Petroleum Research最新文献

{"title":"Hydrocarbon generation potential of South Geisum Oilfield, Gulf of Suez, Egypt: Source rock evaluation and basin modeling for unconventional hydrocarbon prospects","authors":"Mohamed Osman ,&nbsp;Sherif Farouk ,&nbsp;Tamer Salem ,&nbsp;Mohammad A. Sarhan","doi":"10.1016/j.ptlrs.2024.11.002","DOIUrl":"10.1016/j.ptlrs.2024.11.002","url":null,"abstract":"<div><div>This study aims to define the hydrocarbon generation potential of source rocks by assessing various factors including quantity of organic matter, types of kerogen, thermal maturity, and source of organic matter input. Depositional conditions of source rocks from Thebes, Brown Limestone, and Matulla formations in Well G-9, Well GA-2 and Well GW-6, are assessed through pyrolysis, vitrinite reflectance and 1D basin modeling. Results show the source rocks of Thebes and Brown Limestone formations exhibit favorable to excellent source rock characteristics with Type I–II kerogen and have the capacity to generate oil. Conversely, the source rocks of the Matulla Formation show fair to good source rock characteristics with Type II–III kerogen and have the capacity to produce both oil and gas. Thermal maturity shows the source rocks are at an immature stage. A 1D basin model is constructed for Well G-9 to simulate multi-tectonic episodes, burial events, and the history of thermal maturity. Sedimentation rates of Cretaceous to Eocene deposits are characterized by a low burial rate, which contrasts with the high burial and sedimentation rates for Miocene and post Miocene (Pliocene–Recent) strata. Overall, the South Geisum oilfield petroleum system is found to be immature based on integration of source rock evaluation and petroleum basin modelling.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 266-278"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314369","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":"Optimum formation depths for CO2 structural trapping: Impact of salinity","authors":"Haiyang Zhang,&nbsp;Muhammad Arif","doi":"10.1016/j.ptlrs.2025.01.001","DOIUrl":"10.1016/j.ptlrs.2025.01.001","url":null,"abstract":"<div><div>Geological CO₂ storage is considered a promising solution to achieve net-zero goals. Structural trapping is one of the primary mechanisms that holds the injected CO₂ within the storage medium and prevents leakage via an impermeable seal/caprock. The capillary sealing efficiency of the caprock is also crucial in ensuring the safety of structural trapping. Capillary sealing and the associated CO₂ column height are determined by the balance of capillary threshold pressure and buoyancy pressure, which is strongly influenced by the CO₂/fluid/formation properties (i.e., density, interfacial tension (IFT), and wettability). However, subsurface formations typically exhibit a wide range of salt concentrations and depict heterogeneity in terms of wettability and pore radius, further influencing these critical properties. Thus, the impact of salinity, wettability, IFT, and pore radius on structural trapping efficiency is assessed in this study. Our analysis suggests that the optimal storage depth for structural trapping decreases as salinity increases; for instance, the highest CO₂ column height was observed at a depth of ∼1400 m in 5 wt% salinity formations. New correlations were also developed to quantify the CO₂ column height and mass under various formation depths and salinity conditions. Despite different dissolved salts (e.g., NaCl, CaCl₂, and MgCl₂) influencing the brine density and IFT, their impact on structural trapping is negligible. Additionally, the heterogeneity in formation properties (i.e., wettability, IFT, and pore radius) strongly influences the CO₂ column height, resulting in uncertainties in the CO₂ distribution prediction.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 416-424"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314516","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":"Evaluating the potential of depleted oil reservoirs for CO2 sequestration through simulation modeling","authors":"Malik Muhammad Ali Awan ,&nbsp;Farzain Ud Din Kirmani","doi":"10.1016/j.ptlrs.2025.01.003","DOIUrl":"10.1016/j.ptlrs.2025.01.003","url":null,"abstract":"<div><div>Leading to achieve net zero emissions, performing carbon capture and storage (CCS) on a large scale is becoming more necessary, especially for developing countries, which are highly affected by the continuously increasing release of carbon dioxide (CO₂). It has also been observed that developing countries does not participate much in the release of CO₂ in the atmosphere but are highly influenced by global warming because of geological location. Therefore, addressing challenges of climate changes and its impacts requires high-capacity storage in safe and reliable locations. Depleted oil and gas reservoirs offer a valuable option to store CO₂ due to their adequate porosity and permeability. In this research, an effort has been made to provide a simulation study and comprehensive analysis of CO₂ storage through reservoir simulation in subsurface oil reservoir. In contrast to prior works, this research article introduces a simulation approach to assess the feasibility of CO₂ storage in an oil reservoir. Storage in an oil reservoir was modeled using a commercial compositional simulator. CO₂ behavior during injection is examined using gas injection profiles throughout the injection duration and injection rate. Results of the study demonstrate that reservoir pressure changes equally in all layers and grid blocks making the evaluated reservoir suitable for CO₂ storage. Bottom hole pressure (BHP) behavior during injection shows the feasibility of CO₂ storage. The analysis revealed that continuous injection of CO₂ at a rate of 3500 Mscf/day over a period of 10 years led to a successful storage scenario, with the reservoir reaching its space limit and the injection rate dropping to zero. These results suggest the viability and effectiveness of CO₂ storage as a means of mitigating greenhouse gas (GHG) emissions.