This paper proposes an economical and profitable completion method capable of producing in two different reservoirs of a well named "X" (for confidential reasons) in a single descent. The data used are pressure, volume and temperature (PVT), reservoir properties, well architecture, and drilling data. To achieve the desired objective, it is necessary to make the selection of materials, the operating pressures and temperatures, the choice of the appropriate completion design, the installation procedure, the nodal analysis, and finally, the economic balance sheet. Two completions of well X are considered; known as the single string completion, and the dual completion. The oil production flow rate of the well X after the single string completion is 5964.11 STB/D and the cost of equipment used for the single string completion design are 137,500 $. The oil production flow rate of the well X after the dual completion is 5700 STB/D and the cost of equipment used for the double completion design is 147,600 $. The appropriate completion for well X is the single string completion because it is less expensive and performs better in terms of gain and oil flow rate produced. The results obtained are hydrogenated nitrile (HNBR) as a sealing element, 258°F and 5500 PSI as pressure and operating temperature for the design of the single string completion. And the most appropriate type of design is the annular tubing completion. In this field named "Y" (for confidential reasons), the design of single string completion is made with the tubing of 3-1/2", weight of 10.2 ppf, a range of 30 ft and a hydro trip sup of 3-1/2". The financial component shows a return on investment from one year eight months.
{"title":"Completion Design in Petroleum Well with Two Different Reservoirs","authors":"Kibanya Nn","doi":"10.23880/ppej-16000359","DOIUrl":"https://doi.org/10.23880/ppej-16000359","url":null,"abstract":"This paper proposes an economical and profitable completion method capable of producing in two different reservoirs of a well named \"X\" (for confidential reasons) in a single descent. The data used are pressure, volume and temperature (PVT), reservoir properties, well architecture, and drilling data. To achieve the desired objective, it is necessary to make the selection of materials, the operating pressures and temperatures, the choice of the appropriate completion design, the installation procedure, the nodal analysis, and finally, the economic balance sheet. Two completions of well X are considered; known as the single string completion, and the dual completion. The oil production flow rate of the well X after the single string completion is 5964.11 STB/D and the cost of equipment used for the single string completion design are 137,500 $. The oil production flow rate of the well X after the dual completion is 5700 STB/D and the cost of equipment used for the double completion design is 147,600 $. The appropriate completion for well X is the single string completion because it is less expensive and performs better in terms of gain and oil flow rate produced. The results obtained are hydrogenated nitrile (HNBR) as a sealing element, 258°F and 5500 PSI as pressure and operating temperature for the design of the single string completion. And the most appropriate type of design is the annular tubing completion. In this field named \"Y\" (for confidential reasons), the design of single string completion is made with the tubing of 3-1/2\", weight of 10.2 ppf, a range of 30 ft and a hydro trip sup of 3-1/2\". The financial component shows a return on investment from one year eight months.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-07-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139357044","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 current paper aims to examine these parameters for evaluating the reservoir quality Darian Formation situated in one of the South Pars hydrocarbon fields. Also, zoning of the Darian Formation sequence is conducted for this reservoir. The average petrophysical parameters calculated in the Darian Formation sequence, including shale volume, total porosity, and water saturation, are 0.21%, 20.91%, and 81.6%, respectively. Based on these values, the sequence of the Darian Formation is divided into eight different zones. Zone 4 showed the highest reservoir quality, with a depth of 2367 to 2384 meters and a porosity of 22.8%, has the highest porosity, lowest water saturation of 37.1%, and about zero Shale volume. Zone 1 showed the weakest reservoir quality, with a depth of 2337 to 2353 meters and a porosity of 13.6%, has the lowest porosity, water saturation was about 89.19%, and about 5% Shale volume. Furthermore, neutron-density, MID, and M-N cross plots combined lithology in the Darian Formation sequence for calcite, quartz, dolomite, and limestone, and low amounts of shale in the well are identified.
