Petroleum Research最新文献

{"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":"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":"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":"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}

{"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":"Production optimization of heavy oil recovery utilizing Mo-Ni based liquid catalysts: A simulation approach","authors":"Ali Alarbah,&nbsp;Arifur Rahman,&nbsp;Ezeddin Shirif,&nbsp;Na (Jenna) Jia","doi":"10.1016/j.ptlrs.2024.08.005","DOIUrl":"10.1016/j.ptlrs.2024.08.005","url":null,"abstract":"<div><div>In recent years, the demand for heavy oil has increased due to its abundant availability and low cost. However, the extraction of heavy oil poses a significant challenge due to its high viscosity and low mobility. Therefore, various methods have been developed to enhance the recovery of heavy oil, including the use of catalysts. This study has created a unique simulation approach that uses liquid catalysts (LCs) to improve heavy oil recovery. In this work, laboratory testing dataset and numerical simulation studies were used to examine the potential of applying LCs as an alternative chemical agent for enhancing heavy oil recovery. CMG-STARS and CMOST modules were used to historical match the laboratory scale results of two sand-pack flooding experiments (water flooding and liquid catalyst flooding in tertiary recovery mode). Moreover, a sensitivity study was conducted to apply a wide range of assumptions to determine the most effective process controlling parameters. Finally, oil production optimization is performed using a genetic algorithm (particle swarm optimization) by selecting the optimum-operating parameters. In comparison to typical water flooding, the results revealed a discernible rise in the heavy oil recovery factor (RF) when injecting LCs<strong>.</strong> The simulation results showed that the optimized production strategy could increase the ultimate oil recovery by up to 45.06%. The injection rate, slug size, and injection temperature were found to be significant factors in optimizing the production of heavy oil. This simulation approach can be used to optimize the production of heavy oil using acidic Mo-Ni based liquid catalyst in different reservoirs.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 57-65"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684776","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":"Leakage monitoring of carbon dioxide injection well string using distributed optical fiber sensor","authors":"Sen Chen ,&nbsp;Hongjuan You ,&nbsp;Jinshan Xu ,&nbsp;Maoan Wei ,&nbsp;Tirun Xu ,&nbsp;He Wang","doi":"10.1016/j.ptlrs.2024.08.003","DOIUrl":"10.1016/j.ptlrs.2024.08.003","url":null,"abstract":"<div><div>Whether the oil and gas fields in the Carbon Capture, Utilization, and Storage (CCUS) project use underground storage or energy supplementation to enhance oil recovery, they must be injected or monitored through the wellbore. Thus, the foundation and requirement for the safety of carbon dioxide (CO₂) storage is the wellbore's integrity. When CO₂ is dissolved in water, carbonic acid is created, and this acid strongly corrodes underground pipes. Therefore, the integrity issue with CO₂ injection wells is more noticeable than with other wellbores. An annular pressure during gas injection is the primary symptom of gas injection string leakage in CO₂ injection wells. This study aims to provide real-time pipe string monitoring using a distributed optical fiber temperature sensing system (DTS) and a distributed optical fiber acoustic sensing system (DAS). Variations in temperature and vibration are caused by annulus pressure relief or gas injection. Optical fiber logging, in contrast to traditional logging, has better performance indicators for optical fiber sensing apparatus. To adapt to complex wellbore conditions, it is necessary to enhance the temperature accuracy of DTS and the sensitivity and signal-to-noise ratio of DAS in CO₂ drive injection wells based on the features of the gas injection string. To differentiate the leakage signal from the regular fluid flow signal, the energy calculation in the frequency band is done for DAS based on noise reduction, and the signal processing in the frequency band is done by the spectrum characteristics of the CO₂ wellbore signal. The translation invariant wavelet algorithm is the primary denoising method for DTS, overcoming the shortcomings of traditional wavelet threshold algorithms such as excessive smoothing and the pseudo-Gibbs phenomenon. Furthermore, the depth correction during the optical cable lowering process is also examined in this paper. A CO₂ gas injection well field experiment was conducted using this technology. A 1671m well was dug, and 1631m of optical cable were installed in the tubing. The tubing leakage position was successfully identified through gas injection, annulus pressure relief, and a comparison of DAS and DTS data. The field results demonstrate the accuracy with which the gas injection string integrity can be accurately monitored in real-time using distributed optical fiber sensing technology for CO₂ injection wells.