Petroleum Engineering
Mostafa Jafari; Mohammad shahab Deljoo; Ali Vatani
Abstract
Today, one of the challenging issues all over the world is the appropriate use of flare gases in oil, gas, and petrochemical industries. Burning flare gases having high heating value results in economic losses and the pollution of the environment. There are several methods to use flare gases; the heat ...
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Today, one of the challenging issues all over the world is the appropriate use of flare gases in oil, gas, and petrochemical industries. Burning flare gases having high heating value results in economic losses and the pollution of the environment. There are several methods to use flare gases; the heat and power generation, the production of valuable fuels, or the separation of more precious components are examples of these methods. In this study, a polygeneration system is designed and simulated for the coproduction of power, steam, methanol, H2, and CO2 from the flare gases in South Pars and Assaluyeh gas fields. The polygeneration system has advantages such as reducing greenhouse gases and the coproduction and sales of energy-related products. The polygeneration system for converting flare gases to energy and various products includes an acid gas removal unit, a synthesis gas production unit, a methanol synthesis unit, a hydrogen purification unit, a combined heat and power generation unit, and a CO2 capture unit. The purpose of this study is to conduct an economic evaluation of the polygeneration system and obtain the total capital cost, the operating profit, and the payback period of this process. The simulation results show that using 9690 kg/h of flare gases produces 8133 kg/h methanol, 653.7 kg/h hydrogen, 46950 kg/h nitrogen, 9103 kg/h CO2, 109850 kg/h medium-pressure steam, and 3.7 MW power. The economic evaluation results show that in the polygeneration system, the total raw material cost and the total utilities consumption cost are $193.8 and $1859.5 per hour respectively, and the total product sales and the total utility sales are $12941.8 and $2243.5 per hour respectively; also, the operating profit is $13132 per hour. Also, the equipment cost, the installation cost, the total capital cost, and the total operating cost are $29.7 million per year, $39.2 million per year, $71 million per year, and $27.9 million per year respectively; finally, the payback period is 1.5 years.
Electrical Engineering – Control
Karim Salahshoor; Seyed morteza Hoseini
Abstract
The model-based optimization of the waterflooding process has found significant scope for improving the economic life-cycle performance of oil fields due to geological and economic uncertainties compared to conventional reactive strategies. This paper proposes a new frequency-based system identification ...
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The model-based optimization of the waterflooding process has found significant scope for improving the economic life-cycle performance of oil fields due to geological and economic uncertainties compared to conventional reactive strategies. This paper proposes a new frequency-based system identification method to identify a robust multi-input, multi-output (MIMO) surrogate model for an oil reservoir under waterflooding process so as to describe all the injector-producer relationships. In contrast to the conventional modeling methods, the proposed data-driven modeling approach uses the available injection and production rates as the reservoir input–output data. Meanwhile, it includes a structured-bounded uncertainty model in the form of norm-bounded state-space function blocks to account for uncertainties, facilitating the identified model employed in robust control methodology using linear matrix inequality (LMI) problem formulation so as to eliminate the effect of model uncertainty. The identified MIMO surrogate model is integrated with a desired nonlinear net present value (NPV) objective function in a multi-input, single-output (MISO) system configuration to synthesize a model-based optimization prediction for economical operation and production of oil from oil reservoirs under both geological and economic uncertainties. The introduced approach is implemented on the “EGG model” as a well-recognized three-dimensional synthetic oil reservoir with eight water injection wells and four oil production wells. The results demonstrate that economic performance prediction of the oil reservoir, having an uncertain permeability field, lies in the evaluated bound of the uncertainty model. Waterflooding is a well-known method for increasing oil production. A significant amount of time and effort is required even for high-performance processors to numerically simulate a reservoir with thousands of grid blocks. On the other hand, there is a high uncertainty level in oil reservoir model-based economic optimization due to limited information about geological model parameters. Employing robust control methods can provide robustness for the performance and stability of the control system against model norm-bounded uncertainty. However, in all standard identification methods, it is assumed that the uncertainties in the model can be accommodated in the form of noise. Therefore, the challenge of using the models estimated from the standard identification approach in robust control methods can mainly be considered an essential subject. This paper presents a new frequency-based modeling approach to identify a surrogate model and uncertainty modeling for the waterflooding process with the ease of being employed in robust control methods. A desirable relationship is obtained between the injection rate and the economic production function to model the dynamics of the reservoir using the identification of the surrogate model. Then, the concept of structure bounded uncertainty modeling is presented to describe the model geological uncertainty.
