Petroleum Research最新文献

{"title":"Mineral analysis of sandstone formation using chelating agents during sandstone matrix acidizing","authors":"Mian Umer Shafiq ,&nbsp;Hisham Ben Mahmud ,&nbsp;Lei Wang ,&nbsp;Momna Khan ,&nbsp;Ning Qi ,&nbsp;Khizar Abid ,&nbsp;Sophia Nawaz Gishkori","doi":"10.1016/j.ptlrs.2022.10.008","DOIUrl":"10.1016/j.ptlrs.2022.10.008","url":null,"abstract":"<div><p>For many years, the most common acid practice for sandstone acidizing is based on mud acid and dolomite formations using hydrochloric acid. During various stages of sandstone acidizing, different acids react with different minerals, and interactions of minerals with acids are an origin for precipitation reactions, which can be possibly deleterious as they may reduce reservoir permeability. During this research, the effects of chelates on pore size distribution, mineralogy, and grain size distribution have been investigated. Various chelates (GLDA, HEDTA, EDTA) were examined to react with different Berea Sandstone samples at a temperature of 180 °F and under 1000 psi confining pressure. Experimental techniques and analysis like Tescan Integrated Mineral Analysis (TIMA), were implemented in this research to understand the effect of chelates on Berea Sandstone. These results are related to elemental mass, element deportment, mineral mass, mineral locking, grain size distribution, and particle size distribution of the core samples reacted with different chelating agents. It has been found that all the chelating agents are effective in increasing the porosity and dissolving the cations from the Berea sandstone core sample. HEDTA proved to be more effective in dissolving quartz as compared to other chelates. GLDA proved to be more effective in the dissolution of rutile and zircon minerals. The significance of this research is the application of environment-friendly chelating agents to sandstone formation. Moreover, the detailed mineral analysis revealed that the most number of particles were dissolved by HEDTA.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 404-412"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47544165","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":"Impact of microfacies and diagenesis on the reservoir quality of Upper Devonian carbonates in Southeast Tatarstan, Volga-Ural Basin, Russia","authors":"Ibrahem Yousef,&nbsp;V.P. Morozov,&nbsp;A.N. Kolchugin,&nbsp;A. Leontev","doi":"10.1016/j.ptlrs.2022.10.006","DOIUrl":"10.1016/j.ptlrs.2022.10.006","url":null,"abstract":"<div><p>The results of integrated sedimentology, petrography, and petrophysical study of the Upper Devonian (Middle Famennian) Dankovo-Lebedyansky carbonates from Southeast Tatarstan of the Volga-Ural Basin revealed a variety of microfacies and diagenetic events that impacted the reservoir quality. Although our earlier study documented microfacies analysis and depositional environments, none of the studies focused on diagenesis, microfacies interaction, and their controls on the studied sediment's reservoir quality. Based on petrographic and microfacies analyses, the seven identified microfacies types are peloidal grainstone MF 1, cemented bioclastic peloidal grainstone MF 2, echinoderm-concentrated packstone MF 3, algae packstone MF 4, bioclastic wackestone MF 5, whole-fossil wackestone MF 6, and dolomite MF 7. For the investigated sediments, a gently deepening carbonate ramp depositional model with an inner, middle, and outer ramp setting is proposed. The observed diagenetic events in this study include micritization, calcite cementation (six cement types), dolomitization (six dolomite types), dissolution (fabric and non-fabric-selective dissolution), compaction, and microfracturing. The identified microfacies were classified into three distinct classes based on their petrophysical characteristics. MF 1 and MF 7 are microfacies types with the best reservoir quality. MF 3 and MF 4 are microfacies types of moderate reservoir quality. MF 2, MF 5, and MF 6 are microfacies types with poor or non-reservoir quality. Calcite cementation, micritization, and compaction are the primary diagenetic modifications responsible for porosity reduction. Moldic pores created by dissolution are a significant porosity-improving process. Porosity is locally enhanced by stylolite and microfractures. Dolomitization improved reservoir quality by creating intercrystalline and vuggy porosity. Understanding the impact of microfacies and diagenesis on reservoir quality is crucial for understanding reservoir properties in nearby fields with similar settings.