{"title":"Evaluating the Reservoir Quality of the Darian Formation Using Well Logs: A Case Study of One of the Offshore Oil Fields in the South Pars Oilfield","authors":"Riahi Ma","doi":"10.23880/ppej-16000360","DOIUrl":"https://doi.org/10.23880/ppej-16000360","url":null,"abstract":"The current paper aims to examine these parameters for evaluating the reservoir quality Darian Formation situated in one of the South Pars hydrocarbon fields. Also, zoning of the Darian Formation sequence is conducted for this reservoir. The average petrophysical parameters calculated in the Darian Formation sequence, including shale volume, total porosity, and water saturation, are 0.21%, 20.91%, and 81.6%, respectively. Based on these values, the sequence of the Darian Formation is divided into eight different zones. Zone 4 showed the highest reservoir quality, with a depth of 2367 to 2384 meters and a porosity of 22.8%, has the highest porosity, lowest water saturation of 37.1%, and about zero Shale volume. Zone 1 showed the weakest reservoir quality, with a depth of 2337 to 2353 meters and a porosity of 13.6%, has the lowest porosity, water saturation was about 89.19%, and about 5% Shale volume. Furthermore, neutron-density, MID, and M-N cross plots combined lithology in the Darian Formation sequence for calcite, quartz, dolomite, and limestone, and low amounts of shale in the well are identified.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"67 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-07-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139357151","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 report reviews the progress in Enhanced Oil Recovery (EOR) through surfactant injection over the past half century from 1974, with a specific focus on the role of the multivariable Hydrophilic-Lipophilic Deviation (HLD) formulation equation in different expressions. This equation has been instrumental in optimizing surfactant formulations for EOR, enabling the fine-tuning of surfactant types and properties to match specific reservoir conditions like brine salinity, crude characteristic, temperature and even pressure. This short assesment discusses the evolution of surfactant types, and their impact on EOR efficiency for a given reservoir specifications. It highlights the role of intramolecular and intermolecular mixing in surfactant performance, and the benefits of using a multivariable HLD equation to predict and optimize the injected formulation. Furthermore, it explores the challenges and solutions related to surfactant adsorption, aggregation, precipitation, and effect on phase behavior and interfacial tension, and how these factors have to be considered when using surfactants for EOR projects. This review aims to address the existing gaps in the literature, such as the complex effects of surfactant mixtures with insensitivity to temperature and injected composition (amphiphilic concentration and water/oil ratio) that make difficult to propose a unified approach for different petroleum reservoirs. It concludes a discussion on the state of the art and future of surfactant EOR, emphasizing the need for continued research and collaboration across academic and industrial sectors
{"title":"Enhanced Oil Recovery by Surfactant Injection was improved during the Last 50 Years Thanks to the Multivariable HLD Formulation Equation","authors":"Salager Jl","doi":"10.23880/ppej-16000356","DOIUrl":"https://doi.org/10.23880/ppej-16000356","url":null,"abstract":"This report reviews the progress in Enhanced Oil Recovery (EOR) through surfactant injection over the past half century from 1974, with a specific focus on the role of the multivariable Hydrophilic-Lipophilic Deviation (HLD) formulation equation in different expressions. This equation has been instrumental in optimizing surfactant formulations for EOR, enabling the fine-tuning of surfactant types and properties to match specific reservoir conditions like brine salinity, crude characteristic, temperature and even pressure. This short assesment discusses the evolution of surfactant types, and their impact on EOR efficiency for a given reservoir specifications. It highlights the role of intramolecular and intermolecular mixing in surfactant performance, and the benefits of using a multivariable HLD equation to predict and optimize the injected formulation. Furthermore, it explores the challenges and solutions related to surfactant adsorption, aggregation, precipitation, and effect on phase behavior and interfacial tension, and how these factors have to be considered when using surfactants for EOR projects. This review aims to address the existing gaps in the literature, such as the complex effects of surfactant mixtures with insensitivity to temperature and injected composition (amphiphilic concentration and water/oil ratio) that make difficult to propose a unified approach for different petroleum reservoirs. It concludes a discussion on the state of the art and future of surfactant