Petroleum Research最新文献

{"title":"Impact of interfacial tension on oil-water flow in a narrow gap","authors":"Salim Raza ,&nbsp;Ian D. Gates ,&nbsp;Saira Sherin","doi":"10.1016/j.ptlrs.2023.11.002","DOIUrl":"10.1016/j.ptlrs.2023.11.002","url":null,"abstract":"<div><p>Numerous researchers have examined the co-current flow of oil-water and aqueous solutions containing polymers and surfactants in thin gaps for oil recovery. While some have focused on charges and forces at the interfaces of oil-surfactant solutions during flow. The study of flow structures, interface behavior, and relative permeabilities of oil and aqueous phases of surfactant flow through thin gaps has been less explored. For the first time, this research aims to comprehensively investigate the flow of oil-water and oil-surfactant solutions through a thin gap (Hele-Shaw cell) with a particular focus on the impact of sodium dodecyl sulfate (SDS). The experiments reveal that SDS forms an emulsion near the oil-water interface, capturing oil droplets and enabling their flow along with the SDS solution. Microscopic studies confirm this, showing that when SDS contacts oil, it creates channels through the oil phase, leading to the accumulation and division of oil into small round-shaped droplets, resulting in an oil-in-water emulsion. The addition of SDS to the injecting water significantly enhances relative permeabilities, leading to a remarkable 90% increase in oil recovery from the cell. The research suggests that the optimal SDS concentration range for maximum oil recovery is between 1.5 and 2 wt%, as it achieves the minimum interfacial tension between oil and water.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 219-227"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S209624952300087X/pdfft?md5=819a5f7deb924bb2f569fae3685078d7&pid=1-s2.0-S209624952300087X-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138620812","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":"Fine description of unconventional clastic oil reservoirs","authors":"Huanqing Chen","doi":"10.1016/j.ptlrs.2024.01.013","DOIUrl":"10.1016/j.ptlrs.2024.01.013","url":null,"abstract":"<div><p>The latest researches reveal that studies on unconventional clastic oil reservoirs in China generally lag far behind those in other countries in respect of content and methodology. This study presents the definition and classification of unconventional oil reservoirs and analyzes the problems in the fine description of unconventional oil reservoirs. The key content of the fine description of unconventional oil reservoirs is summarized from four aspects: fine fracture characterization based on fine structure interpretation, reservoir architecture characterization based on sedimentary facies, characteristics of nanoscale microscopic pore structure of reservoir, and evaluation of source rock and “sweet spot zone”. Finally, this study suggests that development of fine description of unconventional clastic oil reservoirs in the future should focus on rock brittleness analysis and fracture modeling, geophysical characterization of unconventional clastic oil reservoirs, fluid description of tight reservoirs, and physical/numerical simulation experiments of unconventional oil reservoirs.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 289-303"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000139/pdfft?md5=9c2bba61a84264eb5c43921c906c7438&pid=1-s2.0-S2096249524000139-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139823822","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":"An experimental study of alcohol injection to mitigate water blockage in commingled layered reservoirs","authors":"Emmanuel Gyimah ,&nbsp;Hamed Rahnema ,&nbsp;Hamid Rahnema","doi":"10.1016/j.ptlrs.2024.05.002","DOIUrl":"10.1016/j.ptlrs.2024.05.002","url":null,"abstract":"<div><div>This study explores the effectiveness of alcohol injection as a stimulation treatment to mitigate water blockage in the vicinity of the wellbore. Over the years, water blockage has emerged as a recurring challenge within the oil and gas industry, leading to diminished well productivity. In a commingled reservoir with multiple layers, when a producing well is shut-in for well intervention or workover, water may encroach from water zones into the oil-bearing formations through the wellbore due to pressure differences between the layers. Water encroachment can have a significant impact on the production of a well. It can reduce the oil production rate, increase the water cut, and shorten the well's lifespan. Therefore, it is essential to take steps to mitigate the water encroachment effect in commingled reservoirs. This study explores the use of alcohol injection to reduce transition time and remediate formation damage in commingled oil reservoirs. Limited studies have shown that alcohol has the potential to enhance fluid relative Permeability in gas condensate reservoirs and reduce condensate banking near the wellbore. However, this approach has not yet been tested in commingled oil reservoirs. A series of core flooding tests were conducted using Berea sandstone cores and a Texan light crude oil sample. The core flood setup was designed to represent the water blockage condition in the formation. Two different alcohols were tested: isopropyl alcohol (IPA) and Methanol. Experimental results showed that mutual solvents significantly reduce water blockage and shorten the transition period. However, asphaltene precipitation may become a problem with increasing the molecular weight of injected alcohol.