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 166-177"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684815","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":"Determining the geomechanical units using rock physics methods","authors":"Layal Fadhil AL-Kaaby ,&nbsp;Sina Rashidi ,&nbsp;Reza Ghamarpoor ,&nbsp;Seyednooroldin Hosseini ,&nbsp;Hasan N. Al-Saedi ,&nbsp;Elias Ghaleh Golab","doi":"10.1016/j.ptlrs.2024.08.002","DOIUrl":"10.1016/j.ptlrs.2024.08.002","url":null,"abstract":"<div><div>The stability of the drilled wellbores in carbonate formations is of great importance. This paper is a new approach to determine the elastic properties of the wellbore based on rock physics methods using the Hashin-Shtrikman bounds to determine the wellbore stability. Initially, the static elastic parameters were determined by two different methods, namely the rock physics method and DSI log, followed by clustering through Multi-Resolutional Graph-Based clustering (MRGC) and calculating geomechanical-units (GMUs) of each method separately. The obtained results from DSI log and rock physic methods were then compared followed by determining the wellbore stability. The results showed that the correlation between shear and compressional wave velocity obtained from the petrophysical method with the measured values of shear and pressure wave velocity in the well was 0.94 and 0.90, respectively, which shows that the petrophysical method can estimate these two logs with high accuracy, and it can be a suitable alternative instead of using the Dipole Shear Sonic Imager (DSI). It was observed that the geomechanical units of elastic parameters calculated by proposed rock physics method are in good agreement with those obtained from DSI log. Rock-physic method can be a good alternative for when expensive DSI logs are missing.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 178-187"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684816","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":"Shale gas accumulation mechanism of deep-buried marine shale of Upper Ordovician Wufeng Formation to Lower Silurian Longmaxi Formation in the southeast Sichuan Basin","authors":"Zhujiang Liu ,&nbsp;Zhenxue Jiang ,&nbsp;Fubin Wei ,&nbsp;Tao Yuan ,&nbsp;Fei Li","doi":"10.1016/j.ptlrs.2024.07.006","DOIUrl":"10.1016/j.ptlrs.2024.07.006","url":null,"abstract":"<div><div>Deep shale gas has become an important frontier for future shale gas exploration and development. The Wufeng-Longmaxi formations in southern China have undergone complex tectonic and transformation through multi-stage tectonic movements. Deep shale gas enrichment conditions are complex, which greatly restricts the exploration and development of deep shale gas. In this study, based on systematic analysis of basic geological characteristics and gas reservoir characteristics of deep shales, the main factors controlling deep shale gas enrichment in southern China were investigated, and enrichment modes were established. The results show that high-quality shales were developed in the deep-water continental shelf facies, characterized by moderate thermal maturity, high silica content, and abundant organic matter. These characteristics provide a good basis for the formation and enrichment of shale gas. The deep shale gas reservoir is featured by overpressure, high porosity and high gas content. The development and maintenance of high porosity, favorable roof and floor sealing conditions, and weak tectonic activity during uplift stage are the main factors to control deep shale gas enrichment. Based on a comprehensive analysis, the enrichment modes of deep shale gas under three different tectonic patterns were established, namely overpressure enrichment within the basin, overpressure enrichment in the faulted nose or slope of the margin, and overpressure enrichment in the remnant syncline outside the basin. This study provides a reference for exploration and development of deep shale gas in Sichuan Basin and other areas.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 1","pages":"Pages 137-148"},"PeriodicalIF":0.0,"publicationDate":"2025-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143684778","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}