The effect of pipe length-to-diameter ratio (L/D) on air-water two phase slug flow regime development is hereby investigated. Axial velocity along the leading Taylor bubble and hydrodynamic entrance length required to establish a fully developed parabolic profile were critically assessed. The eccentricity distribution of axial velocity on leading Taylor bubble stream and on its nose is observed in all the L/D geometry ratios. The radial component of the axial velocity profile in the liquid film ahead of the leading Taylor bubble is represented by a power law function; with exponent n=6.1 for L/D=833.3 and n=5.7 for L/D=1666.7. Despite a decrease in the exponent as L/D ratio increases, the full parabolic profile could not be reached. This suggests that further investigation on L/D ratio incorporating other inherent variables which are likely to affect the development of the full parabolic profile may be required.
{"title":"Effect of length-to-diameter ratio on axial velocity and hydrodynamic entrance length in air-water twophase flow in vertical pipes","authors":"J. Chidamoio, Lateef T. Akanji, R. Rafati","doi":"10.30881/JOGPS.00003","DOIUrl":"https://doi.org/10.30881/JOGPS.00003","url":null,"abstract":"The effect of pipe length-to-diameter ratio (L/D) on air-water two phase slug flow regime development is hereby investigated. Axial velocity along the leading Taylor bubble and hydrodynamic entrance length required to establish a fully developed parabolic profile were critically assessed. The eccentricity distribution of axial velocity on leading Taylor bubble stream and on its nose is observed in all the L/D geometry ratios. The radial component of the axial velocity profile in the liquid film ahead of the leading Taylor bubble is represented by a power law function; with exponent n=6.1 for L/D=833.3 and n=5.7 for L/D=1666.7. Despite a decrease in the exponent as L/D ratio increases, the full parabolic profile could not be reached. This suggests that further investigation on L/D ratio incorporating other inherent variables which are likely to affect the development of the full parabolic profile may be required.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"39 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76574433","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}
Chemical absorption is the most common technology used in the Acid Gas Removal (AGR) systems for treating sour gases, but suffers from high regeneration energy and co-process produced water. Co-process produced water is often considered a waste by-product, but recently the industry is beginning to exploit it as a potential profit. In this study, a novel integrated AGR and Forward Osmosis (FO) regeneration system is proposed to reduce the energy consumption in both systems, as well as treating the wastewater from the AGR units. This process utilizes ethanol as a draw solution (DS) along with n-pentane as a low boiling point agent for facilitating the separation of ethanol-water mixture at low temperature. N-pentane is the cross component between the AGR & FO units, through a new economizer coolant fluid replacing the circulated lean amine conventional cooling equipment “air cooler and trim cooler”. This work has been developed using Aspen HYSYS V8.8 amine package along with CPA package for FO-DS regeneration. The results show that, this proposal could save 15% of new AGR plants capital cost (Capex) due to eliminating the lean amine air cooler, trim cooler, reduce electrical consumption by more than 20% for new and existing plants. The net capex savings for the new AGR unit is $9687/MMSCFD, while added capex for existing units is $6504/MMSCFD. In addition, a 93.6% by wt. diluted draw solution could be recovered as a treated water. This proposal is promising for retrofitting an existing AGR process and desalination (FO) units.