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 425-431"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314517","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":"Mitigating gas migration with eutectic bismuth alloy plugs","authors":"Lewaa Hmadeh,&nbsp;Andriani Manataki,&nbsp;Marcelo Anunciação Jaculli,&nbsp;Behzad Elahifar,&nbsp;Sigbjørn Sangesland","doi":"10.1016/j.ptlrs.2024.09.003","DOIUrl":"10.1016/j.ptlrs.2024.09.003","url":null,"abstract":"<div><div>Gas migration is an important concern to address in oil wells, especially in those that are to be abandoned. Stopping a gas leakage is not a simple task, and this can be particularly detrimental when setting a cement plug, as the migrated gas can undermine the integrity of said plug. In this context, and considering the recent attention given to metal plugs, we investigate the capability of bismuth plugs in shutting off gas leakages. The bismuth alloy employed to form the plug is to be melted downhole, and thus its proper solidification may be compromised if a leakage is underway. We test the sealing capability of two bismuth alloys – the eutectic bismuth-tin and the eutectic bismuth-tin-indium – along with two pipes – acrylic and steel. Results indicate that the bismuth plug can seal off the inner space of the pipe as long as the alloy used is eutectic; otherwise, a channel is created if the alloy is only near eutectic, effectively permitting that the leakage still continues. This sealing capability has been verified for both eutectic alloys tested, although it was also observed that voids are still present within the plugs themselves, potentially undermining their mechanical properties. Furthermore, we also observed that a slow and controlled cooling approach reduces the volume of inner voids, thus mitigating the plug degradation caused by the migrating gas. Further work should verify how these voids impact the hydraulic shear bond strength of the plug. From a microstructural perspective, it seemed that the solidification cooling rate plays a key role in the grain size of the material, which significantly impacts the microstructure of the alloy and, consequently, its mechanical properties. Considering the findings discussed in this work, we recommend that a two-plug approach is employed in leaking wells: a first, eutectic plug would shut down the leakage at the cost of its strength, and then a second – eutectic or non-eutectic – plug would be placed under no leakage ensuring the desired strength and sealability requirements. This study further highlights the potential of bismuth alloys to enhance safety and efficiency in plug and abandonment (P&amp;A) operations by mitigating gas migration issues.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 331-341"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314662","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":"Numerical validation of a novel cuttings bed impeller for extended reach horizontal wells","authors":"Chi Peng ,&nbsp;Yao Xiao ,&nbsp;Jianhong Fu ,&nbsp;Quan Cao ,&nbsp;Jiyun Zhang ,&nbsp;Yu Su ,&nbsp;Honglin Zhang ,&nbsp;Xing Wan ,&nbsp;Danzhu Zheng","doi":"10.1016/j.ptlrs.2024.07.002","DOIUrl":"10.1016/j.ptlrs.2024.07.002","url":null,"abstract":"<div><div>To reduce the risk of downhole accidents resulting from poor wellbore cleaning during the drilling of extended reach horizontal wells, a new cuttings bed impeller is developed. The performance of existing cuttings bed impellers on wellbore cleaning efficiency is analyzed by multiphase numerical simulation. Based on this analysis, a new type of cuttings bed impeller is proposed, and its key structure parameters are optimized. Its cuttings removal performance under different working conditions is verified. The results show that the spiral impellers have the highest annular velocity, promoting the movement of the cuttings bed. Increasing the rotation speed of the impeller causes the cuttings bed to move further from the low side of the wellbore, facilitating the cuttings removal. Two major improvements are introduced to the new cuttings bed impeller: a positive displacement motor that enables the self-rotation of the impeller, and the elastic contacts on the spiral blades that stir cuttings bed and reduce friction with the wellbore. The optimized parameters of the new impeller are: helix angle of 60°, 4 blades, elastic contacts arranged in crossed pattern, and self-rotation speed of 60 r/min. It is also demonstrated that the new impeller achieves satisfactory cleaning results in both rotary drilling (84.71%) and sliding drilling (71.07%) conditions. This work provides a new solution for the efficient removal of cuttings in extended reach horizontal wells.