Petroleum Research最新文献

{"title":"Wettability modification effects on relative permeability end-points: Comparative analysis of surfactant agents for enhanced oil recovery","authors":"Erfan Hosseini ,&nbsp;Negar Hosseini ,&nbsp;Mohammad Sarmadivaleh","doi":"10.1016/j.ptlrs.2023.09.002","DOIUrl":"10.1016/j.ptlrs.2023.09.002","url":null,"abstract":"<div><p>This research examines the impact of wettability alteration on the end points of relative permeability, a crucial property of fluids and porous media that influences the displacement processes of immiscible fluids through such media. The estimation of the mobility ratio for oil recovery relies on these end points, which are influenced by connate water saturation and residual oil saturation. To investigate this relationship, carbonate rock is generally subjected to wettability alteration using surfactant agents, and core flooding is employed to determine the relative permeability before and after the alteration. The wettability of the rock is commonly assessed through contact angle measurements. Two surfactants, TritonX-100 (Tx-100) and Cedar, were tested in reducing the wettability of the porous media for oil. The contact angle measurements revealed that Tx-100 was more effective for this purpose than Cedar. Furthermore, the relative permeability tests indicated that both surfactants decreased residual oil saturation, but Tx-100 also improved system pressure. In contrast, Cedar reduced residual oil saturation but increased system pressure, possibly because of its high viscosity. The results also demonstrate that injecting Tx-100 leads to a 14% increase in ultimate oil recovery compared with water injection, while Cedar injection increased the recovery factor by 5%. This difference may be attributed to the incomplete coverage of the pore wall by Cedar or its weaker chemical structure than Tx-100. Notably, in carbonate cores, neither non-ionic surfactant enhanced oil recovery.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 206-218"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000674/pdfft?md5=928d8d7dd97edd62653466a564fed091&pid=1-s2.0-S2096249523000674-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134917509","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":"Pore-scale study of the effects of DTPA chelating agent flooding on oil recovery utilizing a clay-coated micromodel","authors":"Hojjat Mohammadzadeh,&nbsp;Jamshid Moghadasi,&nbsp;Khalil Shahbazi,&nbsp;Shahin Kord","doi":"10.1016/j.ptlrs.2023.11.001","DOIUrl":"10.1016/j.ptlrs.2023.11.001","url":null,"abstract":"<div><p>The use of diethylenetriaminepentaacetic acid (DTPA) chelating agent has shown promising results for enhanced oil recovery (EOR) in prior research. Several mechanisms, mainly resulting from rock-fluid interaction, have been proposed for chelating agent flooding; however, little attention has been paid to fluid-fluid interaction thus far. The assessment of these mechanisms has primarily relied on macroscopic techniques such as core flooding. This paper aims to investigate the injection of DTPA brine and its dominant mechanisms at the pore scale using a clay-coated micromodel. The micromodel tests were performed under oil-wet and water-wet states. For a more precise examination of fluid/fluid interactions, the dynamic interfacial tension (IFT) and Zeta potential were measured. It was observed that the injection of DTPA brine in water-wet state changed the saturation distribution and increased oil recovery. Based on visual inspections, this change in saturation distribution could potentially be linked to the formation of micro-dispersions and viscoelastic interfacial phenomena. Micro-dispersions facilitate flow to unswept areas, and viscoelastic interface formation reshapes the interface between oil and brine, causing disconnected oil droplets to coalesce and thus increase recovery. Under the oil-wet state, the micro-dispersion formation and wettability alteration can be the dominant mechanisms, and the amount of recovered oil was higher than that observed in the water-wet state. Furthermore, Zeta potential measurements at the interface between brine and oil showed a more negative value for DTPA brine, which is effective in wettability alteration and micro-dispersions stability. The results indicate that IFT reduction was not significant enough to be considered the dominant mechanism, although it assists in DTPA brine penetration into the crude oil and subsequent micro-dispersion formation.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 228-237"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000704/pdfft?md5=fa7f37e553309556b87170fc4508337a&pid=1-s2.0-S2096249523000704-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139304606","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 utilization of spent palm cooking oil for formulating oil-based drilling muds with excellent H2S scavenging capability","authors":"Sagheer A. Onaizi","doi":"10.1016/j.ptlrs.2024.01.005","DOIUrl":"10.1016/j.ptlrs.2024.01.005","url":null,"abstract":"<div><p>In this study, a spent palm cooking oil-based mud with an excellent H₂S scavenging capability induced by the inclusion of a small quantity of potassium permanganate is formulated and tested for the first time. The mud formulation, containing the spent palm oil as the continuous phase and water as the dispersed phase, respectively, was stabilized by Span 80 and rhamnolipid biosurfactant as primary and secondary emulsifiers, respectively, while hydrophobic zinc nanoparticles (NPs) were used as weighting agent. The results showed that H₂S scavenging capacity at the breakthrough time reached 182.4 g H₂S/barrel mud, which increased to 417.9 g H₂S/barrel mud at the saturation time, demonstrating the effective H₂S scavenging performance of the formulated mud. The spent palm oil-based mud (SPOBM) also showed a good flow behavior that could be well fitted using the Herschel-Bulkley and Casson models. The effect of temperature on the apparent viscosity of the SPOBM has been investigated, and the fitting of the viscosity-temperature data provided an estimate of the activation energy as 23.53 kJ/mol. The findings reported in this article reveal the feasibility of transforming the spent/waste cooking oils into a valuable commodity for formulating greener drilling fluids with acceptable rheology and excellent H₂S scavenging performance.