{"title":"Novel integrated acid gas removal and forward osmosis draw solution regeneration system for saving energy and water treatment","authors":"A. Amhamed, A. Abotaleb","doi":"10.30881/JOGPS.00017","DOIUrl":"https://doi.org/10.30881/JOGPS.00017","url":null,"abstract":"Chemical absorption is the most common technology used in the Acid Gas Removal (AGR) systems for treating sour gases, but suffers from high regeneration energy and co-process produced water. Co-process produced water is often considered a waste by-product, but recently the industry is beginning to exploit it as a potential profit. In this study, a novel integrated AGR and Forward Osmosis (FO) regeneration system is proposed to reduce the energy consumption in both systems, as well as treating the wastewater from the AGR units. This process utilizes ethanol as a draw solution (DS) along with n-pentane as a low boiling point agent for facilitating the separation of ethanol-water mixture at low temperature. N-pentane is the cross component between the AGR & FO units, through a new economizer coolant fluid replacing the circulated lean amine conventional cooling equipment “air cooler and trim cooler”. This work has been developed using Aspen HYSYS V8.8 amine package along with CPA package for FO-DS regeneration. The results show that, this proposal could save 15% of new AGR plants capital cost (Capex) due to eliminating the lean amine air cooler, trim cooler, reduce electrical consumption by more than 20% for new and existing plants. The net capex savings for the new AGR unit is $9687/MMSCFD, while added capex for existing units is $6504/MMSCFD. In addition, a 93.6% by wt. diluted draw solution could be recovered as a treated water. This proposal is promising for retrofitting an existing AGR process and desalination (FO) units.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"320 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76297113","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}
M. Hasanvand, M. Montazeri, Marzieh Salehzadeh, M. Amiri, Mohamad Fathinasab
Organic precipitations are highly sticky and hard if some asphaltenes are present. This causes a deposition problem to occur when thermodynamic conditions are suitable for sedimentation in a wide range of production processes. This range may start from the porous media around the oil well and continue to the production pipes. Asphaltene exists in many light and heavy oil reservoirs, which often causes problems in the process of crude oil production. Asphaltenes have up to hundreds of carbon molecules in its structure which will be precipitated as a result of natural pressure drop, temperature changes and oil composition changes. In natural depletion, the main cause of asphaltene precipitation is the reduction of pressure. Due to the process of oil production from the well, which is accompanied by simultaneous reduction of pressure and temperature, this molecule is deposited to the tube wall during three stages of precipitation, growth and deposition, and causes flow obstruction. The precipitated asphaltene generated in the process of oil production from the reservoir closes the well and transmission lines. In the process of exploitation, the chock valves, separators, and other equipment in the way are blocked and broken. In refineries and petrochemicals, the presence of even small amounts of asphaltene results in a significant drop in the efficiency of catalysts and other additives. Therefore, before the reactions are performed, attempts are made to remove as much of these materials as possible from oil. In this paper, scientific literature related to the chemical structure and thermodynamic behavior of the asphaltene molecule has been investigated in order to provide clear overviews of the asphaltene precipitation and deposition, and the processes that lead to its occurrence in the well. Then, the precipitation and deposition of asphaltene in the well column and its effective factors are investigated.
{"title":"A literature review of asphaltene entity, precipitation, and deposition, introducing recently models of deposition in the well column","authors":"M. Hasanvand, M. Montazeri, Marzieh Salehzadeh, M. Amiri, Mohamad Fathinasab","doi":"10.30881/JOGPS.00016","DOIUrl":"https://doi.org/10.30881/JOGPS.00016","url":null,"abstract":"Organic precipitations are highly sticky and hard if some asphaltenes are present. This causes a deposition problem to occur when thermodynamic conditions are suitable for sedimentation in a wide range of production processes. This range may start from the porous media around the oil well and continue to the production pipes. Asphaltene exists in many light and heavy oil reservoirs, which often causes problems in the process of crude oil production. Asphaltenes have up to hundreds of carbon molecules in its structure which will be precipitated as a result of natural pressure drop, temperature changes and oil composition changes. In natural depletion, the main cause of asphaltene precipitation is the reduction of pressure. Due to the process of oil production from the well, which is accompanied by simultaneous reduction of pressure and temperature, this molecule is deposited to the tube wall during three stages of precipitation, growth and deposition, and causes flow obstruction. The precipitated asphaltene generated in the process of oil production from the reservoir closes the well and transmission lines. In the process of exploitation, the chock valves, separators, and other equipment in the way are blocked and broken. In refineries and petrochemicals, the presence of even small amounts of asphaltene results in a significant drop in the efficiency of catalysts and other additives. Therefore, before the reactions are performed, attempts are made to remove as much of these materials as possible from oil. In this paper, scientific literature related to the chemical structure and thermodynamic behavior of the asphaltene molecule has been investigated in order to provide clear overviews of the asphaltene precipitation and deposition, and the processes that lead to its occurrence in the well. Then, the precipitation and deposition of asphaltene in the well column and its effective factors are investigated.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84979401","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}
Ultimate water cut (WCult) defines well’s maximum water production for uncontained oil pay with bottom-water. The WCult is important to determine if the reservoir development is economical. Since presently-used WCult formula derives from simplifying assumption ignoring the effect of non-radial inflow, the formula needs to be redefined. A new analytical formula of WCult is developed by considering the inflow of oil and water into separate completions at the top of oil-zone and aquifer respectively. Then the formula is verified using the design of 46 simulated experiments representing wide variety of reservoir-bottomwater systems. It was found out that the for light-oil reservoirs, the presently-used theoretical formula may significantly diverge from the proposed formula which closely matches the simulated data and is more physics driven. Hence the proposed formula should be preferred. However, for the viscous oil reservoirs, the presently used formula conforms to the proposed formula, which is also proved mathematically.
