Petroleum Research最新文献

{"title":"Understanding pore characteristics through core-based petrographic and petrophysical analysis in a heterogeneous carbonate reservoir: A case study from the Mumbai Offshore Basin, India","authors":"Ilius Mondal,&nbsp;Kumar Hemant Singh","doi":"10.1016/j.ptlrs.2023.04.001","DOIUrl":"10.1016/j.ptlrs.2023.04.001","url":null,"abstract":"<div><p>Carbonate rocks exhibit complex and heterogeneous pore structures; such heterogeneity is manifested by the occurrence of a wide variety of pore types with different sizes and geometries as a result of depositional and diagenetic processes. These complications substantially increase the uncertainty of predicted rock hydraulic parameters because samples with comparable porosities might have very different permeability values. In this study, small-scale characterisation of porosity and permeability in heterogeneous Eocene limestone samples from the Bassein Formation of the B-X structure of the MK Field in Mumbai Offshore Basin, India, was carried out, employing an integrated framework that incorporates thin-section petrography, routine core analysis, mercury injection capillary pressure and nuclear magnetic resonance data. The pore characteristics of these carbonates range from poor to excellent. The studied samples exhibited large ranges of porosity, permeability and other associated petrophysical attributes. The pore types, as well as their orientations and connectivity, are the primary factors causing the heterogeneity. Because of the complexity of the pore networks, a simple lithofacies classification alone would have been insufficient to link porosity and permeability. The reservoir characteristics in the study area are strongly linked to the development and/or destruction of reservoir porosity–permeability during different phases of diagenesis. Twenty-four carbonate core samples from the limestone unit were studied and classified into microfacies and pore type classes, producing an accurate assessment of reservoir attributes. The comprehensive workflow incorporates the pore volume distributions and pore throat attributes for each rock type. Three carbonate microfacies were identified by petrographic analysis and their petrophysical characteristics, such as porosity, permeability, pore throat size, pore volume and fluid flow factors, were measured. The study demonstrates how macroporosity, mesoporosity and microporosity are associated with various rock types and how they affect permeability and cementation exponents. The results of this study provide a comprehensive experimental framework for geological and geophysical interpretation that can be applied to identify potential reservoir facies and strengthen our understanding of heterogeneous carbonates. The framework can also be used to guide reservoir evaluation of similar heterogeneous formations in other areas.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 469-480"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000182/pdfft?md5=82202cb3f5759abb218ffcdadfe2d531&pid=1-s2.0-S2096249523000182-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44948564","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":"Rheology and lubricity characteristics study at different temperatures using synthesized SnO2 nanoparticles in KCl free bentonite water base mud","authors":"A.B.M. Ariful Bari Khandaker ,&nbsp;Nayem Ahmed ,&nbsp;Md Saiful Alam","doi":"10.1016/j.ptlrs.2023.03.003","DOIUrl":"10.1016/j.ptlrs.2023.03.003","url":null,"abstract":"<div><p>Drilling mud is a major concerning element due to its high operational and economic impact on the drilling process. Various additives are introduced to enhance the efficiency of drilling fluid, but none of them could perfectly achieve their proposed efficacy in drilling operations. Researchers conceived several nanoparticles (NPs) in drilling fluid to dissolve this issue. In a singular instance, commercial tin oxide (SnO₂) nanoparticles were utilized to analyze the influence of NPs on the rheological and filtration properties of inorganic KCl salt-based drilling fluid. However, the effect of SnO₂ NPs on mud lubricity characteristics is not studied previously. However, due to the hazardous behavior of KCl, its use is very limited. Thus, we consider a KCl-free bentonite water-based mud to avoid any environmental damages from drilling operations. We also use SnO₂ NPs that is synthesized in our laboratory by co-precipitation method. In addition to rheological and filtration properties, we also investigate the effect of NPs on mud's lubricity that was not considered in the previous study. Drilling fluid properties are measured at five different NPs concentrations of 0.10, 