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 386-403"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42993573","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":"Measurement-While-Milling (MWM): An innovative approach for increasing the casing milling efficiency in deep drilling operations","authors":"Mohammed A. Namuq ,&nbsp;Mouhammed Jandal Berro ,&nbsp;Matthias Reich","doi":"10.1016/j.ptlrs.2022.09.003","DOIUrl":"10.1016/j.ptlrs.2022.09.003","url":null,"abstract":"<div><p>Deep boreholes are secured by steel tubes (casings) which are run in the hole and cemented in place. In most cases, these casings are considered a permanent installation. However, sometimes they have to be removed in order to repair or abandon the well. As the casing is cemented in place, it cannot be pulled, but needs to be milled to small chips which are flushed out of the borehole by the drilling mud. One of the main challenges in casing milling operations is continuous and complete chip removal. If the metal chips are too long, chip nests will grow around the milling string. As a result, this will restrict the annulus flow area and affect the chip removal in boreholes. The obvious solution in such condition is to do round tripping and clean the chip nest which is associated with the risk of injuries, as well as, increasing the none-productive time. In the worst case, the poor cleaning and circulation of chips can even end up with the milling string stucking problem in boreholes, consequently long-time fishing job. According to the available literatures, hardly any study for identifying the chip shapes and accordingly adapting the operation parameters to the casing milling process environment downhole to keep milling within desired generated chip shapes and sizes could be found. This paper presents an encouraging idea to monitor the milling process in real time by utilizing the acoustic emission signals (vibration modes) accompanied with the milling process to identify the desired chip shape and size range. Initial laboratory tests have been carried out to investigate and study the acoustic emission signals accompanying the casing milling process to identify the chip shapes and sizes. The preliminary test results show very good correlation and agreement between the chip length formed during those specific tests and the observed burst events in the measured signals. The study results have demonstrated the functionality of the new concept, and thus confirmed that it is a very promising idea towards developing a practical real time downhole monitoring system for milling operations. Adapting the milling operation parameters downhole in real time to keep the milling process within the desired generated chip shapes and sizes will offer better cleaning and removal of the chips and will prevent the development of chip nest around the drill string and its consequences such as round tripping, risk of drilling crew injury, none-productive time and even milling string stucking problems.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 360-369"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"45820064","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":"Integrate inter–well connectivity data with static reservoir models based on Bayesian formalism","authors":"Yupeng Li ,&nbsp;Rashid S. Mohammad","doi":"10.1016/j.ptlrs.2023.01.003","DOIUrl":"10.1016/j.ptlrs.2023.01.003","url":null,"abstract":"<div><p>The inter-well connectivity calculated from reservoir dynamic production data reflects formation heterogeneity quantitatively. Currently, the calculated inter-well connectivity between pair wells is mainly used as a tool for water flood management but not for quantitative reservoir characterization. This study proposes an innovative, dynamic data integration workflow that can integrate inter-well connectivity with a static reservoir model. In the workflow, the first step is calculating the inter-well connectivity vectors from the reservoir pairwise injector and producer wells. The second step covers interpolation in the domain of interest. The third step is to update the permeability model based on the Bayesian updating method. The result of this study shows that integrating the calculated inter-well connectivity with the static models enhances model reliability and it also provides an insight to deeper geological understanding reflected from dynamic data integration in reservoir modeling.