Petroleum Engineering
Hessam MansouriSiahgoli; Mohammad Ali Riahi; Bahare Heidari; Reza Mohebian
Abstract
It is difficult to identify the carbonate reservoirs by using conventional seismic reflection data, especially in cases where the reflection coefficient of the gas-bearing zone is close to that of the carbonate background. In such cases, the extended elastic impedance (EEI) as a seismic reconnaissance ...
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It is difficult to identify the carbonate reservoirs by using conventional seismic reflection data, especially in cases where the reflection coefficient of the gas-bearing zone is close to that of the carbonate background. In such cases, the extended elastic impedance (EEI) as a seismic reconnaissance attribute with the ability to predict fluids and lithology can be used. It allows for a better distinction between seismic anomaly caused by lithology and the one caused by the fluid content. The EEI attribute extends the available reflection angles and applies different weights to the intercept and gradient values so as to extract the petrophysical properties of the rock at a specific incident angle. Using the EEI attribute, we can estimate the elastic parameters such as shear impedance; the ratio of the compressional velocity to shear velocity; Poisson’s ratio; and bulk, Lame, and shear moduli, and petrophysical properties, including porosity, clay content, and water saturation. The known reservoirs in the study area are three oil-bearing formations namely, Surmeh (Arab), Gadvan (Buwaib), and Dariyan (Shuaiba), and three gas-bearing formations, including Kangan, Dalan, and Faraghan. The Dehram group is composed of Kangan (Triassic), Dalan, and Faraghan (Permian) formations. Permian carbonates of Kangan–Dalan and its equivalent Khuff have regionally been developed as a thick carbonate sequence in the southern Persian Gulf region. In this paper, parameters 𝜆𝑝 and 𝜇𝜌 extracted from the EEI method are used to characterize a carbonate reservoir. Our results show that the EEI can highlight the difference between the reservoir and non-reservoir formation to identify the gas-bearing areas.
Petroleum Engineering – Production
Behzad Orangii; Mohammad Ali Riahi
Abstract
This paper investigates the role of the adequate thickness of the Asmari reservoir formation zones on oil production in one of the Iranian carbonate oil fields. Adequate thickness is a term that includes the total gross thickness of rocks by lithofacies for a selected wellbore. The lithology of the Asmari ...
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This paper investigates the role of the adequate thickness of the Asmari reservoir formation zones on oil production in one of the Iranian carbonate oil fields. Adequate thickness is a term that includes the total gross thickness of rocks by lithofacies for a selected wellbore. The lithology of the Asmari formation in the studied area consists of dolomite, sandstone, lime, dolomitic-lime, sandstone-shale, and shale limestone dolomites. Based on the existing well-logs, the average shale volume, the effective arithmetic means of porosity in the gross intervals, and average water saturation or hydrocarbon-bearing increments of the studied field are calculated using well-logs. In wellbore #A, a depth interval of 2214 to 2296 m shows 9.6% average shale volume, 27.2% average water saturation, and 20.9% average porosity. A depth interval of 2213 to 2280 m, in wellbore #B, shows 6% average shale volume, 21.25% average water saturation, and 28.5% average porosity. Based on our petrophysical assessments, we divide the Asmari reservoir in the studied field into eight zones. Zone 1 is made of carbonate (calcareous and dolomitic), and zones 2–5 are mainly sandstone; zones 7 and 8 are calcareous and shale, and zone 6 is a mixture of all the rocks mentioned above. Among these eight zones, there are two primary hydrocarbon productive zones. The numerical calculation of in situ oil volume showed that zone 2 contains 65% of oil volume in this reservoir. With more than 80% sand, this zone has the highest net hydrocarbon column.