0.25, 0.50, 0.75 &amp; 1.0 wt%, and at six different temperatures of 30, 40, 50, 60, 70, and 80 °C, while filtration properties are measured using API low-pressure low temperature (LPLT) condition. The addition of 0.1 wt% SnO₂ NPs increases plastic viscosity, yield point, 10 s gel strength, and 10 min gel strength by 10%, 63%, 20%, and 14%, respectively. The maximum reduction in lubricity coefficient is found to be 14% at NPs concentration of 1.0 wt%. The NPs concentration of 0.5 wt% yielded a reduction in fluid loss and mud cake thickness by 8.1% and 34%, respectively. The study suggests that SnO₂ NPs can be employed as an additive to improve the rheology, lubricity, and filtration properties of KCl-free bentonite water-based drilling mud.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 541-549"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000169/pdfft?md5=24b8b9380e7731bd858949b9ab5c41ea&pid=1-s2.0-S2096249523000169-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"54962249","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":"Combining indicators analysis and chemometrics to trace the geographical origin of crude oil","authors":"Tong Li,&nbsp;Detian Yan,&nbsp;Wenjie Liang,&nbsp;Xiaosong Wei","doi":"10.1016/j.ptlrs.2023.05.001","DOIUrl":"https://doi.org/10.1016/j.ptlrs.2023.05.001","url":null,"abstract":"<div><p>Geographic traceability is crucial to global oil trade security. This study discusses the possibility of using multivariate statistical methods combined with multi-indicator analysis to identify samples of crude oil imports from five major countries to China. The physicochemical properties and trace elements of crude oil were detected by Petroleum product standards and inductively coupled plasma atomic emission spectrometry (ICP-AES). Eight indexes (moisture, density, sulfur content, acid value, organochlorine, carbon residual, V, and Ni) were analyzed. Principal component analysis (PCA), hierarchical clustering analysis (HCA), Orthogonal projections to lateen structures-discriminant analysis (OPLS-DA), and other multivariate data analysis methods were used to determine the geographical origin of crude oil samples. Satisfying results have been obtained using PCA to reduce the dimensions of the indicators of crude oil from different origins. It allows the reduction of 8 variables to 3 principal components and accounts for 80.06% of the total variance. The HCA shows five clusters corresponding to five sources of crude oil. This will help to improve the utilization rate of crude oil with different characteristics, improve the quality of crude oil trade, and ensure the high quality of crude oil trade. For the sample set used for modeling, the model's accuracy was 97.19% after OPLS-DA optimization. These results show that the combination of multi-index analysis and stoichiometry is an effective tool for identifying crude oil origin, which fills the technical gap in the rapid identification of crude oil origin.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 524-530"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000200/pdfft?md5=a742d26475649bb8de0d532a13c100ab&pid=1-s2.0-S2096249523000200-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138656126","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":"Thermal oil recovery factors from sandpacks of variable mineralogy","authors":"Viacheslau Y. Kudrashou ,&nbsp;Hisham A. Nasr-El-Din","doi":"10.1016/j.ptlrs.2023.06.002","DOIUrl":"10.1016/j.ptlrs.2023.06.002","url":null,"abstract":"<div><p>Steam injection is commonly used for production of viscous crude oil. Reservoir rock often contains clay minerals. Reactive nature of steam and clay minerals may lead to formation damage. This work investigates oil recovery and changes in petrophysical properties as a function of the mineralogy. Sandpacks with quartz, calcite, feldspar, kaolinite, smectite, and illite were prepared for steam injection experiments. Permeability of the steamed sandpacks was determined using coreflood experiments. Chemical composition of the produced aqueous samples was determined using ICP-OES (inductively coupled plasma-optical emission spectroscopy). Morphology of the rock samples was studied using SEM-EDS (scanning electron microscope-energy dispersive X-ray spectroscopy). Mineralogy and elemental content of the solid samples were determined using XRD (X-ray diffraction) analysis and XRF (X-ray fluorescence) respectively. It was found that aqueous phase samples produced from clay-rich sandpacks tend to have higher pH than samples produced from samples without clay minerals. Oil recovery factors for 100% quartz case was determined to be 65 wt%. Calcite- and feldspar-rich