Petroleum Research最新文献

{"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}

{"title":"Pilot test of polymer microsphere alternate surfactant flood (PMAS) with mixtures of anionic-cationic surfactants under harsh conditions in a sandstone reservoir","authors":"Yingcheng Li ,&nbsp;Jun Jin ,&nbsp;Zhiqing Su ,&nbsp;Weidong Zhang ,&nbsp;Xinning Bao ,&nbsp;Baolun Niu ,&nbsp;Changhua Yang ,&nbsp;Xinyue Wu ,&nbsp;Xiaodong Zhai ,&nbsp;Li Zhang ,&nbsp;Rong Guo ,&nbsp;Yong Meng ,&nbsp;Xiujuan He ,&nbsp;Zhiqin Shen ,&nbsp;Hui Zhang ,&nbsp;Ou Sha","doi":"10.1016/j.ptlrs.2023.01.001","DOIUrl":"10.1016/j.ptlrs.2023.01.001","url":null,"abstract":"<div><p>The first pilot test of polyacrylamide microsphere alternate surfactant flood (PMAS) with mixtures of anionic-cationic surfactants (S_a/c) was carried out for a high-temperature, high-salinity, and high-hardness sandstone reservoir to demonstrate the potential of this novel technique to improve oil recovery. A critical micelle concentration (CMC) of 4.82 mg/L, an ultralow interfacial tension (IFT) of 8 × 10⁻⁴ mN/m, and a high oil solubilization of 22 were obtained. Static and dynamic adsorptions of S_a/c on natural core containing 15 wt% clay were reduced to about 2.20 and 0.30 mg/g-core, respectively, with the addition of adsorption inhibitor (AI). Since June 2014, the pilot test of PMAS was carried out in a Sinopec reservoir with a temperature of 87 °C, a salinity of 260,393 mg/L, and a hardness of 6,401 mg/L. Twelve cycles of alternative injection of 0.0125 PV S_a/c with a concentration of 0.1% and 0.0125 PV polyacrylamide microsphere with a concentration of 0.2% were conducted at an injection rate of 0.1 PV/yr, for a total of 0.3 PV chemical injection. As a result, the net daily oil production increased from 0 t to 6.5 t, and the water cut decreased from 96.3% to 93.8%, leading to an ultimate improved oil recovery of 6.3% original oil-in-place.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 291-300"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42840740","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":"Statistical distribution of geomechanical properties and ‘Sweet Spots’ identification in part of the upper Bakken","authors":"Nelson R.K. Tatsipie,&nbsp;James J. Sheng","doi":"10.1016/j.ptlrs.2022.10.005","DOIUrl":"10.1016/j.ptlrs.2022.10.005","url":null,"abstract":"<div><p>Completions and Reservoir Quality are two key attributes that are used to characterize nonconventional hydrocarbon assets. This is because, for optimum exploitation of these unconventional assets, horizontal wells need to be drilled in “Sweet Spots” (i.e., regions where Completions and Reservoir Quality are both superior). One way to quantify these qualities is to use reservoir and geomechanical properties. These properties can be estimated on a location basis from well logs, and then mapped over terrain using geostatistical modeling. This study presents a ‘Sweet Spots’ identification workflow based on three performance indexes (Storage Potential Index, Brittleness Index, and Horizontal Stress Index) that can be used to quantify CQ and RQ. The performance indexes are computed from petrophysical property volumes (of Young's Modulus, Bulk Modulus, Shear Modulus, Poisson's Ratio, Minimum Horizontal Stress, Volume of Shale, Total Organic Carbon, Thickness, and Porosity) which are in turn computed from well logs and geostatistical simulation. In the end, the study offers a method to compare the predicted “Sweet Spots” against available production data via their correlation coefficient. The resulting reasonable formation property maps, the successful identification of ‘Sweet Spots’, and a correlation coefficient of 0.88 (between the predicted “Sweet Spots” and well production data) point to the potential of the proposed effort.