Chemical Engineering
Taleb Eidy; Seyed Ali Hosseini; Ghasem Marandi
Abstract
The separation of naphthenic acids from crude oil is difficult, and the presence of such materials in crude oil reduces its value. In this work, using catalytic esterification with methanol, naphthenic acids of crude oil were removed to reduce their harmful effects. SnO2/γ-Al2O3 nanocatalyst was ...
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The separation of naphthenic acids from crude oil is difficult, and the presence of such materials in crude oil reduces its value. In this work, using catalytic esterification with methanol, naphthenic acids of crude oil were removed to reduce their harmful effects. SnO2/γ-Al2O3 nanocatalyst was synthesized and used to convert naphthenic acids of crude oil in a fixed bed catalytic reactor. The nanocatalyst was characterized by the X-ray diffraction (XRD), field emission scanning electron microscopy (FESEM), and Brunauer–Emmett–Teller (BET) surface area techniques. The XRD revealed the formation of rutile SnO2 on alumina, and the FESEM approved that the catalyst is comprised of nanoparticles with a diameter in the range of 50 to 90 nm. The BET indicated that the catalyst has a mesopore structure with a surface area of 213.4 m2·g–1. The optimal conditions for the catalytic esterification process of naphthenic oil were determined. The temperature of the reduction of the total acid number (TAN) of crude oil ranged from 250 to 360 °C, and the TAN was reduced to less than 0.5 mg KOH/g in this temperature range. A methanol-to-oil ratio (M/O) of 2 wt %, a velocity space of 2.5 h–1, a reaction temperature of 300 °C, and atmospheric pressure were selected as the optimal conditions for the removal of naphthenic acids. Under these conditions, 83% of naphthenic acids was removed. The study indicated that SnO2/γ-Al2O3 could be a promising nanocatalyst for the reduction of total acid of crude oil under mild conditions.
Petroleum Engineering
Yaser Ahmadi
Abstract
Recently nanoparticles are used for improving the volume of oil and gas production and Enhanced Oil Recovery (EOR) purposes. Based on our recent researches, using nanoparticles such as Silica and Calcium oxide has a good potential for changing mechanisms in the porous media such as interfacial tension ...
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Recently nanoparticles are used for improving the volume of oil and gas production and Enhanced Oil Recovery (EOR) purposes. Based on our recent researches, using nanoparticles such as Silica and Calcium oxide has a good potential for changing mechanisms in the porous media such as interfacial tension and wettability. For finding the application of nanoparticles in the porous media, low permeability carbonate plugs were selected, and two main steps were used , including 1) Using CaO and SiO2 nanoparticles for wettability alteration, interfacial tension reduction, and improving fluid flow through porous media 2) Surveying the application of nanoparticles on the water alternative gas (NCs assisted WAG) test. The Zeta potential amounts are stable at condition of -56.4±2 mV and -44.0±3 mV for Calcium oxide and Silica nanoparticles, respectively at optimum nanoparticles concentration of 15 ppm. Calcium oxide and Silica nanoparticles have effectively altered the wettability from oil-wet to water-wet by surveying the intersection of two-phase relative permeability. Moreover, CaO nanoparticles had better performance in low permeability carbonate porous media than SiO2 nanoparticles with regards to wettability alteration to water wet. Based on the results and better version of CaO, it was selected for performing NCs assisted WAG tests at WAG ratios of 1:1, 40 ℃, and 15 ppm.The recovery factor was increased from 42.9 % to 73 % in the presence of CaO during performing NCs assisted WAG tests, and residual oil saturation was decreased from 40.9 % to 19.4 %.
Hydrocarbon Reservoirs Management
TEMPLE N CHIKWE; Remy Ukachukwu Duru
Abstract
The Asphaltene and metal naphthenate components of crude oil samples from ten different wells within an oil reservoir were determined using different analytical techniques. The asphaltene content was determined by gravimetric analyses while the metal naphthenate components were determined by obtaining ...