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 105-128"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141691513","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":"Development characteristics and controlling mechanism of different microfracture combinations in shale reservoir: A case study of Silurian Longmaxi Formation in Weiyuan area","authors":"Yuexiang Hao ,&nbsp;Lei Wu ,&nbsp;Wei Jiang ,&nbsp;Chao Qian ,&nbsp;Xin Zhou ,&nbsp;Yuanlin Wang","doi":"10.1016/j.ptlrs.2024.07.003","DOIUrl":"10.1016/j.ptlrs.2024.07.003","url":null,"abstract":"<div><div>Fractures in organic-rich shale are important reservoir spaces and seepage channels of shale gas, and they are closely related to the gas-bearing properties of shale. The development characteristics and laws of fractures are of great significance in the exploration and development of shale oil and gas. This study examines organic-rich shales of the Wufeng–Longmaxi Formation in the Weiyuan area of the Sichuan Basin. On the basis of two-dimensional large-area multi-scale combination electron microscopy characterization and digital core platform technology, the development degree and distribution of different fractures are quantitatively characterized. The results show the following. (1) The shale of the Wufeng and Longmaxi formations developed a variety of fractures with different occurrences, sizes, and origins. According to the number and combination relationship between fractures of different occurrences, the shale can be divided into four fracture combination types: horizontal bedding fractures; vein fractures; reticular fractures; and ring fractures. Of these, the horizontal bedding fracture group has the largest number of samples and a higher average fracture surface porosity. (2) The degree of fracture development in the shale is affected by many factors, such as the laminar type, mineral composition, mineral particle size, mineral distribution, and total organic carbon, and the controlling mechanisms of different fracture combination types differ. Factors such as horizontal stratification, high clay mineral content, and uneven mineral particle size are conducive to the development of horizontal bedding joints. (3) Differences in the sedimentary environment affect the variation laws of the vertical fracture combination types and density. The total organic carbon and organic quartz content of the Long1₁¹ layer with deeper sedimentary water is higher, and the vein fracture formation is more developed than in other small layers, while the clay mineral content of the Long1₁² and Long1₁⁴ layers with shallower sedimentary water is higher and the horizontal layer is more developed; the fracture combination type is dominated by the horizontal bedding fracture combination. At the same time, the fractures at the junction of each layer of the Long1₁ sub-member are the most developed because sea level rise and fall make the mineral particle size heterogeneity most prominent at the junction of the small layer.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 66-78"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141716314","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":"Modelling of physical and chemical properties of activated carbons which affect methane adsorption mechanisms","authors":"John Rwiza Rugarabamu","doi":"10.1016/j.ptlrs.2024.08.001","DOIUrl":"10.1016/j.ptlrs.2024.08.001","url":null,"abstract":"<div><div>Effect of important physical and chemical properties of activated carbons which affect the way methane adsorbs were studied. The Grand Canonical Monte Carlo (GCMC) simulations were used to study how the curvature and size of the platelets affect the mechanisms of methane adsorption process; and which role is played by the amount of oxygen present in activated carbons. Furthermore, Molecular dynamic (MD) simulations were carried out to study the effect of those properties on motion behavior of methane molecules during adsorption. The two simulations are very vital because they were able to exploit mechanisms which are difficult to obtain by using experiments alone. It was found that oxygen content, degree of curvature of platelets and size of basic structural units affected the availability of suitable methane binding sites in activated carbons and hence total methane adsorbed amount. Furthermore, the studied parameters were found to have impacts to the energy of interaction between activated carbons and methane, methane diffusion characteristics and amount of heat generated during adsorption process. It is concluded that the studied activated carbon properties hugely affect the way methane adsorbs and should be given attention during designing of the optimal adsorbent for methane adsorption.