EOR, emphasizing the need for continued research and collaboration across academic and industrial sectors","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127186896","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 research was to evaluate by using the advanced oxidative process (AOP), a toxic compound, such as an initial hydroquinone concentration (C0) of 500 mg L-1 in a batch reactor. At this stage of the work, an optimization method was performed to obtain mineralization of the total organic carbon (TOC). Furthermore, hydrogen peroxide was used as a source of free hydroxyl radicals (•OH). First, a factorial planning 22 was carried out with the two most significant variables, and two levels were used for the variables (pH and RH). Second, a rotational central composite design (RCCD) was used to investigate the optimal point corresponding to the maximum mineralization of hydroquinone (HQ) and the variables used in the model were pH and RH. Third, the optimal point of HQ mineralization was obtained carried for the desirability function, ranging from 0.0 (very undesirable) to 1.0 (very desirable). Fourth, artificial neural networks (ANNs) was used and the values included in the experiment were time (t), initial hydrogen potential (pH), temperature of the liquid effluent (T), air flow supply (QAF), and the mole ratio of hydroquinone/hydrogen peroxide (RH). The optimal conditions for a TOC conversion, (>80%) were identified. Modeling using artificial neural networks (ANNs) was used to predict the TOC conversion as a function of time. The values of the correlation coefficients (R2) for agreement between the ANN predictions and the experimental results were approximately 0.97, indicating that the model was satisfactory. These techniques have shown to be very promising in the prediction of the degradation and mineralization of contaminants. Thus, the process modeling data by ANN, allowed to carry out a treatment of organic liquid effluents in vertical reactors installed on offshore platforms and then to release this treated water into the oceans, after the complete degradation of hydroquinone and the highest TOC conversion. Therefore, seas pollution caused by the exploration on offshore platforms of oil and natural gas, the main sources of obtaining energy in the planet, tends to be minimized, providing a more sustainable energy generation.
{"title":"Advanced Oxidative Process for Treatment of Effluents with Hydroquinone in a Batch Reactor: Optimization/Modelling Technique by Response Surface Methodology and Artificial Neural Networks","authors":"Brandão Yb","doi":"10.23880/ppej-16000358","DOIUrl":"https://doi.org/10.23880/ppej-16000358","url":null,"abstract":"The main objective of this research was to evaluate by using the advanced oxidative process (AOP), a toxic compound, such as an initial hydroquinone concentration (C0) of 500 mg L-1 in a batch reactor. At this stage of the work, an optimization method was performed to obtain mineralization of the total organic carbon (TOC). Furthermore, hydrogen peroxide was used as a source of free hydroxyl radicals (•OH). First, a factorial planning 22 was carried out with the two most significant variables, and two levels were used for the variables (pH and RH). Second, a rotational central composite design (RCCD) was used to investigate the optimal point corresponding to the maximum mineralization of hydroquinone (HQ) and the variables used in the model were pH and RH. Third, the optimal point of HQ mineralization was obtained carried for the desirability function, ranging from 0.0 (very undesirable) to 1.0 (very desirable). Fourth, artificial neural networks (ANNs) was used and the values included in the experiment were time (t), initial hydrogen potential (pH), temperature of the liquid effluent (T), air flow supply (QAF), and the mole ratio of hydroquinone/hydrogen peroxide (RH). The optimal conditions for a TOC conversion, (>80%) were identified. Modeling using artificial neural networks (ANNs) was used to predict the TOC conversion as a function of time. The values of the correlation coefficients (R2) for agreement between the ANN predictions and the experimental results were approximately 0.97, indicating that the model was satisfactory. These techniques have shown to be very promising in the prediction of the degradation and mineralization of contaminants. Thus, the process modeling data by ANN, allowed to carry out a treatment of organic liquid effluents in vertical reactors installed on offshore platforms and then to release this treated water into the oceans, after the complete degradation of hydroquinone and the highest TOC conversion. Therefore, seas pollution caused by the exploration on offshore platforms of oil and natural gas, the main sources of obtaining energy in the planet, tends to be minimized, providing a more sustainable energy generation.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"38 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-07-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139357108","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}