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 610-619"},"PeriodicalIF":0.0,"publicationDate":"2024-05-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141134805","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":"Foam drainage modeling of vertical foam column and validation with experimental results","authors":"S.M. Hosseini-Nasab ,&nbsp;M. Rezaee ,&nbsp;P.L.J. Zitha","doi":"10.1016/j.ptlrs.2024.05.001","DOIUrl":"10.1016/j.ptlrs.2024.05.001","url":null,"abstract":"<div><div>The understanding of the mechanisms behind foam generation and the structure of foam itself form the basis of foam-related experiments for its application in Enhanced Oil Recovery and overcoming gas injection limitations. Novel insights in this paper towards the theory of foam generation can help explain experimental results and lead to improved formulas of the applied substances and concentrations. This study aims to investigate the mechanisms behind foam generation and the structure of foam by specific laboratory experiments and theoretical analyses. The liquid drainage through interconnected Plateau borders was found to be the most critical foam decay mechanism for this particular research. The justification of the foam drainage equation was demonstrated by comparing the numerical solution with the outcome of a few bulk experiments. The discrepancies were described according to the limitations of both the theory and the experimental settings. Foam modelling gives more profound knowledge in more detail of the different stages in foam drainage than experimental data can deliver, which is because of the lack of continuous measurement of foam conductivity for the foam bulk test. Therefore, a comprehension of foam modelling investigation and comparison is required to gain a deeper understanding of foam behaviour.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 586-598"},"PeriodicalIF":0.0,"publicationDate":"2024-05-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141137395","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":"Recent developments, challenges, and prospects of carbon dots (CDs) for fluid flow investigation in porous media","authors":"Mehdi Razavifar ,&nbsp;Ali Khoshsima ,&nbsp;Masoud Riazi ,&nbsp;James J. Sheng ,&nbsp;Ehsan Esmaeilnezhad","doi":"10.1016/j.ptlrs.2024.04.004","DOIUrl":"10.1016/j.ptlrs.2024.04.004","url":null,"abstract":"<div><div>Carbon nanostructures exhibit unique physicochemical properties and play a significant role in modern and advanced technologies. Carbon dots (CDs) are a subset of carbon-based particles less than 20 nm in size. In this study, a comprehensive review was performed on the applications of CDs for fluid flow investigations in porous media. CD technology provides precious information about the heterogeneity and permeability of the rock and the existence of a sealed part between the wells in the hydrocarbon reservoir. Studying the volume and flow potential of aquifers is another application of CD in fluid flow study. CDs can be used as an additive in the fluid to modify the chemical or physical properties. Adding CD to injected fluid in the reservoir can change the rheological properties of the fluid and reduce its viscosity. CD injection as a nanofluid in the reservoir rock increases the oil recovery factor and decreases injection pressure due to the change in the wettability of rock from oil-wet to water-wet and the reduction of interfacial tension between the fluids. The mobility and performance of CDs in pore scale are related to some parameters including ionic strength, pH, pore size distribution, and type of fluids in porous media.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 553-564"},"PeriodicalIF":0.0,"publicationDate":"2024-04-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142705889","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":"Machine learning classification algorithm screening for the main controlling factors of heavy oil CO2 huff and puff","authors":"Peng-xiang Diwu ,&nbsp;Beichen Zhao ,&nbsp;Hangxiangpan Wang ,&nbsp;Chao Wen ,&nbsp;Siwei Nie ,&nbsp;Wenjing Wei ,&nbsp;A-qiao Li ,&nbsp;Jingjie Xu ,&nbsp;Fengyuan Zhang","doi":"10.1016/j.ptlrs.2024.04.002","DOIUrl":"10.1016/j.ptlrs.2024.04.002","url":null,"abstract":"<div><div>CO₂ huff and puff technology can enhance the recovery of heavy oil in high-water-cut stages. However, the effectiveness of this method varies significantly under different geological and fluid conditions, which leads to a high-dimensional and small-sample (HDSS) dataset. It is difficult for conventional