{"title":"A new analytical model of ultimate water cut for light oil reservoirs with bottom-wate","authors":"Samir Prasun, Sayantani Ghosh","doi":"10.30881/JOGPS.00015","DOIUrl":"https://doi.org/10.30881/JOGPS.00015","url":null,"abstract":"Ultimate water cut (WCult) defines well’s maximum water production for uncontained oil pay with bottom-water. The WCult is important to determine if the reservoir development is economical. Since presently-used WCult formula derives from simplifying assumption ignoring the effect of non-radial inflow, the formula needs to be redefined. A new analytical formula of WCult is developed by considering the inflow of oil and water into separate completions at the top of oil-zone and aquifer respectively. Then the formula is verified using the design of 46 simulated experiments representing wide variety of reservoir-bottomwater systems. It was found out that the for light-oil reservoirs, the presently-used theoretical formula may significantly diverge from the proposed formula which closely matches the simulated data and is more physics driven. Hence the proposed formula should be preferred. However, for the viscous oil reservoirs, the presently used formula conforms to the proposed formula, which is also proved mathematically.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"64 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78843632","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}
In China, heavy oil reservoirs face several production challenges: most of the heavy oil reservoirs have already been in the middle or last stage of steam stimulation, and the throughput effect has deteriorated significantly; even though steam flooding has been widely applied in shallow reservoir, steam flooding technology suitable for medium-deep reservoir is still in the experimental stage; meanwhile, for ultra-heavy oil reservoir, a rapid decline in production is observed by utilizing conventional steam injection. Therefore, it is necessary to develop new technologies to replace steam floodingin order to enhance oil recovery of heavy oil reservoirs. In-situ combustion has been proved as a relatively effective technology for heavy oil production. In recent years, several field tests have been conducted in Shengli, Liaohe and Xinjiang oil regions, and the results proved that the feasibility of in-situ combustion technology for heavy oil reservoirs in China. This review paper introducesadvantages, adaptability, and developments of in-situ combustion technology for heavy oil reservoirs in China.