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 280-288"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S209624952400005X/pdfft?md5=711cb9870a91456e0ae8fb0da73d1914&pid=1-s2.0-S209624952400005X-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139638174","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":"Protection of steel hooks embedded in glass-fiber-reinforced concrete against macrocell corrosion","authors":"Husnu Gerengi ,&nbsp;Muhammed Maraşlı ,&nbsp;Marziya Rizvi ,&nbsp;Beni Kohen ,&nbsp;Ismail Taşkıran","doi":"10.1016/j.ptlrs.2024.01.001","DOIUrl":"10.1016/j.ptlrs.2024.01.001","url":null,"abstract":"<div><p>This study evaluated the corrosion behavior of steel hooks embedded in GFRC, which were protected by a zinc-rich (96% Zn) galvanizing coating. The coating provided the hooks with active cathodic protection and a passive physical shield. Macrocell corrosion may form when the anode is smaller than the total steel surface. Thus, the steel hooks at the embedment juncture were additionally sealed against water ingress and air exchange using a construction sealant. The study was conducted in three phases in a salt-spray chamber. First, the electrogalvanized steel hooks embedded in GFRC were allowed to freely corrode for 7 days. In the second phase, the electrogalvanized steel hooks were painted with the zinc-rich coating and observed over 7 days. In the third phase, the steel hooks were protected by the zinc-rich coating together with a primer and construction sealant, and observed over 7 days. To evaluate the electrogalvanized hooks and the corrosion products formed, the thickness of the material was measured. Corrosion on the metal surface was inferred by studying the surface morphology of the hooks at various points of contact and after different periods of time.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 317-326"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000012/pdfft?md5=63f680a1e03a3df30b54ad6576a86ae9&pid=1-s2.0-S2096249524000012-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139455603","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":"Simultaneous inversion of permeability, skin and boundary from pressure transient test data in three-dimensional single well reservoir model","authors":"Arvind Kumar ,&nbsp;Lin Liang ,&nbsp;Keka Ojha","doi":"10.1016/j.ptlrs.2024.01.004","DOIUrl":"10.1016/j.ptlrs.2024.01.004","url":null,"abstract":"<div><p>This study presents a novel approach for simultaneous inversion of the key reservoir parameters like horizontal permeability, vertical permeability, skin, and boundary distances for spatial distribution across the grid cells in a 3D single well reservoir model (SWRM). These parameters are first estimated from the standard pressure transient analysis of well test pressure and rate data, which also act as a priori for the inverse problem. A field-worthy layer cake geological model is prepared based on the prior information obtained from pressure transient analysis, followed by a sequential flow simulation of field well test operation. The simulation results provide the model pressure versus rate data as the synthetic data for this study. A cost function is defined incorporating the well test pressure data and model pressure data, which would determine the convergence. The inversion process is to optimize the spatial distribution of reservoir parameters to minimize the difference between the measured pressure transient data and the modelled one, which is obtained from the multiphase fluid flow simulator that solves the implicit black-oil fluid-flow diffusivity equations at every step. A Gauss-Newton (GN) inversion scheme is used for the inversion. The reliability of inversion results depends on the accuracy of priori reservoir parameters fed to the solver, which can be refined if required through uncertainty parameter optimization (UPO). This approach helps to obtain a faster and reliable update of reservoir parameters in a layer cake homogeneous geomodel, hereby introducing the required heterogeneity. This increases the confidence and reliability of a geomodel, which is further used for various production prediction strategies.