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The Asphaltene and metal naphthenate components of crude oil samples from ten different wells within an oil reservoir were determined using different analytical techniques. The asphaltene content was determined by gravimetric analyses while the metal naphthenate components were determined by obtaining the metal ion concentration of the produced water and the naphthenic acid concentration of the crude using Atomic absorption spectrometer (AAS) and potentiometric titration respectively. Results obtained showed that the asphaltene content of the crude samples ranges from 2.0000 – 8.000 %w while the naphthenic acid concentration indicated by the total acid number (TAN) ranges from 0.3000 – 1.4600 mg/KOH/g. All the crude samples possess asphaltene components as well as the propensity to form calcium and sodium naphthenate scale deposits having a Ca2+ concentration between 32.5000 – 94.5000 mg/L and a Na+ concentration between 27.7 – 105.1 mg/L respectively, however the formation of naphthenate scale deposits is highly dependent on the pH of the produced water of the crude which makes well FT01 less likely to form naphthenate scales since it has a pH < 6. Both asphaltene and naphthenate deposits are directly proportional to the specific gravity of the crude and inversely proportional to the API gravity implying that both components reduce the quality of the crude. Asphaltene and metal naphthenate solid deposits in the crude can cause a lot of flow assurance difficulties such as, blocking of expedition lines, pore plugging, wettability, crude oil parameter alteration, as well as reduction in oil recovery.
Petroleum Engineering
AliPanah Rostamzadeh; Seyed Aboutaleb Mousavi Parsa; Faramarzi Mehdi
Abstract
One of the most important ways to enhance oil recovery in oil reservoirs is chemical flooding. The study of performance and efficiency of these processes in increasing the range of oil recovery from reservoirs depends on several factors, including the rock and fluid properties of the reservoir, and therefore ...
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One of the most important ways to enhance oil recovery in oil reservoirs is chemical flooding. The study of performance and efficiency of these processes in increasing the range of oil recovery from reservoirs depends on several factors, including the rock and fluid properties of the reservoir, and therefore one of the most important steps in evaluating the performance of these methods for a reservoir is the laboratory study and calculating the chemical agent potential to recover oil. For this purpose, a laboratory study and integrated simulation in order to identify the effective mechanisms in the injection of smart water polymer in order to identify the necessary and dominant conditions of this method was performed to improve the recovery of Iranian carbonate reservoirs. Initially, four injection scenarios, water injection-polymer injection-smart water injection, water injection-smart water injection-polymer injection, water injection-smart water polymer injection and smart water injection- smart water polymer injection were tested in a laboratory and then simulation of smart water polymer flooding using Eclipse simulator 100 and the effect of polymer injection on oil recovery and oil trapping in the reservoir rock was performed and finally the results of the simulator and the results of laboratory data were validated. The results showed that smart water injection- smart water polymer injection have better performance in improving secondary oil recovery by 63.45% and wettability changing is one of the main mechanisms to improve oil recovery. The results also showed that in optimal conditions, despite the mechanical degradation of the polymer, initial oil in place recovery is achieved up to 85% by controlled adsorption of polymer on the rock surface.
Petroleum Engineering – Exploration
Ali Jelvegarfilband; Mohammad Ali Riahi; Majid Bagheri
Abstract
The petrophysical parameters of the Ghar Formation are characterized in this study. A combination of pre-stack seismic data gathers and well-log data is used to estimate water saturation and shale volume in the Ghar reservoir. For such a purpose, first, the highest possible correlation between the well ...
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The petrophysical parameters of the Ghar Formation are characterized in this study. A combination of pre-stack seismic data gathers and well-log data is used to estimate water saturation and shale volume in the Ghar reservoir. For such a purpose, first, the highest possible correlation between the well logs and the seismic inverse data was established. After extracting the best wavelet, an accurate relationship between the estimated and the values from core data was obtained. Secondly, using the data of another well, the validity of the constructed model was examined. The results showed that the combination of three attributes of instantaneous cosine of phase, √(Z_P ), and √(V_P ) is suitable to estimate the shale volume of the reservoir with considerable accuracy with a correlation coefficient of about 70%. Although the two layers in the Ghar section have a shale volume of about 10%, in general, the shale volume in the reservoir area is negligible. The logarithm of the ratio of compressional wave velocity to shear wave velocity attribute shows the highest correlation, about 62%. Finally, validation of the results of the mentioned properties with unintroduced well-log data showed an accuracy of about 90% in prediction.
