithms-based Artificial Neural Network (GA-ANN) approach outperforms all other methods, achieving an impressive Mean Squared Error (MSE) of 0.0013. In comparison, ANFIS records an MSE of 0.0015, ICA-ANN 0.0090, PSO-ANN 0.0093, and ANN 0.0183.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000085/pdfft?md5=9c5236924d89719aebc109365066ee17&pid=1-s2.0-S2096249524000085-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140516300","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}