With a geological and dynamic model of the hydrocarbon field, adapted to historical exploitation data, petroleum engineers can gain invaluable insights into the current situation and evaluate proposed solutions with great effectiveness. This resource is highly beneficial, providing invaluable insights that can result in favourable results. Therefore, in order to obtain reliable results, it is very important to build a reservoir model, taking into account their geological features. One of these features can be considered anisotropy of permeability. This is very important when it comes to low porosity and permeability reservoirs, which oil and gas companies are actively developing. The goal of this study was to assess how permeability anisotropy impacts the performance of a hydrodynamic model for a productive reservoir in an oil field. This study involves creating a field model and performing hydrodynamic calculations. This includes using field data to determine a close-to-real value for permeability anisotropy, optimizing an existing development system, and analyzing development maps. As a result of the study, it was found that the omission of permeability anisotropy leads to an overestimation of the accumulated field development indicators. It was found that an increase in the value of anisotropy does not always lead to an increase in cumulative oil production, which undoubtedly emphasizes the peculiarity of the geological structure of the reservoir. In the final stage, a hydrodynamic calculation of the development was performed for 15 years, allowing conclusions to be reached about the correctness of applying operations to enhance oil recovery (EOR).
{"title":"The Influence of Permeability Anisotropy on Reservoir Simulation Model Behaviour in Oil Fields","authors":"Kamensky Ip","doi":"10.23880/ppej-16000357","DOIUrl":"https://doi.org/10.23880/ppej-16000357","url":null,"abstract":"With a geological and dynamic model of the hydrocarbon field, adapted to historical exploitation data, petroleum engineers can gain invaluable insights into the current situation and evaluate proposed solutions with great effectiveness. This resource is highly beneficial, providing invaluable insights that can result in favourable results. Therefore, in order to obtain reliable results, it is very important to build a reservoir model, taking into account their geological features. One of these features can be considered anisotropy of permeability. This is very important when it comes to low porosity and permeability reservoirs, which oil and gas companies are actively developing. The goal of this study was to assess how permeability anisotropy impacts the performance of a hydrodynamic model for a productive reservoir in an oil field. This study involves creating a field model and performing hydrodynamic calculations. This includes using field data to determine a close-to-real value for permeability anisotropy, optimizing an existing development system, and analyzing development maps. As a result of the study, it was found that the omission of permeability anisotropy leads to an overestimation of the accumulated field development indicators. It was found that an increase in the value of anisotropy does not always lead to an increase in cumulative oil production, which undoubtedly emphasizes the peculiarity of the geological structure of the reservoir. In the final stage, a hydrodynamic calculation of the development was performed for 15 years, allowing conclusions to be reached about the correctness of applying operations to enhance oil recovery (EOR).","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"56 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-07-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139357236","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}
Anthropogenic CO2 emissions rapidly increased during the post-industrial revolution causing global warming issues. In order to reduce the CO2 concentration in the atmosphere Carbon Capture and Sequestration will play a key transition role to transform into clean energy by utilizing the existing oil and gas infrastructure and subsurface data. The technology comes with certain challenges, amongst them, one of the real threats is the stored CO2 leakage back into the atmosphere and at shallower surfaces. This work talks about the understanding of geomechanical risks involved in the CCS process and probable ideas to mitigate the risks. CO2 injection leads to an increase in the pressure within the pores which eventually results in a change of stress and strain conditions within the reservoir. With a proper understanding of the reservoir and with a realistic field dataset a controlled injection can avoid a formation leading to geomechanical failures. Often field data are insufficient, in such a scenario this works talks about the preventive measures that can be adopted to avoid early mentioned calamity