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 301-308"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"45843791","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":"An artificial neural network visible mathematical model for real-time prediction of multiphase flowing bottom-hole pressure in wellbores","authors":"Chibuzo Cosmas Nwanwe ,&nbsp;Ugochukwu Ilozurike Duru ,&nbsp;Charley Anyadiegwu ,&nbsp;Azunna I.B. Ekejuba","doi":"10.1016/j.ptlrs.2022.10.004","DOIUrl":"10.1016/j.ptlrs.2022.10.004","url":null,"abstract":"<div><p>Accurate prediction of multiphase flowing bottom-hole pressure (FBHP) in wellbores is an important factor required for optimal tubing design and production optimization. Existing empirical correlations and mechanistic models provide inaccurate FBHP predictions when applied to real-time field datasets because they were developed with laboratory-dependent parameters. Most machine learning (ML) models for FBHP prediction are developed with real-time field data but presented as black-box models. In addition, these ML models cannot be reproduced by other users because the dataset used for training the machine learning algorithm is not open source. These make using the ML models on new datasets difficult. This study presents an artificial neural network (ANN) visible mathematical model for real-time multiphase FBHP prediction in wellbores. A total of 1001 normalized real-time field data points were first used in developing an ANN black-box model. The data points were randomly divided into three different sets; 70% for training, 15% for validation, and the remaining 15% for testing. Statistical analysis showed that using the Levenberg-Marquardt training optimization algorithm (trainlm), hyperbolic tangent activation function (tansig), and three hidden layers with 20, 15 and 15 neurons in the first, second and third hidden layers respectively achieved the best performance. The trained ANN model was then translated into an ANN visible mathematical model by extracting the tuned weights and biases. Trend analysis shows that the new model produced the expected effects of physical attributes on FBHP. Furthermore, statistical and graphical error analysis results show that the new model outperformed existing empirical correlations, mechanistic models, and an ANN white-box model. Training of the ANN on a larger dataset containing new data points covering a wider range of each input parameter can broaden the applicability domain of the proposed ANN visible mathematical model.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 370-385"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47821036","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 review on the mechanisms of low salinity water/surfactant/nanoparticles and the potential synergistic application for c-EOR","authors":"Stanley Sim Sze Lim ,&nbsp;Henry Elochukwu ,&nbsp;Jobrun Nandong ,&nbsp;Ziad Bennour ,&nbsp;Mohamed Ali Hamid","doi":"10.1016/j.ptlrs.2023.02.001","DOIUrl":"10.1016/j.ptlrs.2023.02.001","url":null,"abstract":"<div><p>Chemical enhanced oil recovery (c-EOR) is a conventional and promising strategy to recover oil from reservoir techniques such as low salinity water flooding (LSWF), surfactant flooding, alkaline flooding, polymers flooding, and nanofluid flooding. The use of various types of chemical materials for c-EOR method has recently attracted the attention of the oil and gas industry. The primary objective of this review work is to explore the synergy of low salinity water/surfactant/nanoparticle flooding for effective c-EOR method and investigate the mechanism behind these methods. The advantages of combining these chemical materials for c-EOR methods is also reviewed. Challenges and limitations of this synergy and their economic feasibility for additional oil recovery and potential return on investment are reviewed. Nanoparticles have been successfully used in various applications in several industries and have also shown good application for EOR in terms of wettability alteration. LSWF contributes to wettability alteration, while surfactant contributes to wettability alteration and interfacial tension (IFT) reduction. However, fines migration caused by LSWF and nanoparticle agglomeration can cause formation damage, while excessive surfactant adsorption can lead to cost overrun on surfactant use. Understanding the characteristics of reservoir formation mineralogy and appropriate nanoparticle type, size, and concentration can be used to resolve this challenges. The synergy of LSWF and nanoparticles in alkaline medium can serve as sacrificial agent to reduce excessive surfactant loss. Therefore, the appropriate synergistic formulation of LSFW/surfactant/nanoparticle can improve additional oil recovery and support return on investment for c-EOR projects.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 324-337"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43241921","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}