{"title":"Application of In-situ combustion for heavy oil production in China: A Review","authors":"Jia Yao, Guiheng Li, Jinjin Wu","doi":"10.30881/JOGPS.00014","DOIUrl":"https://doi.org/10.30881/JOGPS.00014","url":null,"abstract":"In China, heavy oil reservoirs face several production challenges: most of the heavy oil reservoirs have already been in the middle or last stage of steam stimulation, and the throughput effect has deteriorated significantly; even though steam flooding has been widely applied in shallow reservoir, steam flooding technology suitable for medium-deep reservoir is still in the experimental stage; meanwhile, for ultra-heavy oil reservoir, a rapid decline in production is observed by utilizing conventional steam injection. Therefore, it is necessary to develop new technologies to replace steam floodingin order to enhance oil recovery of heavy oil reservoirs. In-situ combustion has been proved as a relatively effective technology for heavy oil production. In recent years, several field tests have been conducted in Shengli, Liaohe and Xinjiang oil regions, and the results proved that the feasibility of in-situ combustion technology for heavy oil reservoirs in China. This review paper introducesadvantages, adaptability, and developments of in-situ combustion technology for heavy oil reservoirs in China.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75450307","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}
Current demands for oil resources has led the industry to explore greater depths, affecting the operational variables under which the processes take place. On the other hand, plenty of studies in the literature have attempted to capture the flow behavior of oil via rheological models and the corresponding rheological parameters are well understood, however, results of practical interest for the drilling process have not been extensively examined. This merger is achieved by the work of Ahmad et al.1 which presents a comprehensive analysis on the dependence of rheological parameters on the major process variables, i.e., pressure and temperature. A water-based mud, “Glydrill,” is used, for that matter, as a model fluid and experiments are conducted to simulate the downhole conditions of the real process. Their work focuses on the effects of temperature and pressure on the properties of the mud, such as viscosity and yield strength. The authors ultimately present both the qualitative and quantitative effects of the process above variables to the rheological characteristics of the mud and conclude that the Bingham model can sufficiently describe the rheology of the material, especially in conditions of elevated temperature and pressure. In addition, the field of oil industry constantly meets new opportunities and thus it is necessary to evaluate the options available in terms of potential carefully. This kind of study has been conducted by Ideozu et al.2 regarding the Akani Oil field structures in Eastern Niger Delta, Nigeria. The authors scrutinize the reservoir properties and sealing potential of the aforementioned structures utilizing various tools, such as seismic profiles and petrochemical analyses. According to their study, the field has a unique morphology which adds to its complexity. They highlight both the virtues of the site in terms of exploitation potential owing to several characteristics while they showcase several unavoidable limitations. Moreover, the field of Petrochemical sciences has many unique traits and is constantly evolving in an attempt to pivot according to the ordains of breakthrough science and technological advancements. This is reflected in the work of Yao et al.3whose work involves the utilization of microfluidic devices for specific tasks. Advances in this field are expected to find future application to oil and gas related issues. Therefore, the significance of working on this subject can be well appreciated. The main focus of the authors’ study is the effect of the geometrical configuration of microfluidics devices, and more particularly the region of the nozzle, on the generation of droplets and, in general, the opportunities that arise regarding the fabrication of stable emulsions. The authors discuss the physics of the phenomenon with great attention and explain why this study is useful for simulating the events taking place in the reservoir.
{"title":"Commentary on Volume I-Issue II of the Journal of Oil, Gas and Petrochemical Sciences","authors":"Y. Dimakopoulos","doi":"10.30881/JOGPS.00013","DOIUrl":"https://doi.org/10.30881/JOGPS.00013","url":null,"abstract":"Current demands for oil resources has led the industry to explore greater depths, affecting the operational variables under which the processes take place. On the other hand, plenty of studies in the literature have attempted to capture the flow behavior of oil via rheological models and the corresponding rheological parameters are well understood, however, results of practical interest for the drilling process have not been extensively examined. This merger is achieved by the work of Ahmad et al.1 which presents a comprehensive analysis on the dependence of rheological parameters on the major process variables, i.e., pressure and temperature. A water-based mud, “Glydrill,” is used, for that matter, as a model fluid and experiments are conducted to simulate the downhole conditions of the real process. Their work focuses on the effects of temperature and pressure on the properties of the mud, such as viscosity and yield strength. The authors ultimately present both the qualitative and quantitative effects of