The objective of this work is to remove Vanadium V+5 ions from wastewater by batch adsorption utilizing Nano Graphene Oxide (NGO) since Vanadium presents a hazardous concern due to its effect on biological systems; According to the International Agency for Research on Cancer (IARC), vanadium V+5 ions are a potential human carcinogen. In the adsorption process, the effects of temperature (20-50)°C and initial concentration effect (100-800) mg L-1 were investigated. The adsorption isotherms were identified using a simulated aqueous solution of the V+5 ions and a kinetic and thermodynamic sorption analysis. Both the Langmuir and Freundlich isotherm models were used to fit the data. Due to the correlation coefficient (R2) of 0.999, analyses showed that the Adsorption of V+5 ions by NGO followed the Langmuir model. Kinetic models analyzed Intra Particle Diffusion, Pseudo First & Second Order Models revealed that an Intra-Particle Diffusion model was followed. Thermodynamically, The Adsorption processes were exothermic, random, and spontaneous, all shown by the negative values for Enthalpy ∆H, Entropy ∆S, and Gibbs free Energy ∆G.
{"title":"Mathematical Modeling Investigation of V+5 Ion Removal from Wastewater by Nanographene Oxide","authors":"H. Mh","doi":"10.23880/ppej-16000336","DOIUrl":"https://doi.org/10.23880/ppej-16000336","url":null,"abstract":"The objective of this work is to remove Vanadium V+5 ions from wastewater by batch adsorption utilizing Nano Graphene Oxide (NGO) since Vanadium presents a hazardous concern due to its effect on biological systems; According to the International Agency for Research on Cancer (IARC), vanadium V+5 ions are a potential human carcinogen. In the adsorption process, the effects of temperature (20-50)°C and initial concentration effect (100-800) mg L-1 were investigated. The adsorption isotherms were identified using a simulated aqueous solution of the V+5 ions and a kinetic and thermodynamic sorption analysis. Both the Langmuir and Freundlich isotherm models were used to fit the data. Due to the correlation coefficient (R2) of 0.999, analyses showed that the Adsorption of V+5 ions by NGO followed the Langmuir model. Kinetic models analyzed Intra Particle Diffusion, Pseudo First & Second Order Models revealed that an Intra-Particle Diffusion model was followed. Thermodynamically, The Adsorption processes were exothermic, random, and spontaneous, all shown by the negative values for Enthalpy ∆H, Entropy ∆S, and Gibbs free Energy ∆G.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"138 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132083268","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}
The world's hegemonic energy model is mostly based on the burning of fossil fuels. The heavy reliance on oil, coal, and natural gas for power generation as well as the pollution resulting from burning such fuels is a growing global concern. Biodiesel from the transesterification of vegetable oils is a promising alternative source for diesel engines. The ANP, National Agency of Petroleum, Natural Gas and Biofuels, regulates fuels in Brazil. In this work, soybean biodiesel was produced on a laboratory scale through an alkaline transesterification reaction. An analysis of the exegetic efficiency of the process, the physical-chemical characterization of biodiesel, and a brief discussion on the following parameters were carried out: higher and lower calorific value, water content, specific mass at 20°C, kinematic viscosity at 40°C, acidity index and oxidative stability, verifying the adequacy to the parameters of ANP Resolutions nº 45/2014 and nº 798/2019. Considering the exergetic efficiency of 63.42% and the physical-chemical characterization, despite the non-conformities in water content and oxidative stability, soybean biodiesel proved to be a satisfactory alternative for renewable fuel.