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 433-438"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42164860","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":"Design and construction of a continuous pilot flotation facility: A case study for water-based oil sand extraction","authors":"Feng Lin","doi":"10.1016/j.ptlrs.2022.11.001","DOIUrl":"10.1016/j.ptlrs.2022.11.001","url":null,"abstract":"<div><p>In this work, the design and construction of a continuous and pilot-scale flotation facility are demonstrated. The performance of the new facility was evaluated from series of pilot flotation tests, carried out using oil sands slurry to extract bitumen—an extra-heavy form of petroleum. Results indicated that bitumen recoveries of the new pilot plant for an identical ore and water chemistry were largely dependent on air injection method, slurry conditioning time, flotation residence time, and slurry temperature. Importantly, when compared with those of bitumen extraction tests using a bench-scale Batch Extraction Unit (BEU) operated at the most optimal conditions, it was suggested that the new pilot plant produced flotation recoveries of bitumen and froth qualities at a level as good as, or even higher than, the level accomplished using the BEU at an identical ore, water chemistry and operating temperature. This continuous, pilot flotation plant could potentially serve as a pre-commercial production system that verifies a new processing aid, or as an alternative extraction technology for oil sand, coal, and mineral processing.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 309-315"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47492642","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":"Experimental investigation of the influence of carbonated water on sandstone and carbonate rock properties","authors":"Hisham Ben Mahmud ,&nbsp;Mohamed Khalifa ,&nbsp;Mian Shafiq ,&nbsp;Ausama Giwelli","doi":"10.1016/j.ptlrs.2022.10.007","DOIUrl":"10.1016/j.ptlrs.2022.10.007","url":null,"abstract":"<div><p>Laboratory measurements using nuclear magnetic resonance, scanning electron microscopy, and gas porosity and permeability analysis were conducted to acquire a petrophysical interpretation of the Carbon Tan Sandstone and Savonnieres Carbonate for potential carbon dioxide storage in subsurface formations. The relationships between pore structures, such as pore-size distribution, pore geometry, and porosity/permeability, were investigated near and far from the wellbore. At operating pressures of 2500psi (17.24 MPa) and temperatures of 176 °F (50 °C), carbonated water was injected into a composite core constructed of two similar core samples bounded by a compact disc located between them. The current results showed that a strong calcite dissolution took place near the injection position of both rock samples and led to improvements in the primary intergranular permeability and porosity, while the carbonate sample showed significant improvement compared to sandstone. The durable heterogeneous dissolution of calcite grains also led to the creation of new pores as intra-granular micro-pores. While at deeper depths from the injection position, it noticed an insignificant development in pore structure and its populations as well as rock hydraulic properties of both rock samples. In conclusion, the study revealed that the injected carbonated brine had a valuable impact on fluid-formation interactive, which improved rock's inlet properties compared with outlet.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 316-323"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41417649","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":"Geomechanical analysis of an oil field: Numerical study of wellbore stability and reservoir subsidence","authors":"Saeed Shad ,&nbsp;Parvin Kolahkaj ,&nbsp;Davood Zivar","doi":"10.1016/j.ptlrs.2022.08.002","DOIUrl":"10.1016/j.ptlrs.2022.08.002","url":null,"abstract":"<div><p>Geomechanics as the knowledge of rock deformation and stability is an indispensable part of all field development plans. Conducting geomechanical analyses leads to a safer and more efficient operation otherwise different kinds of instability and distortion might occur. In this study, the geomechanical behavior of Ilam and Sarvak formations of an oil field in southwest of Iran was investigated. The research objectives can be summarized as wellbore stability evaluation and predicting the value of reservoir subsidence due to pressure drop as a result of reservoir fluid production. To fulfill these, a set of petrophysical logs run in the exploration well of this green field were collected. Next, using empirical correlations and statistical methods, required data for evaluating wellbore stability during drilling, specifying safe mud window to discover reservoir breakdown pressure, predicting the possibility of wellbore collapse in field lifetime, and assessing reservoir subsidence were determined. The results revealed that the average subsidence value as the consequence of production within 21 years is 0.275 ft Which is not significant. In terms of wellbore stability, it was concluded that all horizontal and vertical wells remain stable during this time period. Briefly to conclude, field development is not associated with alarming incidents from geomechanical aspect.