{"title":"Role and Advancements in Geomechanical Challenges in Carbon Capture and Sequestration","authors":"B. T.","doi":"10.23880/ppej-16000348","DOIUrl":"https://doi.org/10.23880/ppej-16000348","url":null,"abstract":"Anthropogenic CO2 emissions rapidly increased during the post-industrial revolution causing global warming issues. In order to reduce the CO2 concentration in the atmosphere Carbon Capture and Sequestration will play a key transition role to transform into clean energy by utilizing the existing oil and gas infrastructure and subsurface data. The technology comes with certain challenges, amongst them, one of the real threats is the stored CO2 leakage back into the atmosphere and at shallower surfaces. This work talks about the understanding of geomechanical risks involved in the CCS process and probable ideas to mitigate the risks. CO2 injection leads to an increase in the pressure within the pores which eventually results in a change of stress and strain conditions within the reservoir. With a proper understanding of the reservoir and with a realistic field dataset a controlled injection can avoid a formation leading to geomechanical failures. Often field data are insufficient, in such a scenario this works talks about the preventive measures that can be adopted to avoid early mentioned calamity","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126204022","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 this study, a wet proof multiple air cathode microbial fuel cell that generates bioelectricity by biodegradation of organic matter was fabricated. In this, platinum coated (0.5 mg/cm2) carbon cloth was used as air cathode and graphite rod was used as anode. The maximum power produced by MFC was 1.65042, 0.66951, 0.425061 mW on the 2nd day of operation with 1K, 3K, 5K ohm external resistance respectively. The maximum open circuit voltage and current given by MFC was 1.557 mV and 1.06 mA respectively incorporated with 1 K ohm external resistance. It was seen that open circuit voltage (OCV) initially increases with time due to increase in microbial activity but after that there is drop in voltage possibly due to decline of available substrate for microbial population. Maximum bacterial count of 90 ×105 CFU was observed on the 3rd day of operation.
{"title":"Bioelectricity Generation by Single Chamber Microbial Fuel Cell by Using Platinum Catalyst as Electrode","authors":"Nawaz A","doi":"10.23880/ppej-16000344","DOIUrl":"https://doi.org/10.23880/ppej-16000344","url":null,"abstract":"In this study, a wet proof multiple air cathode microbial fuel cell that generates bioelectricity by biodegradation of organic matter was fabricated. In this, platinum coated (0.5 mg/cm2) carbon cloth was used as air cathode and graphite rod was used as anode. The maximum power produced by MFC was 1.65042, 0.66951, 0.425061 mW on the 2nd day of operation with 1K, 3K, 5K ohm external resistance respectively. The maximum open circuit voltage and current given by MFC was 1.557 mV and 1.06 mA respectively incorporated with 1 K ohm external resistance. It was seen that open circuit voltage (OCV) initially increases with time due to increase in microbial activity but after that there is drop in voltage possibly due to decline of available substrate for microbial population. Maximum bacterial count of 90 ×105 CFU was observed on the 3rd day of operation.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133257159","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 oil and gas industry faces significant challenges when simulating fractured reservoirs. With the rising cost of hydrocarbons, there is a growing interest in exploiting unconventional reservoirs using hydraulic fracturing technologies. However, unconventional reservoirs typically contain fractured systems at various scales, ranging from nano to kilometer, making it difficult to simulate and predict these reservoirs accurately. Therefore, a rapid and precise method is crucial for this purpose. This paper presents a comprehensive review of the Embedded Discrete Fracture Model (EDFM), a novel approach designed for this purpose. This work begins by reviewing and comparing common methods for simulating naturally and hydraulically fractured reservoirs with EDFM, considering each method's advantages and disadvantages. The concept and formulation of EDFM are then discussed, focusing on adding mass balance equations and making them compatible with reservoir simulators. Additionally, this paper considers the concept and application of non-neighboring connections, which are crucial in simulating fractured reservoirs using EDFM models. This work also highlights the importance of considering changes in the EDFM formulation and simulation when fractures are treated as dynamic systems; failure to do so can lead to significant errors that deviate from actual results. Finally, the disadvantages of EDFM and proposed solutions for enhancing this method are discussed.