{"title":"Production, Characterization, and Exergy Analysis of the Soybean Biodiesel Produced by Laboratory Scale","authors":"Rios Mas","doi":"10.23880/ppej-16000328","DOIUrl":"https://doi.org/10.23880/ppej-16000328","url":null,"abstract":"The world's hegemonic energy model is mostly based on the burning of fossil fuels. The heavy reliance on oil, coal, and natural gas for power generation as well as the pollution resulting from burning such fuels is a growing global concern. Biodiesel from the transesterification of vegetable oils is a promising alternative source for diesel engines. The ANP, National Agency of Petroleum, Natural Gas and Biofuels, regulates fuels in Brazil. In this work, soybean biodiesel was produced on a laboratory scale through an alkaline transesterification reaction. An analysis of the exegetic efficiency of the process, the physical-chemical characterization of biodiesel, and a brief discussion on the following parameters were carried out: higher and lower calorific value, water content, specific mass at 20°C, kinematic viscosity at 40°C, acidity index and oxidative stability, verifying the adequacy to the parameters of ANP Resolutions nº 45/2014 and nº 798/2019. Considering the exergetic efficiency of 63.42% and the physical-chemical characterization, despite the non-conformities in water content and oxidative stability, soybean biodiesel proved to be a satisfactory alternative for renewable fuel.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"68 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116239105","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}
Accurate assessment of bed boundaries at a drill site is a crucial step for reservoir characterization. Generally, the interpreters in oil industries carry out such analysis through expensive softwares based on their experiences and geological knowledge in the study area. However, identifying bed boundaries using traditional interpretation is tedious. In this study, we adopted a synergistic approach of Walsh transform and a bed boundary demarcation technique to discriminate the lithological boundaries in Bhogpara oil field of Assam in NE India. This bed boundary detection technique was tested over self-potential (SP), gamma ray (GR) and laterolog deep resistivity (LLD) logs. Initially, we detected the possible lithological boundaries from GR log variations and hence proposed a lithological model as per the knowledge of traditional log interpretation techniques. Subsequently, Walsh low pass filter was applied to the self-potential (SP), GR and LLD logs to obtain their step function. Afterward, the step functions of logs were processed through the boundary detection algorithm to find out the possible thick and thin beds. Further, bed correlation was made among the Walsh-detected boundaries for the studied wells of the Bhogpara oil field. Finally, a bed boundary model was generated using the boundaries picked from the Walsh-based approach. Our analysis exhibit that the model generated from Walsh boundaries more explicitly envisaged the possible heterogeneity. Traditionally we discriminated the minimum bed thickness of the order of 5.15 m, whereas, from the Walsh-based approach we obtained thin bed of the order of 3.2 m. This proposed bed boundary assessment technique is also helpful in understanding the position of subsurface rock layers as well as possible thick and thin beds when we don’t have any pre-received core information.
{"title":"A Comparative Study on Appraisal of Lithological Boundaries and Litho-Models Using Well Log Data at Bhogpara Oil Field in Assam of NE India","authors":"","doi":"10.23880/ppej-16000335","DOIUrl":"https://doi.org/10.23880/ppej-16000335","url":null,"abstract":"Accurate assessment of bed boundaries at a drill site is a crucial step for reservoir characterization. Generally, the interpreters in oil industries carry out such analysis through expensive softwares based on their experiences and geological knowledge in the study area. However, identifying bed boundaries using traditional interpretation is tedious. In this study, we adopted a synergistic approach of Walsh transform and a bed boundary demarcation technique to discriminate the lithological boundaries in Bhogpara oil field of Assam in NE India. This bed boundary detection technique was tested over self-potential (SP), gamma ray (GR) and laterolog deep resistivity (LLD) logs. Initially, we detected the possible lithological boundaries from GR log variations and hence proposed a lithological model as per the knowledge of traditional log interpretation techniques. Subsequently, Walsh low pass filter was applied to the self-potential (SP), GR and LLD logs to obtain their step function. Afterward, the step functions of logs were processed through the boundary detection algorithm to find out the possible thick and thin beds. Further, bed correlation was made among the Walsh-detected boundaries for the studied wells of the Bhogpara oil field. Finally, a bed boundary model was generated using the boundaries picked from the Walsh-based approach. Our analysis exhibit that the model generated from Walsh boundaries more explicitly envisaged the possible heterogeneity. Traditionally we discriminated the minimum bed thickness of the order of 5.15 m, whereas, from the Walsh-based approach we obtained thin bed of the order of 3.2 m. This proposed bed boundary assessment technique is also helpful in understanding the position of subsurface rock layers as well as possible thick and thin beds when we don’t have any pre-received core information.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130404984","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}
This study examined the phenomena of free span for a pipe -in- pipe (PIP) system for pipeline application. Two different span length of 8 and 30 meters are modelled and simulated using nonlinear stress analysis. The effect of pressure, temperature and gravity on the PIP system are determined and compared with conventional single pipeline. From the results obtained, it is clear that the finite element analysis (FEA) results correlated very well with those calculated using analytical methods. Percentage differences were generally less than 10%, with some discrepancies which were due to assumption of thin-walled theory which assumes a radial stress equals to zero, whereas the FEA calculates a non- zero radial stress. The key finding in this study demonstrated the strong potentials of PIP system in terms of structural reliability for deepwater pipeline application. Specifically, the 30m single pipe in free span (with pressure and temperature) deflected 205.1mm, more than double the corresponding PIP. This knowledge can be beneficial to selection and design considerations for pipeline system responses to both the gravity, thermal and pressure loading as well as the potential failure modes that may results in a typical scenario. Various theoretical calculations of stresses are used to validate the finding in this study of the single pipe and PIP models for flat seabed and free span.