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 265-272"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000048/pdfft?md5=762073cec58d13d23ad1ebba4f84d7e8&pid=1-s2.0-S2096249524000048-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139633670","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":"Advancing sandstone reservoir compressibility prediction: A correlation-driven methodology","authors":"Tarek Ganat ,&nbsp;Meftah Hrairi ,&nbsp;Amr Badawy ,&nbsp;Vahid Khosravi ,&nbsp;Mohammed Abdalla","doi":"10.1016/j.ptlrs.2024.01.006","DOIUrl":"10.1016/j.ptlrs.2024.01.006","url":null,"abstract":"<div><p>This study presents a correlation-based approach for predicting the compressibility of sandstone reservoir rocks. The study proposes a matrix of new empirical equations that significantly improve the precision of measuring the pore volume compressibility, with the most optimal fit of results based on a cubic polynomial model. The accuracy of the calculations was validated through comparison with actual data using root mean square method, and the suggested correlations significantly enhance the precise prediction of rock compressibility in sandstone reservoirs. In this study, the source of data collection is consolidated and unconsolidated sandstone from East Asia offshore oilfields. Accordingly, variations in compressibility with net overburden pressure over the course of the field's lifespan have been examined. The results demonstrate the application of regression analysis in establishing a network of linkages between independent and dependent variables. The proposed correlations for consolidated and unconsolidated sandstones offer a remarkable improvement in the accurate calculation of rock compressibility compared to traditional laboratory procedures, with an average error of 2.5% compared to 5–10% for laboratory measurements. The approach of this study offers a cost-effective and time-efficient alternative to remarkedly enhance the overall performance of sandstone reservoirs in the oil and gas industry.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 2","pages":"Pages 273-279"},"PeriodicalIF":0.0,"publicationDate":"2024-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249524000061/pdfft?md5=b2aa0024892ab824ed2d7e109c077872&pid=1-s2.0-S2096249524000061-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139457404","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":"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":"Optimization of gas lift system for well performance improvement in Asmari formation: A techno-economic perspective","authors":"Hari Sreenivasan,&nbsp;Jash Patel,&nbsp;Dev Jain,&nbsp;Setu Patel,&nbsp;Isaac Wilson,&nbsp;Shanker Krishna","doi":"10.1016/j.ptlrs.2023.08.003","DOIUrl":"10.1016/j.ptlrs.2023.08.003","url":null,"abstract":"<div><p>Well productivity in the Asmari carbonate formation of southwest Iran has decreased in recent years as a result of production issues. The production rate must be maintained below 1500 STB/day to prevent water coning. In this study, a gas lift well is modeled using data from one of the producing wells of this field. Nodal analysis is performed using lift-gas injection rates and wellhead pressures at different reservoir pressures and water cut conditions to optimize production. Economic aspects are considered to optimize the artificial gas injection rates at different tubing head pressures and water cut conditions. Increasing the lift-gas injection rate from 0.4 MMscf/day to 1 MMscf/day enhances the oil production rate by 37.71% and 43.89% for 10% and 30% water cut conditions, respectively. Gas injection rates of 5.2 MMscf/day and 5.4 MMscf/day are determined to be economically optimal for 30% water cut with tubing head pressures of 260 psig and 270 psig, respectively.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 1","pages":"Pages 115-124"},"PeriodicalIF":0.0,"publicationDate":"2024-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S209624952300056X/pdfft?md5=1d5813dd963fc2913594682da4bb05dd&pid=1-s2.0-S209624952300056X-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"54962341","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 contrasting analysis of CO2 and N2 foam flood for enhanced oil recovery and geological storage of CO2","authors":"Alireza Roozbahani ,&nbsp;Farshad Soofivand ,&nbsp;Ali Sagban Hassoon Al-Tameemi ,&nbsp;Hadi Abdollahi ,&nbsp;Sogand Saatchi ,&nbsp;Abdolhamid Ansari","doi":"10.1016/j.ptlrs.2023.07.003","DOIUrl":"10.1016/j.ptlrs.2023.07.003","url":null,"abstract":"<div><p>Foam flooding using CO₂ has emerged as a promising method for both enhanced oil recovery (EOR) and the storage of CO₂ in geological reservoirs. This study conducts a thorough analysis of the behavior of CO₂ and N₂ foams in bulk and porous media, utilizing bubble-scale analyses and foam flooding experiments. The study compares the foamability and longevity of CO₂ and N₂ foams, with findings indicating that N₂ foam bubbles tend to be smaller and less varied in size than CO₂ foam bubbles, leading to increased foam stability. Additionally, the study compares the half-lives of CO₂ and N₂ foams generated through sparging and winding methods, showing that N₂ foam has half-lives 22 and 10 times greater than CO₂ foam when produced using the sparging and winding methods, respectively. Furthermore, CO₂ foam generated through the sparging method had a lower foaming volume than N₂ foam due to CO₂'s solubility. In the foam flooding experiments, N₂ foam proved more effective in recovering oil from porous media than CO₂ foam, thus demonstrating the effectiveness of the foam injection procedure. These results offer valuable insights into the differing performance of N₂ and CO₂ foam floods for EOR and CO₂ geological storage.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"9 1","pages":"Pages 55-60"},"PeriodicalIF":0.0,"publicationDate":"2024-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2096249523000509/pdfft?md5=f64ab280bb864808a823037a135c2d76&pid=1-s2.0-S2096249523000509-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47009673","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}