{"title":"Review of Embedded Discrete Fracture Models: Concepts, Simulation and Pros & Cons","authors":"Rostami S","doi":"10.23880/ppej-16000350","DOIUrl":"https://doi.org/10.23880/ppej-16000350","url":null,"abstract":"The oil and gas industry faces significant challenges when simulating fractured reservoirs. With the rising cost of hydrocarbons, there is a growing interest in exploiting unconventional reservoirs using hydraulic fracturing technologies. However, unconventional reservoirs typically contain fractured systems at various scales, ranging from nano to kilometer, making it difficult to simulate and predict these reservoirs accurately. Therefore, a rapid and precise method is crucial for this purpose. This paper presents a comprehensive review of the Embedded Discrete Fracture Model (EDFM), a novel approach designed for this purpose. This work begins by reviewing and comparing common methods for simulating naturally and hydraulically fractured reservoirs with EDFM, considering each method's advantages and disadvantages. The concept and formulation of EDFM are then discussed, focusing on adding mass balance equations and making them compatible with reservoir simulators. Additionally, this paper considers the concept and application of non-neighboring connections, which are crucial in simulating fractured reservoirs using EDFM models. This work also highlights the importance of considering changes in the EDFM formulation and simulation when fractures are treated as dynamic systems; failure to do so can lead to significant errors that deviate from actual results. Finally, the disadvantages of EDFM and proposed solutions for enhancing this method are discussed.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"12 4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123679175","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 present study, nanoparticles of chitosan-cetyltrimethylammonium bromide (CTAB)-sodium bentonite clay were synthesized and characterized using EDX, SEM, FTIR, XRF and XRD techniques. The composite material was utilized as adsorbent for the treatment of contaminated aqueous solution containing naphthalene. The adsorption process was modeled and optimized using artificial neural network (ANN) and ANN–genetic algorithm respectively. The process variables considered were surfactant concentration, X1 , activation time, X 2 , activation temperature, X3 , and chitosan dosage, X4 . The predicted ANN models for % removal of naphthalene and adsorption capacity of the composite adsorbent fitted excellently the experimental adsorption data of naphthalene judging from high value of coefficient of determination, 2 R , amongst others and very low values of error functions. The optimum conditions obtained with ANN–GA were X1 = 70.7580 mg/L, X 2 = 2.9940 h, X3 = 99.9880o C, and X 4 = 2.0340 g. The predicted response variables of 99.1461% removal of naphthalene and 249.67 mg/g adsorption capacity of the composite adsorbent using the ANN-GA models were in excellent agreement with their corresponding experimental values of 99.35% and 250.16 mg/g with % errors of 0.2056 and 0.1960 respectively. Consequently, the ANN models and the ANN–GA optimized conditions can be reliably applied to the experimental adsorption data of naphthalene on the chitosan–CTAB–sodium bentonite clay composite nanoparticles as adsorbent. Moreover, the prepared adsorbent in this study is a viable alternative adsorbent for the treatment of industrial wastewater containing polycyclic aromatic compounds, especially naphthalene.