the process above variables to the rheological characteristics of the mud and conclude that the Bingham model can sufficiently describe the rheology of the material, especially in conditions of elevated temperature and pressure. In addition, the field of oil industry constantly meets new opportunities and thus it is necessary to evaluate the options available in terms of potential carefully. This kind of study has been conducted by Ideozu et al.2 regarding the Akani Oil field structures in Eastern Niger Delta, Nigeria. The authors scrutinize the reservoir properties and sealing potential of the aforementioned structures utilizing various tools, such as seismic profiles and petrochemical analyses. According to their study, the field has a unique morphology which adds to its complexity. They highlight both the virtues of the site in terms of exploitation potential owing to several characteristics while they showcase several unavoidable limitations. Moreover, the field of Petrochemical sciences has many unique traits and is constantly evolving in an attempt to pivot according to the ordains of breakthrough science and technological advancements. This is reflected in the work of Yao et al.3whose work involves the utilization of microfluidic devices for specific tasks. Advances in this field are expected to find future application to oil and gas related issues. Therefore, the significance of working on this subject can be well appreciated. The main focus of the authors’ study is the effect of the geometrical configuration of microfluidics devices, and more particularly the region of the nozzle, on the generation of droplets and, in general, the opportunities that arise regarding the fabrication of stable emulsions. The authors discuss the physics of the phenomenon with great attention and explain why this study is useful for simulating the events taking place in the reservoir.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"64 2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-06-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88357056","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}
Pub Date : 2018-01-01Epub Date: 2018-03-26DOI: 10.30881/jogps.00009
Jia Yao, John Oakey
Microfluidic channel networks allow the control of flowing fluids within structures with length scales on the order of single or tens of micrometers (μm). This affords the opportunity to mix and separate fluids with fine precision and, in the case of immiscible multiphase flows, generate stable emulsions with well-controlled sizes and size distributions. It is generally well understood that emulsion droplet size can be regulated by carefully balancing capillary-associated parameters, such as relative fluid velocity, with the interfacial tension of the immiscible phases. Channel size and geometry, particularly that of the junction where fluids merge in microfluidic flow focusing (or "pinch flow") devices, has been shown to scale droplet size and bound the lower droplet size. Channel constrictions or "nozzles" are commonly employed to amplify the extensional flow at channel junctions, but their function has not been quantified and is, therefore, not well understood. This paper describes the use of geometry as a tunable parameter in microfluidic droplet generator design by focusing upon the effect of nozzle geometry (relative width, length and depth) upon droplet snap off behavior. Our results show that nozzle geometry can dramatically influence droplet size by shifting its snap-off position, an effect that can be anticipated by Raleigh-Plateau theory.
{"title":"Geometrically-mediated snap-off of water-in-oil emulsion droplets in microfluidic flow focusing devices.","authors":"Jia Yao, John Oakey","doi":"10.30881/jogps.00009","DOIUrl":"https://doi.org/10.30881/jogps.00009","url":null,"abstract":"<p><p>Microfluidic channel networks allow the control of flowing fluids within structures with length scales on the order of single or tens of micrometers (μm). This affords the opportunity to mix and separate fluids with fine precision and, in the case of immiscible multiphase flows, generate stable emulsions with well-controlled sizes and size distributions. It is generally well understood that emulsion droplet size can be regulated by carefully balancing capillary-associated parameters, such as relative fluid velocity, with the interfacial tension of the immiscible phases. Channel size and geometry, particularly that of the junction where fluids merge in microfluidic flow focusing (or \"pinch flow\") devices, has been shown to scale droplet size and bound the lower droplet size. Channel constrictions or \"nozzles\" are commonly employed to amplify the extensional flow at channel junctions, but their function has not been quantified and is, therefore, not well understood. This paper describes the use of geometry as a tunable parameter in microfluidic droplet generator design by focusing upon the effect of nozzle geometry (relative width, length and depth) upon droplet snap off behavior. Our results show that nozzle geometry can dramatically influence droplet size by shifting its snap-off position, an effect that can be anticipated by Raleigh-Plateau theory.</p>","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"1 2","pages":"42-46"},"PeriodicalIF":0.0,"publicationDate":"2018-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.ncbi.nlm.nih.gov/pmc/articles/PMC7453402/pdf/nihms-1032175.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"38326738","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}
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