{"title":"Stress Analysis of Pipe-In-Pipe Systems under Free Span for Deep Water Pipeline Applications","authors":"Njuguna J","doi":"10.23880/ppej-16000325","DOIUrl":"https://doi.org/10.23880/ppej-16000325","url":null,"abstract":"This study examined the phenomena of free span for a pipe -in- pipe (PIP) system for pipeline application. Two different span length of 8 and 30 meters are modelled and simulated using nonlinear stress analysis. The effect of pressure, temperature and gravity on the PIP system are determined and compared with conventional single pipeline. From the results obtained, it is clear that the finite element analysis (FEA) results correlated very well with those calculated using analytical methods. Percentage differences were generally less than 10%, with some discrepancies which were due to assumption of thin-walled theory which assumes a radial stress equals to zero, whereas the FEA calculates a non- zero radial stress. The key finding in this study demonstrated the strong potentials of PIP system in terms of structural reliability for deepwater pipeline application. Specifically, the 30m single pipe in free span (with pressure and temperature) deflected 205.1mm, more than double the corresponding PIP. This knowledge can be beneficial to selection and design considerations for pipeline system responses to both the gravity, thermal and pressure loading as well as the potential failure modes that may results in a typical scenario. Various theoretical calculations of stresses are used to validate the finding in this study of the single pipe and PIP models for flat seabed and free span.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"33 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125021420","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}
The main objective of this article is to do a comprehensive sensitivity analysis so as to study the influence of rotational speeds on the drillstring and BHA vibrations in well ZB-290 of s-shape well profile. This study is an extention of our reseach work of drillstring vibrations that were previously implemented to identify, analyze and control the resulting vibration in Zubair field wells. This well (ZB-290) has been drilled in Zubair field. Furthermore, recorded time-based vibration data and the vibration logs of this well to perform this analysis. BHAs forces, stresses, displacements, torque, and moments have been successfully identified and analysed taking into account the change of drilling speed. Drilling performance and future well designs will be enhanced based on the previous and this work.
{"title":"Analyzing the Effects of Drillstring Speed on Bottom Hole Assembly Vibration in S-Shape Directional Wells: A Comprehensive Sensitivity Analysis","authors":"","doi":"10.23880/ppej-16000337","DOIUrl":"https://doi.org/10.23880/ppej-16000337","url":null,"abstract":"The main objective of this article is to do a comprehensive sensitivity analysis so as to study the influence of rotational speeds on the drillstring and BHA vibrations in well ZB-290 of s-shape well profile. This study is an extention of our reseach work of drillstring vibrations that were previously implemented to identify, analyze and control the resulting vibration in Zubair field wells. This well (ZB-290) has been drilled in Zubair field. Furthermore, recorded time-based vibration data and the vibration logs of this well to perform this analysis. BHAs forces, stresses, displacements, torque, and moments have been successfully identified and analysed taking into account the change of drilling speed. Drilling performance and future well designs will be enhanced based on the previous and this work.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131021803","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 the evaluation of petroleum, the true boiling point (TBP) curve stands out among the characterization analyzes, as it is fundamental to assist in decision making such as pricing, royalty payment and petroleum valuation. This is possible by defining the yields of petroleum derivatives obtained as a function of their true boiling points. Its obtainment can partially conducted by applying the ASTM D2892 methodology, for fractions with temperatures up to 673 kelvin. Requiring a minimum volume of 1200 mL of oil and an average time of 48 hours. The present work aims to evaluate the feasibility of applying micro-distillation in the construction of the TBP curve, with volume and time reduction using reference oil. For this, established experiments will conducted according to the application of experiment planning and their results will compared with the curve obtained under standard conditions by ASTM D2892. The variables studied were distillation column size, heating rate control and magnetic bar shape. As a result, two conditions provided adjustment to the validation curve across the entire length of the conventional TBP ASTM curve, with the possibility of using columns of different sizes, minimum sample volume of 700 mL and reduction of total time to 16 hours and 40 minutes.