sandpacks produced 56 and 61 wt% of oil respectively. Sandpacks with clay fractions have shown the lowest oil recovery – 39, 29, and 28 wt% for kaolinite-, smectite-, and illite-rich samples respectively. Mineral dissolution and precipitation were the dominant damaging mechanism for quartz and calcite cases. Feldspar-rich sandpack demonstrated signs of structural destruction of the mineral and fines release. Kaolinite's effect on oil recovery was found to be associated with fines migration. Smectite hydration and swelling in presence of steam was the dominant formation damage effect on the oil production. Steam interaction with illite-rich sandpack caused formation of amorphous silica. This paper presents oil recovery factors as a function of injected pore volume (PV) of steam for sandpacks of different mineralogy. Obtained results characterize petrophysical changes caused by steam interaction with minerals in presence of oil. This data provides insights into effects of steam on minerals with different structures and properties.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 481-489"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000479/pdfft?md5=31dba2f37a4fb1bd4a65abad11fbb5c6&pid=1-s2.0-S2096249523000479-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47021609","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":"Optimal performance of water-oil axial jet pump in an egyptian offshore oil field","authors":"A.A.A. Sheha ,&nbsp;K.A. Ibrahim ,&nbsp;H.A. Abdalla ,&nbsp;I.M. Sakr ,&nbsp;Samy M. El-Behery","doi":"10.1016/j.ptlrs.2023.07.002","DOIUrl":"10.1016/j.ptlrs.2023.07.002","url":null,"abstract":"<div><p>The jet pump is an artificial lift employed when the reservoir pressure declines and the well deviation increases. The use of computer well models for optimizing the oil well output has proven to be a successful strategy, and has helped increasing the efficiency and production of numerous wells. The objective of this study was to use a production optimization technique that achieves some improvements, and recommend approaches toward increasing the oil well production. The effects of the motive fluid flow rate and pressure on the oil production rate were investigated to determine the optimal injection rate and pressure on the performance of the deep well water-oil axial jet-pump. Additionally, the effects of the well-head pressure, water cut, and roughness of tubing on oil production of this jet pump type were investigated. The results revealed that the impact on the oil lift performance is significant. The oil production increased by 19.43%, and the optimal economic value for the injection rate and pressure for the GA-1A well are 744.44 BFPD and 2722.22 psig, respectively. In summary, increasing the tubing roughness decreased the well's total liquid production. Thus, maintaining the well integrity is a very important factor because not doing so can lower the productivity by up to 20%–25%.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 561-571"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000492/pdfft?md5=5479c80360064c11e003055a014be651&pid=1-s2.0-S2096249523000492-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48502509","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":"Numerical analysis and experimental research on detection of welding defects in pipelines based on magnetic flux leakage","authors":"Changsheng Zhang ,&nbsp;Jinpeng Bi ,&nbsp;Yuexia Lv ,&nbsp;Mengli Li ,&nbsp;Yongying Qi ,&nbsp;Kai Zhou ,&nbsp;Ming Zhang ,&nbsp;Tingting Du","doi":"10.1016/j.ptlrs.2023.05.013","DOIUrl":"10.1016/j.ptlrs.2023.05.013","url":null,"abstract":"<div><p>Regular inspection of long-distance oil and gas pipelines plays an important role in ensuring the safe transportation of oil and gas, and inspection on welding defects is an important part of the inspection process. Magnetic flux leakage (MFL) is an electromagnetic non-destructive testing technique which has been commonly utilized to detect welding defects in pipelines. In the present study, Maxwell electromagnetic simulation software was used to carry out numerical study on the welding defects in pipelines, including incomplete penetration and undercut. The Ф406 pipeline with a wall thickness of 7 mm was selected as the study case to establish the numerical model. Setting the life-off value at 1 mm, the distribution of magnetic leakage field was investigated for pipeline without defect, pipeline with incomplete penetration defect and pipeline with undercut defect respectively, the characteristic values describing the depth and width of defects were found. Furthermore, quantified equations which can be used to describe the defect depth were proposed. Finally, experimental research was carried out to validate the effectiveness of the numerical model, and the experimental results showed good consistence with the numerical calculation results. The research results indicate that, it is technically feasible and reliable to diagnose the incomplete penetration and undercut welding defects in pipelines using MFL.