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 188-203"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684817","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":"CO2 injection for enhanced oil recovery: Analyzing the effect of injection rate and bottom hole pressure","authors":"Malik Muhammad Ali Awan ,&nbsp;Farzain Ud Din Kirmani","doi":"10.1016/j.ptlrs.2024.08.006","DOIUrl":"10.1016/j.ptlrs.2024.08.006","url":null,"abstract":"<div><div>The goal of net-zero carbon emissions has led to widespread interest in lowering carbon dioxide (CO₂) emissions. At the same time, the oil and gas industry seeks to enhance oil recovery (EOR) techniques to meet growing demand. CO₂ flooding, a key EOR method, offers a dual benefit: reducing CO₂ emissions and enhancing oil recovery. This study investigates the impact of injection rate and bottom hole pressure (BHP) on CO₂ injection performance using the Nexus reservoir simulator, a novel application in CO₂-EOR research. To the best of the author's knowledge, there is no previous research published in which the researchers used the Nexus reservoir simulator for the study of CO₂-EOR. Cases are thoroughly investigated with various injection rates and BHP limitations. Simulation results show that BHP has a minimal impact on oil production, whereas increased injection rates significantly enhance cumulative oil production (COP) by 33.39% and extend reservoir life from 20 to 37 years. Total oil production increased to 33150.7 MSTB, accompanied by reduced water production and maintained reservoir pressure. These findings align with previous research, underscoring the importance of optimized CO₂ injection strategies for maximizing oil recovery and reservoir performance.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 129-136"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684777","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":"Flow assurance methods for transporting heavy and waxy crude oils via pipelines without chemical additive intervention","authors":"Rakesh Kumar Ratnakar ,&nbsp;Sivakumar Pandian ,&nbsp;Hepzibah Mary ,&nbsp;Himanshu Choksi","doi":"10.1016/j.ptlrs.2024.07.005","DOIUrl":"10.1016/j.ptlrs.2024.07.005","url":null,"abstract":"<div><div>Most of the unconventional fossil fuel reserves consist of heavy crude oil. Crude oil is transported through pipelines, land, and cargo tankers. It loses its ability to flow below its pour point. Therefore, crude oil needs to be heated above its pour point, or it requires some mechanism to reduce viscosity and improve the flow in pipeline transportation. The flow assurance methods depend on the types and attributes of crude oil. Saturates, aromatic, resin and asphaltenes are the main constituents, and their composition and proportion define crude oil's properties. Higher molecular weight components, such as waxes, resins, and asphaltenes cause high viscosity in crude oil. Chemical additives are the commonly used method to reduce viscosity. However, recent advancements in non-chemical treatment methods for heavy and waxy crude oil provide an opportunity for flow assurance in pipeline transportation. These methods include dilution and emulsification, annular and core flow, thermal and electrical heating, ultrasonic and microwave treatment, solar heating, electromagnetic field conditions, thermochemical heat treatment, and plasma heating. However, these techniques have certain advantages and disadvantages depending on the characteristics of the crude, the applicability of technology, and economic considerations. A combination of two or more techniques for viscosity reduction is more suitable for flow assurance in pipeline transportation.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 204-215"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141841188","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":"Identification and tracing of near-source petroleum transport system based on reservoir bitumen index (RBI) method: A case study of the lower cambrian in the Tazhong-Bachu area, Tarim Basin, China","authors":"Lihao Bian ,&nbsp;Nan Wu ,&nbsp;Zhongxian Cai","doi":"10.1016/j.ptlrs.2024.06.007","DOIUrl":"10.1016/j.ptlrs.2024.06.007","url":null,"abstract":"<div><div>The exploration of deep layers has become increasingly important in the global oil and gas industry. The Tazhong-Bachu area of the Tarim Basin is a pioneering target for deep petroleum exploration in China, but only Wells Zhongshen1 and Zhongshen5 have found industrial oil flow in the Cambrian. Noteworthily, the occurrence of reservoir bitumen in the Lower Cambrian coring interval in many wells indicates that large-scale hydrocarbon migration had occurred here in geological history. Effective identification of reservoir bitumen in the Cambrian dolomite reservoirs is crucial to understanding hydrocarbons' distribution and migration. In this study, we adopt the Reservoir Bitumen Index (RBI) method to deduce a quantitative calculation formula for reservoir bitumen, and classify the transport system into four types based on differences in hydrocarbon transport behavior and characteristics. The results show that the deep carbonate low permeability-tight reservoirs of the Lower Cambrian in the Tazhong-Bachu area generally develop reservoir bitumen, most likely derived from underlying Precambrian source rocks. Therefore, the Lower Cambrian carbonate reservoir is considered a near-source discrete petroleum transport system, providing great potential for further oil and gas exploration in the Lower Paleozoic in the Tazhong-Bachu area.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 45-56"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684775","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}