{"title":"Evaluation of Micro-Distillation Methodology in Obtaining the Oil Distillation Curve Using Design of Experiments","authors":"Chrisman Ecan","doi":"10.23880/ppej-16000315","DOIUrl":"https://doi.org/10.23880/ppej-16000315","url":null,"abstract":"In the evaluation of petroleum, the true boiling point (TBP) curve stands out among the characterization analyzes, as it is fundamental to assist in decision making such as pricing, royalty payment and petroleum valuation. This is possible by defining the yields of petroleum derivatives obtained as a function of their true boiling points. Its obtainment can partially conducted by applying the ASTM D2892 methodology, for fractions with temperatures up to 673 kelvin. Requiring a minimum volume of 1200 mL of oil and an average time of 48 hours. The present work aims to evaluate the feasibility of applying micro-distillation in the construction of the TBP curve, with volume and time reduction using reference oil. For this, established experiments will conducted according to the application of experiment planning and their results will compared with the curve obtained under standard conditions by ASTM D2892. The variables studied were distillation column size, heating rate control and magnetic bar shape. As a result, two conditions provided adjustment to the validation curve across the entire length of the conventional TBP ASTM curve, with the possibility of using columns of different sizes, minimum sample volume of 700 mL and reduction of total time to 16 hours and 40 minutes.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127698587","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}
To meet the global exponential demand for crude oil, development of unconventional crude oil deposits is essential but the major limitation is seen in pipeline transportation, given its exceptionally high viscosity. Saudi Aramco is the world’s leading crude oil producer with a significant contribution of Arab Heavy crude oil in the total production mix. In this paper, we have measured the viscosities of both binary and ternary mixtures of this heavy oil crude for the first time, using toluene and natural gas condensate fluids over temperatures encountered in pipeline transportation. Our study shows that both binary and ternary systems show excellent viscosity reduction characteristics with increase in viscosity index with temperature. The degree of viscosity reduction shows polynomial trends with excellent fits that facilitated the determination of the wax appearance temperature using differential calculus approach. The range of experimental temperature in this study and the excellent viscosity reduction characteristics of the systems testify to the suitability of our experimental data for pipeline transportation planning
{"title":"Experimental Viscosity Data for Binary and Ternary Systems of Arab Heavy Crude Oil and Diluents","authors":"Miadonye A","doi":"10.23880/ppej-16000312","DOIUrl":"https://doi.org/10.23880/ppej-16000312","url":null,"abstract":"To meet the global exponential demand for crude oil, development of unconventional crude oil deposits is essential but the major limitation is seen in pipeline transportation, given its exceptionally high viscosity. Saudi Aramco is the world’s leading crude oil producer with a significant contribution of Arab Heavy crude oil in the total production mix. In this paper, we have measured the viscosities of both binary and ternary mixtures of this heavy oil crude for the first time, using toluene and natural gas condensate fluids over temperatures encountered in pipeline transportation. Our study shows that both binary and ternary systems show excellent viscosity reduction characteristics with increase in viscosity index with temperature. The degree of viscosity reduction shows polynomial trends with excellent fits that facilitated the determination of the wax appearance temperature using differential calculus approach. The range of experimental temperature in this study and the excellent viscosity reduction characteristics of the systems testify to the suitability of our experimental data for pipeline transportation planning","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"96 1-3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125981560","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}
The exploration and exploitation of the downthrown side of the productive upthrown Pre-rifting reservoirs at the Gulf of Suez marked bring a renaissance to the rift basin Exploration. This work documents the reservoir performance, trap geometry, and structural style of the downthrown deep marine stratigraphic entrapment. In addition, it outlines the requirements necessary beyond the production mitigations and limits. To gain better understanding of Asl Formation (deep marine) reservoir characteristics early in the exploration program, Asl Formation was cored in the north October J-5 well. A continuous 366- foot (112m) core was recovered including the main reservoir interval, which is producing over 12,000 barrel of oil per day. The J-5 Asl Formation has been interpreted as a synthetic, mixed clastic-carbonate turbidity deposit. Three major lithofacies described are recognizable on electric log. These are sandstone, shale and carbonates. The sandstones dominate the lower portion of the core and are the main oil producing section. Sandstone porosity and permeability range from 17 to 27% and 30 millidarcies to 3 darcies, respectively. Compared to the sandstone, the carbonate turbidites have poorer reservoir quality. They dominate the upper portion of the core and are composed of coarse fossil debris, silica framework grains and rock fragments. Horizontal and vertical permeabilities with rock types. Both the sandstone and carbonate sections of the J-5 core have experienced a complex diagenetic history. Deposition of the cored interval was initiated by a convulsive geological event such as flashflood or earthquake. These events would likely generate sufficient energy for mobilization of onshore and/or near shore sediments into multiple gravity flows having regional extent. The reservoir quality is controlled by a combination of primary depositional fabric and subsequent diagenetic modification. This research work can guide future exploration of reservoir-prone deep marine deposits in the Red Sea Rift and provide a reference for the subsurface deep-water reservoir quality analysis in the propagation stage in the Rift Basins.