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 550-560"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000339/pdfft?md5=fbe57e11c6cbf1bf0e60a1c3853c1141&pid=1-s2.0-S2096249523000339-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48562019","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":"Comparative studies on numerical sensitivity of different scenarios of enhanced oil recovery by water-alternating-gas (CO2) injection","authors":"Saddam Mohammed Mohammed Nasser,&nbsp;Achinta Bera,&nbsp;Vivek Ramalingam","doi":"10.1016/j.ptlrs.2023.07.001","DOIUrl":"10.1016/j.ptlrs.2023.07.001","url":null,"abstract":"<div><p>Enhanced oil recovery by CO₂ injection technology (CO₂-EOR) plays a crucial role in enhancing oil production and the permanent sequestration of anthropogenic CO₂ in depleted oil reservoirs. However, the availability of CO₂ in oil field locations and its mobility in contrast with reservoir fluids are prime challenges in CO₂-EOR. The cost of CO₂ and its availability at the oil fields has prompted investigations on efficient injection of CO₂ at the fields to achieve the best sweep efficiency possible. Injection strategies such as water-alternating-gas (WAG), simultaneous vertical and horizontal WAG, simultaneous water injection into the aquifer and vertical WAG, water and gas injection simultaneously but separately (SS-WAG), and water and gas injection simultaneously but not separately (SNS-WAG) play a significant role, as well as the purity of CO₂. In this work, the significance of the above criteria was investigated individually and in combination. The coupled sequence of injection rate, soaking time, WAG ratio, and purity of injected CO₂ for enhancement of oil production were delineated. A realistic reservoir simulation model conceptualizing the CO₂-EOR system with five spot injection patterns was developed by the company CMG. The history-matched model that was developed was used to investigate the sensitivity of the coupled effects to the criteria listed above on oil recovery. Numerical investigations quantitatively emphasized that purity and soaking time of CO₂ have an inverse effect in the oil production rate and that SNS-WAG resulted in a better oil production rate than SS-WAG.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 505-513"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000480/pdfft?md5=3b50b142b056f702fb6dac0586c41d1e&pid=1-s2.0-S2096249523000480-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46035388","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":"Sequence stratigraphic evaluation for the Abu Madi Formation, Abu Madi/El Qar'a/Khilala gas fields, onshore Nile Delta, Egypt","authors":"Farouk I. Metwalli ,&nbsp;Amir Ismail ,&nbsp;M.S. Metwally ,&nbsp;Ibrahim M. El Shafei","doi":"10.1016/j.ptlrs.2023.04.002","DOIUrl":"10.1016/j.ptlrs.2023.04.002","url":null,"abstract":"<div><p>The present study aims to integrate a large set of geological and geophysical data into a comprehensive model describing the depositional features of the Abu Madi/El Qar'a/Khilala gas fields. The model is based on the sequence stratigraphic framework of the Abu Madi Formation defined using cores, well logs, and time-migrated seismic data. Seismic trace attribute sections and relative acoustic impedance sections are also used. A possible depositional pattern for the main Level III is established, based on the lithological and petrophysical information derived from the seismic data analysis. The Abu Madi Formation can be regarded as a depositional sequence recording the progressive drowning of the incised valley. The sequence is bounded at the base by an erosional unconformity, created by a drop in the level of the Late Messinian Sea, and at the top by a drowning unconformity related to the Early Pliocene transgression. The bottom of Level II divides the Abu Madi sequence into two smaller sequences. In both sequences, gas-bearing traps can be found in the Lowstand Systems Tracts, represented by the fluvial Level III and fluvial-deltaic Level II, respectively.