techniques that identify key factors that influence CO₂ huff and puff effects, such as fuzzy mathematics, to manage HDSS datasets, which often contain nonlinear and irremovable abnormal data. To accurately pinpoint the primary control factors for heavy oil CO₂ huff and puff, four machine learning classification algorithms were adopted. These algorithms were selected to align with the characteristics of HDSS datasets, taking into account algorithmic principles and an analysis of key control factors. The results demonstrated that logistic regression encounters difficulties when dealing with nonlinear data, whereas the extreme gradient boosting and gradient boosting decision tree algorithms exhibit greater sensitivity to abnormal data. By contrast, the random forest algorithm proved to be insensitive to outliers and provided a reliable ranking of factors that influence CO₂ huff and puff effects. The top five control factors identified were the distance between parallel wells, cumulative gas injection volume, liquid production rate of parallel wells, huff and puff timing, and heterogeneous Lorentz coefficient. These research findings not only contribute to the precise implementation of heavy oil CO₂ huff and puff but also offer valuable insights into selecting classification algorithms for typical HDSS data.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 541-552"},"PeriodicalIF":0.0,"publicationDate":"2024-04-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142705793","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":"Laser drilling through Hashma sandstone","authors":"Mohamed Hosin ElNeiri ,&nbsp;Abdel Sattar Abdel Hamid Dahab ,&nbsp;Abdulaziz Mohamed Abdulaziz ,&nbsp;Khalid Mahmoud Abdelghany","doi":"10.1016/j.ptlrs.2024.04.003","DOIUrl":"10.1016/j.ptlrs.2024.04.003","url":null,"abstract":"<div><div>The application of laser in the drilling and perforation of oil wells can achieve great benefits such as reduced drilling costs and time with a higher rate of penetration (ROP) and elimination of casing necessity in oil and gas well drilling. This paper presents an original experimental investigation of Laser cutting through Hashma sandstone (a common quarry rock in Egypt) to develop a good understanding of the laser cutting process in sandstone. Five blocks of Hashma sandstone with dimensions of 35 cm × 35 cm × 10 cm were utilized to study the effects of the various parameters involved in the lasing (cutting) process in order to evaluate the cutting process through sandstone, investigate the effect of laser parameters on the process and the cutting mechanisms. The experimental results showed that the laser drilling can provide lower specific energy (SE) compared to conventional drilling methods, revealed the effect of various laser and rock parameters (such as beam power, intensity, duration, sample size, and orientation) on the cutting process, and demonstrated the laser cutting mechanisms through sandstone such as thermal spallation and melting mechanisms. Several parameters must be optimized for an optimum laser cutting process with the lowest SE, such as using the optimum beam power, beam duration (or Lasig time), and beam mode (continuous or pulsed). The optimum parameters may change from one case to another and depend on the overall interactions among the various variables such as thermal dissipation rate and purging system efficiency.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 673-685"},"PeriodicalIF":0.0,"publicationDate":"2024-04-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140765526","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":"The discrete-imitation modeling concept of the “sucker-rod pump-well-reservoir” system and the optimization of the pumping process","authors":"Mahammad A. Jamalbayov ,&nbsp;Nazim A. Valiyev","doi":"10.1016/j.ptlrs.2024.04.001","DOIUrl":"10.1016/j.ptlrs.2024.04.001","url":null,"abstract":"<div><div>A new approach to dynamic modeling based on a discrete-imitation concept has been developed. The fundamentals, including terms and principles of the concept, have been explained. The presented concept has been applied to the integrated modeling of the development of a volatile oil reservoir operated by a sucker-rod pumping well within a pump-well-reservoir system. The discrete-imitation model of the “pump-well-reservoir” system, developed based on the principles of the new concept, takes into account fluid flow between the annulus and the lifting bore. It was employed to investigate the operation of the sucker-rod pumping well. The correlation between pumping rate, pump fillage, and stroke speed has been investigated. It was observed that, as the stroke speed increases, both pump performance and pump fillage increase up to a certain point. Beyond this threshold, the pumping rate stabilizes, and the pump fillage experiences a sharp decline. Notably, the maximum pump fillage does not always align with the peak pumping rate. In such instances, achieving an optimal regime is possible only through intermittent pumping. An expression has been derived to determine the optimal pump idle time in intermittent mode.