{"title":"Reservoir Description, Diagenesis and Reservoir Quality of the Deep Marine Sediments in the Propagation Stage of Rift Basin","authors":"Kassem Aa","doi":"10.23880/ppej-16000316","DOIUrl":"https://doi.org/10.23880/ppej-16000316","url":null,"abstract":"The exploration and exploitation of the downthrown side of the productive upthrown Pre-rifting reservoirs at the Gulf of Suez marked bring a renaissance to the rift basin Exploration. This work documents the reservoir performance, trap geometry, and structural style of the downthrown deep marine stratigraphic entrapment. In addition, it outlines the requirements necessary beyond the production mitigations and limits. To gain better understanding of Asl Formation (deep marine) reservoir characteristics early in the exploration program, Asl Formation was cored in the north October J-5 well. A continuous 366- foot (112m) core was recovered including the main reservoir interval, which is producing over 12,000 barrel of oil per day. The J-5 Asl Formation has been interpreted as a synthetic, mixed clastic-carbonate turbidity deposit. Three major lithofacies described are recognizable on electric log. These are sandstone, shale and carbonates. The sandstones dominate the lower portion of the core and are the main oil producing section. Sandstone porosity and permeability range from 17 to 27% and 30 millidarcies to 3 darcies, respectively. Compared to the sandstone, the carbonate turbidites have poorer reservoir quality. They dominate the upper portion of the core and are composed of coarse fossil debris, silica framework grains and rock fragments. Horizontal and vertical permeabilities with rock types. Both the sandstone and carbonate sections of the J-5 core have experienced a complex diagenetic history. Deposition of the cored interval was initiated by a convulsive geological event such as flashflood or earthquake. These events would likely generate sufficient energy for mobilization of onshore and/or near shore sediments into multiple gravity flows having regional extent. The reservoir quality is controlled by a combination of primary depositional fabric and subsequent diagenetic modification. This research work can guide future exploration of reservoir-prone deep marine deposits in the Red Sea Rift and provide a reference for the subsurface deep-water reservoir quality analysis in the propagation stage in the Rift Basins.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132751286","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}
The paper presents the results of laboratory and field experiments on a developed polymer gel-forming composition “PSB” that enhances oil recovery. In this composition, two aqueous solutions are used: a polymeric gelling agent and an inorganic crosslinker. An alternating injection of solutions that are mixed directly in the reservoir allows a bulk gel to be formed that blocks water or gas breakthroughs. This leads to an increase in oil production, and a decrease in water cut, resulting in more efficient wells. On five wells in a hydrocarbon field that was located within the Permian-Carboniferous deposits, a series of field tests were conducted. It has been observed that wells treated with this developed polymer gel-forming composition “PSB” show a decrease in water cut, a decrease in liquid flow rates, and an increase in oil production. This technology led to an increase in oil flow rates of 5 tonnes per day per well (2 times) and a decrease in water cut of 10-40%, confirming its effectiveness. According to the values of the cumulative effect as of February 2016, this effect continues to increase oil production by 20-600 tons per well.