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 4","pages":"Pages 514-523"},"PeriodicalIF":0.0,"publicationDate":"2023-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000194/pdfft?md5=19cd7295a6f3ecece45b9b4193bef9e7&pid=1-s2.0-S2096249523000194-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134934268","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":"Coupled tripartite investigation of breaker fluid invasion and impact on hydrocarbon recovery in sandstone reservoirs","authors":"Stella I. Eyitayo ,&nbsp;Kazeem A. Lawal ,&nbsp;Marshall C. Watson ,&nbsp;Oladoyin Kolawole ,&nbsp;Ibrahim Abdullahi ,&nbsp;Asekhame U. Yadua ,&nbsp;Oluchukwu M. Okoh ,&nbsp;Saka Matemilola ,&nbsp;Tunde Alabi","doi":"10.1016/j.ptlrs.2022.11.002","DOIUrl":"10.1016/j.ptlrs.2022.11.002","url":null,"abstract":"<div><p>Breaker fluids are designed to dissolve filter cakes by breaking their long-chain molecules, thereby removing solid deposits on the wellbore wall. Although breaker fluids are not intended to infiltrate the hydrocarbon reservoir, they can invade and cause formation damage by altering sandstone reservoirs' wettability and relative permeability. This can lead to a reduction in the overall reservoir performance. This study coupled tripartite methods to investigate the potential impact of breaker invasion and transport in hydrocarbon reservoirs and its multiscale effect on the performances of sandstone reservoirs. We utilized experimental, analytical, and numerical methods to assess and predict the susceptibility of reservoirs to breaker fluid invasion and transportation. Our experimental and empirical investigations considered varying breaker fluid formulations to evaluate the effects of breaker fluid concentration, formation temperature, and solution gas-oil ratio (GOR) on residual-oil saturation (ROS) and oil-water relative permeability. By adopting the ROS and relative permeability associated with the 50% v/v breaker fluid mixture, the performance of the hydrocarbon reservoir was numerically simulated under the limiting scenarios of no-invasion, moderate-invasion, and deep-invasion of breaker fluid. The results indicate a positive correlation between breaker fluid concentration and ROS, highlighting the risks that breaker fluid invasion and deep infiltration pose to hydrocarbon recovery. Further, results show that both live-oil condition (LOC) and dead-oil condition (DOC) reservoirs are susceptible to the detrimental impacts of breaker fluid infiltration, while their invasion can reduce hydrocarbon recovery in both LOC (−6%) and DOC (−28%). The multi-scale effects on reservoir performance are more pronounced at near-wellbore and DOC than at far-field and LOC. Findings from this work provide valuable insights into the complexity of breaker-fluid invasion in sandstone reservoirs and the mitigation of associated risks to reservoir performance.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 338-349"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49390914","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":"Data driven prediction of oil reservoir fluid properties","authors":"Kazem Monfaredi,&nbsp;Sobhan Hatami,&nbsp;Amirsalar manouchehri,&nbsp;Behnam Sedaee","doi":"10.1016/j.ptlrs.2022.10.001","DOIUrl":"10.1016/j.ptlrs.2022.10.001","url":null,"abstract":"<div><p>Accuracy of the fluid property data plays an absolutely pivotal role in the reservoir computational processes. Reliable data can be obtained through various experimental methods, but these methods are very expensive and time consuming. Alternative methods are numerical models. These methods used measured experimental data to develop a representative model for predicting desired parameters. In this study, to predict saturation pressure, oil formation volume factor, and solution gas oil ratio, several Artificial Intelligent (AI) models were developed. 582 reported data sets were used as data bank that covers a wide range of fluid properties. Accuracy and reliability of the model was examined by some statistical parameters such as correlation coefficient (R²), average absolute relative deviation (AARD), and root mean square error (RMSE). The results illustrated good accordance between predicted data and target values. The model was also compared with previous works and developed empirical correlations which indicated that it is more reliable than all compared models and correlations. At the end, relevancy factor was calculated for each input parameters to illustrate the impact of different parameters on the predicted values. Relevancy factor showed that in these models, solution gas oil ratio has greatest impact on both saturation pressure and oil formation volume factor. In the other hand, saturation pressure has greatest effect on solution gas oil ratio.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 424-432"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48209818","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}