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 350-359"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47466095","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":"Energy efficiencies and CO2 emissions associated with low-temperature separation technologies for the processing of formation fluid from the Achimov deposits","authors":"Alexandra Saitova ,&nbsp;Sergey Strokin ,&nbsp;Falk Ahnert ,&nbsp;Aleksandr Chepurnov","doi":"10.1016/j.ptlrs.2022.12.001","DOIUrl":"10.1016/j.ptlrs.2022.12.001","url":null,"abstract":"<div><p>Three different technologies for the low-temperature separation (LTS) of gas condensate from the Achimov deposits in the Russian Urengoyskoe gas and condensate field were assessed using exergy analyses. The options examined included turbo-expansion and ejection. Thermomechanical exergy values were calculated for material streams and exergy losses and efficiencies were estimated for dedicated equipment used in the LTS. The lowest exergy loss of 4221.2 kW was obtained using turbo-expansion and electricity cogeneration. The carbon release associated with each scenario was calculated while considering different production rates, technological parameters and natural decreases in wellhead pressure. The integral carbon footprint after 40 years of LTS operation was estimated for all cases. A classical ejector-based LTS scheme was shown to produce 1200 t of CO₂ emissions over 40 years of operation. This same scheme combined with a turboexpander and electricity generator produced 59% less CO₂ in the same period. An expansion-cogeneration LTS scheme was found to be the most effective and ecologically friendly among the various options based on this analysis.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 3","pages":"Pages 413-423"},"PeriodicalIF":0.0,"publicationDate":"2023-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49488688","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":"Effects of nanoparticles, polymer and accelerator concentrations, and salinity on gelation behavior of polymer gel systems for water shut-off jobs in oil reservoirs","authors":"Shaikh Mohammad Shehbaz,&nbsp;Achinta Bera","doi":"10.1016/j.ptlrs.2022.06.005","DOIUrl":"10.1016/j.ptlrs.2022.06.005","url":null,"abstract":"<div><p>Excess water production is one of the crucial complications in the oil industry, leading to a rapid decline in oil production. To overcome this problem, different polymer gels are used to block the water's path to reduce water production. In the present work, polymer gel systems were prepared with polymers namely partially hydrolyzed polyacrylamide (PHPA), organic crosslinkers like hexamine, and hydroquinone with the incorporation of silica and alumina nanoparticles. Nanoparticles are used to enhance the stability of the gel framework in high salinity and high temperature reservoir environment. When designing the polymer gel system, factors such as pH, thermal stability, brine composition, injection rate, and chemical concentration were considered. Concentrations of PHPA and nanoparticles were varied from 1 to 2 wt% and 0.25–1.0 wt% respectively for the preparation of different gel systems. The concentration of the organic crosslinker was extended from 5000 to 11000 ppm for investigating the effect on gelation time. Brine concentration was chosen from 2 to 8 wt% to find the impact of high salinity. Succinic acid as an accelerator was also used to study the effect on gelation time, and it was found that the gelation time is reduced as the concentration of succinic acid increases. The prepared polymer solution was taken in a test tube and was kept inside a hot air oven at 95 °C to perceive the gelation time and nature of the produced gel. Results showed that nanoparticles do not influence the gelation time, but they considerably affect gel stability. However, concentrations of polymer, accelerator, and salt (salinity) have significant effects on the gelation behavior of the gel systems.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 2","pages":"Pages 234-243"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48851771","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":"Erratum regarding missing Declaration of Competing Interest statements in previously published articles","authors":"","doi":"10.1016/j.ptlrs.2023.05.009","DOIUrl":"https://doi.org/10.1016/j.ptlrs.2023.05.009","url":null,"abstract":"","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"8 2","pages":"Pages 287-288"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"50168986","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}