{"title":"Improvement of Oil Recovery in Hydrocarbon Fields by Developing Polymeric Gel-Forming Composition","authors":"AL-Obaidi Sh","doi":"10.23880/ppej-16000314","DOIUrl":"https://doi.org/10.23880/ppej-16000314","url":null,"abstract":"The paper presents the results of laboratory and field experiments on a developed polymer gel-forming composition “PSB” that enhances oil recovery. In this composition, two aqueous solutions are used: a polymeric gelling agent and an inorganic crosslinker. An alternating injection of solutions that are mixed directly in the reservoir allows a bulk gel to be formed that blocks water or gas breakthroughs. This leads to an increase in oil production, and a decrease in water cut, resulting in more efficient wells. On five wells in a hydrocarbon field that was located within the Permian-Carboniferous deposits, a series of field tests were conducted. It has been observed that wells treated with this developed polymer gel-forming composition “PSB” show a decrease in water cut, a decrease in liquid flow rates, and an increase in oil production. This technology led to an increase in oil flow rates of 5 tonnes per day per well (2 times) and a decrease in water cut of 10-40%, confirming its effectiveness. According to the values of the cumulative effect as of February 2016, this effect continues to increase oil production by 20-600 tons per well.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"64 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114570811","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 the oil and gas industry, there is a major challenge to accurately predict the crude oil production due to the complexity and sophistication of the subsurface conditions. Production forecasting is highly limited by the non-linearity between hydrocarbon production and any relevant petrophysical parameter. Trying to use just the conventional mathematical approaches might give inaccurate result because of the numerous assumptions employed by this approach. Therefore, there is a huge need to develop a reliable prediction model of hydrocarbon production. This will surely assist Petroleum Engineers to have a better understanding of the entire reservoir behavior to solve, evaluate, and optimize its overall performance. Utilizing data driven models which is the machine learning techniques can help to predict crude oil production with much more acceptable accuracy. In this paper, Python-Support Vector Regression and Orange-Linear Regression have been implemented to build the models that predict the daily oil production of a well in Bakken-Three Forks Formations. The statistical data for the Bakken-Three Forks formation oil production was from North Dakota Industrial Commission (NDIC) website. An open-source visual programmingbased data mining software Orange was used to train a multi-linear regression model of 817 datasets with addition of 200 lines of code algorithm written in Python which is a high-level programming language. Combination of these two software models gave a more robust and accurate predictions compared to the conventional method of using just a software model by others. The models developed can practically estimate the Daily oil production of a well in Bakken-Three Forks Formations. The R2 obtained is 0.98 from the low performance value of 0.35, the MAE became 10.593 and RMSE is 16.593 for SVR and linear regression with a cross validation of 10 folds for the 70% train dataset and 30 % test dataset shows MSE value of 2.826, RMSE of 1.681, MAE of 1.045 and R2 value of 0.998. The performance of this SVR model indicate that this developed model can be used to predict the Daily oil produced per well accurately with the supervised algorithm. The values obtained from the Orange-Linear regression show better performance when compared with the SVR and validates the values obtained from the Python Support Vector Regression from the model criteria evaluation of the results.
{"title":"The Bakken and Three Forks Formations Daily Crude Oil Production per Well Prediction Based on Support Vector Regression","authors":"Ebere F","doi":"10.23880/ppej-16000317","DOIUrl":"https://doi.org/10.23880/ppej-16000317","url":null,"abstract":"In the oil and gas industry, there is a major challenge to accurately predict the crude oil production due to the complexity and sophistication of the subsurface conditions. Production forecasting is highly limited by the non-linearity between hydrocarbon production and any relevant petrophysical parameter. Trying to use just the conventional mathematical approaches might give inaccurate result because of the numerous assumptions employed by this approach. Therefore, there is a huge need to develop a reliable prediction model of hydrocarbon production. This will surely assist Petroleum Engineers to have a better understanding of the entire reservoir behavior to solve, evaluate, and optimize its overall performance. Utilizing data driven models which is the machine learning techniques can help to predict crude oil production with much more acceptable accuracy. In this paper, Python-Support Vector Regression and Orange-Linear Regression have been implemented to build the models that predict the daily oil production of a well in Bakken-Three Forks Formations. The statistical data for the Bakken-Three Forks formation oil production was from North Dakota Industrial Commission (NDIC) website. An open-source visual programmingbased data mining software Orange was used to train a multi-linear regression model of 817 datasets with addition of 200 lines of code algorithm written in Python which is a high-level programming language. Combination of these two software models gave a more robust and accurate predictions compared to the conventional method of using just a software model by others. The models developed can practically estimate the Daily oil production of a well in Bakken-Three Forks Formations. The R2 obtained is 0.98 from the low performance value of 0.35, the MAE became 10.593 and RMSE is 16.593 for SVR and linear regression with a cross validation of 10 folds for the 70% train dataset and 30 % test dataset shows MSE value of 2.826, RMSE of 1.681, MAE of 1.045 and R2 value of 0.998. The performance of this SVR model indicate that this developed model can be used to predict the Daily oil produced per well accurately with the supervised algorithm. The values obtained from the Orange-Linear regression show better performance when compared with the SVR and validates the values obtained from the Python Support Vector Regression from the model criteria evaluation of the results.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131836794","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}
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