Mechanical Engineering
Hadi eskandari
Abstract
This work pertains to investigate the values of the stress intensity factor (SIF) in a functionally graded spherical pressure vessel with an embedded surface defect (semi elliptical crack) under thermo-mechanical loading. The three dimensional finite element analysis is performed to evaluate the SIFs ...
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This work pertains to investigate the values of the stress intensity factor (SIF) in a functionally graded spherical pressure vessel with an embedded surface defect (semi elliptical crack) under thermo-mechanical loading. The three dimensional finite element analysis is performed to evaluate the SIFs through the crack front for a wide range of crack profiles and the various layer thickness. It is assumed that the elastic modulus of sphere varies exponentially in the radial direction of the vessel.The effect of non-uniform coefficient of thermal expansion (CTE) on the fracture parameters is also studied. The obtained results show that the material gradation of spherical pressure vessel can considerably affect the distribution of the SIFs along the crack front. The gradation of material, the wall thickness of spherical pressure vessel and the profile of crack front can affect the critical point through the crack front which is apt to the crack growth.
Mechanical Engineering
Hadi eskandari; Moslem Ghanbari
Abstract
The present study deals on the geometry effects of the spherical pressure vessel(SPV) and the crack configuration on the variation of the stress intensity factor (SIF) through the crack line. The pressurized vessel is subjected to the pressure and thermal gradient (thermo-mechanical loading). The 3D ...
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The present study deals on the geometry effects of the spherical pressure vessel(SPV) and the crack configuration on the variation of the stress intensity factor (SIF) through the crack line. The pressurized vessel is subjected to the pressure and thermal gradient (thermo-mechanical loading). The 3D analysis of defected thick-walled pressurized sphere vessel is done using the numerical Finite Element Method (FEM). This work covers a wide range of the crack configurations in vessels with different geometries. The effect of the various parameters such as thermal gradient, RO/Ri, a/c and a/t on the variation of the dominant first mode of SIF through the crack front is studied. The obtained SIF’s are compared with the mechanical loading results (in the absence of the thermal gradient). The results show that parameters such as the aspect ratio of the crack, the ratio of the crack depth, the pressure vessel wall thickness and also the temperature gradient have significant effects on the distribution of the SIF through the crack line. It can be seen that the thermo-mechanical condition is more critical.
Petroleum Engineering – Exploration
Hamid Reza Okhovvat; Mohammad Ali Riahi; Afshin Akbari Dehkharghani
Abstract
In this study, in order to facies classification, the kernel principal component analysis (KPCA) feature extraction method is used to extract new features from the measured well-logs. After applying the Principal Component Analysis (PCA), and KPCA feature extraction approaches, the classification was ...
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In this study, in order to facies classification, the kernel principal component analysis (KPCA) feature extraction method is used to extract new features from the measured well-logs. After applying the Principal Component Analysis (PCA), and KPCA feature extraction approaches, the classification was made using three powerful classifiers: Multilayer Perceptron Neural Network (MLP), Support Vector Machine (SVM), and Random Forest (RF). Finally, the predicted results for the test data that were not included in the training process were evaluated with the F1 score criterion.The PCA method did not show a significant effect on the classification performance due to the nonlinear structure of the facies. Our results show that the KPCA improves the performance of facies classification. Compared with the conventional approach based on well-log data, our new approach improves the classification accuracy for each classifier algorithm. In the RF results, the classification accuracy has increased by about 6% while using the KPCA feature extraction approach, increasing from 52% to 58% compared to the original well-log data.