{"title":"ANN Optimization of Adsorption of Naphthalene on Composite Nanoparticles of Chitosan-CTAB-Sodium Bentonite Clay","authors":"Olafadehan Oa","doi":"10.23880/ppej-16000354","DOIUrl":"https://doi.org/10.23880/ppej-16000354","url":null,"abstract":"In the present study, nanoparticles of chitosan-cetyltrimethylammonium bromide (CTAB)-sodium bentonite clay were synthesized and characterized using EDX, SEM, FTIR, XRF and XRD techniques. The composite material was utilized as adsorbent for the treatment of contaminated aqueous solution containing naphthalene. The adsorption process was modeled and optimized using artificial neural network (ANN) and ANN–genetic algorithm respectively. The process variables considered were surfactant concentration, X1 , activation time, X 2 , activation temperature, X3 , and chitosan dosage, X4 . The predicted ANN models for % removal of naphthalene and adsorption capacity of the composite adsorbent fitted excellently the experimental adsorption data of naphthalene judging from high value of coefficient of determination, 2 R , amongst others and very low values of error functions. The optimum conditions obtained with ANN–GA were X1 = 70.7580 mg/L, X 2 = 2.9940 h, X3 = 99.9880o C, and X 4 = 2.0340 g. The predicted response variables of 99.1461% removal of naphthalene and 249.67 mg/g adsorption capacity of the composite adsorbent using the ANN-GA models were in excellent agreement with their corresponding experimental values of 99.35% and 250.16 mg/g with % errors of 0.2056 and 0.1960 respectively. Consequently, the ANN models and the ANN–GA optimized conditions can be reliably applied to the experimental adsorption data of naphthalene on the chitosan–CTAB–sodium bentonite clay composite nanoparticles as adsorbent. Moreover, the prepared adsorbent in this study is a viable alternative adsorbent for the treatment of industrial wastewater containing polycyclic aromatic compounds, especially naphthalene.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132122974","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}
Seawater injection is a novel emerging technology for enhancing oil recovery in Middle East carbonate reservoirs. This paper investigated the mechanism of seawater injection in Mishrif formation for the West Qurna-1 oil field. The decline in the pressure of West Qurna-1 needs pressure support by water injection, where it is a supergiant oil field. This study is significant because seawater injection technology is considered a future technology in the south of Iraq for several reasons. One of these reasons is the scarcity of fresh water in the Middle East, especially in Iraq, and the second reason is the availability of seawater, which is close to Basra city. This paper aims to study the essential parameters that influence the oil recovery via sweater injection as well as the inherent mechanisms that help increase the oil recovery. Collected five core plugs from producing units of Mishrif formation, MB1, and MB2, having different petrophysics properties where the permeabilities ranged from 6 to 143 md. Two types of water are used formation water and seawater. We conduct core flood experiments on chosen carbonate core samples and formation water from Iraq's West Quran-1 carbonates. The common belief facts that low salinity flooding of oil recovery gives more producing oil for the same volume of water injected due to wettability alteration. The analysis of injected and producing water indicates that higher concentrations of SO4-2 and Ca-2 ions change the wettability of the rock to more water-wet. Consequently, the oil recovery increases by 10-15 % when using seawater, which is richer in these ions.
{"title":"Enhancement of Oil Recovery in West Qurna-1 Carbonate Reservoir by Injecting Seawater","authors":"Radhi A","doi":"10.23880/ppej-16000353","DOIUrl":"https://doi.org/10.23880/ppej-16000353","url":null,"abstract":"Seawater injection is a novel emerging technology for enhancing oil recovery in Middle East carbonate reservoirs. This paper investigated the mechanism of seawater injection in Mishrif formation for the West Qurna-1 oil field. The decline in the pressure of West Qurna-1 needs pressure support by water injection, where it is a supergiant oil field. This study is significant because seawater injection technology is considered a future technology in the south of Iraq for several reasons. One of these reasons is the scarcity of fresh water in the Middle East, especially in Iraq, and the second reason is the availability of seawater, which is close to Basra city. This paper aims to study the essential parameters that influence the oil recovery via sweater injection as well as the inherent mechanisms that help increase the oil recovery. Collected five core plugs from producing units of Mishrif formation, MB1, and MB2, having different petrophysics properties where the permeabilities ranged from 6 to 143 md. Two types of water are used formation water and seawater. We conduct core flood experiments on chosen carbonate core samples and formation water from Iraq's West Quran-1 carbonates. The common belief facts that low salinity flooding of oil recovery gives more producing oil for the same volume of water injected due to wettability alteration. The analysis of injected and producing water indicates that higher concentrations of SO4-2 and Ca-2 ions change the wettability of the rock to more water-wet. Consequently, the oil recovery increases by 10-15 % when using seawater, which is richer in these ions.","PeriodicalId":282073,"journal":{"name":"Petroleum & Petrochemical Engineering Journal","volume":"128 2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124309922","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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