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 686-694"},"PeriodicalIF":0.0,"publicationDate":"2024-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140769849","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":"Experimental investigation of the impact of soybean oil-derived surfactant as a surface-active agent during gas well deliquification","authors":"Gbadegesin Abioun Adeyemi,&nbsp;Kegang Ling,&nbsp;Adesina Fadairo","doi":"10.1016/j.ptlrs.2024.03.007","DOIUrl":"10.1016/j.ptlrs.2024.03.007","url":null,"abstract":"<div><div>The inability of the gas rate to overcome the gas critical (minimum) flow rate leads to liquid loading in a gas well. To avoid premature well shut-in, the injection of surfactants is one of the standard methods used in gas well deliquification, although many commercial surfactants pose environmental toxicity concerns. This project investigates the suitability of biosurfactants in generating foam that will reduce the surface tension of the liquid by adsorbing at the liquid-gas interface to create a more significant mass than the liquid droplets which can be easily extracted from the walls of the wellbore. An experimental setup simulating gas well conditions introduce a surfactant derived from soybean oil, subjecting it to tests for foam stability, unloading efficiency, and dynamic surface tension. The results from the modified ASTM D-892 test show that Soybean Oil Derived Surfactant (SODS) exhibits promising surface tension reduction properties and effectively alters the gas-liquid interface. With the increase in concentration from 200 ppm, 400 ppm, and 600 ppm, the expelled water increased from 17%, 28%, and 70% respectively. Similarly, Gao-Rosen adsorption isotherms confirmed SODS appropriate for the prediction of the adsorption from solution with the R² values of approximately 1.0. This study introduces a cost-effective and environmentally friendly surfactant that performs favorably for gas well deliquification.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 489-501"},"PeriodicalIF":0.0,"publicationDate":"2024-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140399612","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":"Reservoir identification of marine facies carbonate shoals in the Middle Permian in the Sichuan Basin","authors":"Yunbo Zhang ,&nbsp;Yan Feng ,&nbsp;Miao Miao ,&nbsp;Xingying Yu ,&nbsp;Xufeng Liu ,&nbsp;Mingjian Wang ,&nbsp;Li Sun","doi":"10.1016/j.ptlrs.2024.03.009","DOIUrl":"10.1016/j.ptlrs.2024.03.009","url":null,"abstract":"<div><div>Controlled by the base level change cycle, the carbonates exposed from the periodically shallowed water body at the top of the high-frequency sequence develops multiple sets of thin reservoirs. Such reservoir identification has always been tricky in the prediction of carbonate reservoirs. Based on the Middle Permian strata from the Sichuan Basin, this paper established a forecasting approach of high-frequency-sequence-controlled carbonate thin reservoir. The steps are as follows: (1) Combine the measured results of samples from the typical outcrops with changes of carbon and oxygen isotopes, thus to construct a division program for the 3rd-order sequence of the Middle Permian strata. (2) Compare the carbon and oxygen isotope changes and the global sea level change trend, determine the controlling factors of the 3rd-order sequences. (3) Carry out spectrum analysis based on the natural gamma energy spectrum logging (ln (Th/K)) curves of Wells Long-17 and Anping-1 to establish a high-frequency sequence framework division program, and then apply the logging curve characteristics to correct the top interface positions of the high-frequency sequences, which is the potential location of carbonate reservoir. The research results suggest that the Middle Permian in the Sichuan Basin can be divided into three 3rd-order sequences, which are PSQ1, PSQ2 and PSQ3 from bottom to top. Among which, PSQ1 is mainly affected by global sea level (GSL) changes, and the changes originated from its tuning curve can be directly applied to the division of high-frequency sequences and reservoir prediction. PSQ2 and PSQ3 are jointly controlled by global sea level changes and regional tectonics. In cope with the influence of regional tectonics, the positions of the four-level sequence interface established according to the tuning curve need to be fully considered, and good results were achieved through systematical correction. This method can effectively reduce the risk of reservoir prediction caused by marine carbonate heterogeneity, and provide scientific foundation for the prediction of high-frequency cyclic reservoirs of platform facies and platform margin subfacies in other marine carbonate sedimentary basins.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 4","pages":"Pages 502-513"},"PeriodicalIF":0.0,"publicationDate":"2024-03-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140403153","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}