Accounting
Seyyed Abdollah Razavi; Bahar Homayoni; Sadegh Saffarzadeh
Abstract
In this study, by using a relatively complex reservoir model and reservoir simulator, the gas injection process was investigated from two technical and economic perspectives. This reservoir model has 4 production wells and 3 gas injection wells, which are in operational conditions for a period of 15 ...
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In this study, by using a relatively complex reservoir model and reservoir simulator, the gas injection process was investigated from two technical and economic perspectives. This reservoir model has 4 production wells and 3 gas injection wells, which are in operational conditions for a period of 15 and 10 years. Since gas injection with higher pressures in the reservoir requires more gas supply to stabilize the pressure, from a technical point of view, the effect of different injection pressures on the improvement of the final recovery factor and cumulative oil production was investigated. The findings show that all gas injection scenarios due to the increase in the oil recovery factor (injection with well bottom pressure in the scenarios of 3750, 4000, 4250, and 4500 psi led to an improvement of 10, 12, 13.7 and 15% respectively) compared to natural depletion (no gas injection in the reservoir) is desirable. From an economic point of view, after sensitivity analysis of the parameters related to production and injection (such as the price of produced oil, the price of produced gas, the cost of injected gas, and the discount rate), the results show that the increase in the price of oil and produced gas increases the economic added value of gas injection projects. Considering various parameters for the price of export gas as well as gas export costs (capital and operational), comparing the added value of gas injection projects with gas export showed that the higher the price of export gas, the more favorable gas export projects are compared to gas injection. Also, as the cost of gas export increases, the desirability of gas export decreases compared to gas injection in the reservoir.
Petroleum Engineering – Exploration
Alireza Kordzangeneh; Bahram Habibnia; Majid Akbari
Abstract
Permeability is one of the most significant petrophysical parameters of reservoir rock and its accurate, inexpensive, and rapid estimation is important. One of the methods for the estimation of permeability is the Stoneley flow zone index method. In this study, this method was used to estimate the permeability. ...
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Permeability is one of the most significant petrophysical parameters of reservoir rock and its accurate, inexpensive, and rapid estimation is important. One of the methods for the estimation of permeability is the Stoneley flow zone index method. In this study, this method was used to estimate the permeability. For this purpose, after processing the Stoneley waves in the studied well by Geolog software, the permeability index was calculated based on Stoneley wave slowness. Then, by optimizing this index with default values of the Index Matching Factor (IMF), the flow zone index was calculated and the permeability value was estimated based on that index. Some parameters required for these calculations such as porosity, type, and volume of minerals were determined based on the fullset logs analysis and with the help of cross-plots. Finally, in order to validate the obtained permeability data, these results were compared with the core data, and the IMF values were customized for the studied field. The results indicated that the main lithology of the Asmari Formation in the studied well is carbonate rock with a small amount of shale. The customized IMF value for calcite, dolomite, anhydrite, and shale was 11.93, 10.53, 0, and 0 respectively. The correlation coefficient between Stoneley-Flow Zone Index permeability and core permeability was 0.79. Therefore, according to this good correlation, this method can be used to estimate permeability, especially in wells without core data.
Petroleum Engineering – Drilling
Abbas Hashemizadeh; Mohammad Javad Ameri; Babak Aminshahidy; Mostafa Gholizadeh
Abstract
Stimulation of hydrocarbon wells with matrix acidizing operation is among the most common operations to stimulate the formation in order to remove the skin and improve the productivity index. But corrosion of equipment, including casings, is one of the most important concerns. In the present paper, the ...
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Stimulation of hydrocarbon wells with matrix acidizing operation is among the most common operations to stimulate the formation in order to remove the skin and improve the productivity index. But corrosion of equipment, including casings, is one of the most important concerns. In the present paper, the influence of the magnetic field on the corrosion behavior of drilling casing in 1.5 M (5 wt.%) HCl was investigated at various conditions using potentiodynamic polarization (PDP) and weight loss (WL) measurements. Taguchi’s design of experiment (L-18 array) should be utilized to model the impacts of magnetic field intensity, elapsed time, magnetization time, and temperature on the change in corrosion rate. The results of experiments show that passing of acid through a magnetic field reduces the corrosion rate of N-80 carbon steel in HCl up to 96%. Consequently, magnetized acid has a high ability to reduce the effects of corrosion on matrix acidizing operations as a green corrosion inhibitor.
Chemical Engineering
behrouz Bayati; pardis morshedi; Akbar Falahi; Towan Kikhavandi
Abstract
HThe formation of heat stable salts, such as acetate, formate, oxalate, and thiosulfate, in gas sweetening units creates various issues including corrosion, high foaming, and a reduction in unit efficiency. This research aimed to investigate the elimination of heat stable salts using an anion resin. ...
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HThe formation of heat stable salts, such as acetate, formate, oxalate, and thiosulfate, in gas sweetening units creates various issues including corrosion, high foaming, and a reduction in unit efficiency. This research aimed to investigate the elimination of heat stable salts using an anion resin. The findings indicate that it is feasible to remove approximately 85% of acetate anion salt from an amine solution at solution-to-resin ratio of 30. Two adsorption models, Langmuir and Freundlich, were employed to analyze the equilibrium adsorption of acetate anion salt. The results indicate that the Langmuir adsorption isotherm aligns more closely with the data obtained from the acetate anion ion exchange process with the resin. Furthermore, it was determined that the maximum adsorption capacity for acetate onto the resin is 15 mg/g at a temperature of 25°C. The impact of contact time during the adsorption process was examined using quasi-first-order and quasi-second-order kinetic models, as well as an intra-particle model. The results indicated that the quasi-first-order kinetic model provided the best fit to the data, and equilibrium adsorption was achieved after approximately 70 minutes. Thermodynamic parameters were also investigated, revealing a ΔH value of -12.7370 kJ/mol, indicating an exothermic adsorption process. Based on the conducted studies, the utilization of the selected resin appears to be a suitable option for the removal of heat stable salts.
Petroleum Engineering – Drilling
Seyed Reza Shadizadeh; Sina Khajehniyazi
Abstract
Fishing operations are one of the most important parts of drilling operations. If the fishing operation fails, the other direction should be considered to continue drilling and reach the desired depth, which can be achieved by using sidetracking operations. The long-term fishing operation increases the ...
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Fishing operations are one of the most important parts of drilling operations. If the fishing operation fails, the other direction should be considered to continue drilling and reach the desired depth, which can be achieved by using sidetracking operations. The long-term fishing operation increases the cost and time of the drilling operation, therefore, should try to have a successful fishing operation in the shortest possible time. It can be said that the execution of the fishing operation is economical as long as the costs of the fishing operation are less or at least equal to the cost of the sidetracking operation. Therefore, the optimal time for fishing must be determined so that the drilling operation to be economical. Many statistical analysis methods have been used to determine the optimal time, but due to insufficient accuracy and time-consuming calculations, they are not popular. In this study, for the Gachsaran oil field a Machine Learning (ML) model with a regression algorithm were used to estimate an optimal time of Fishing operations. To calculate the optimal fishing time, the fishing cost rate and fishing depth as input data was first collected and categorized based on different sections of the Gachsaran oil field. Then the sidetracking cost is predicted by the machine learning model and this cost was equated to the fishing cost in worst conditions and in the result the optimal fishing time was calculated for each individual section. The result shows that the model can estimate the cost of sidetracking with an error of less than 2%. Using the designed model and the input data of Gachsaran oil field, considering the average optimal fishing time, it is possible to save an average of 1 million dollars and 16 hours in drilling a well.
Safety and Technical Protection Engineering
Abdolrahim Taheri; Dariush Nouri Bakhsh; mohsen motevasel; Gholamreza Rashed
Abstract
Chlorine is a toxic and oxidising gas used in Iran to purify drinking water. There has been no research into the effects of the gas or the explosion of the tank, which could cause irreparable damage to people and the surrounding area. No such research has been carried out in the city of Abadan. To this ...
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Chlorine is a toxic and oxidising gas used in Iran to purify drinking water. There has been no research into the effects of the gas or the explosion of the tank, which could cause irreparable damage to people and the surrounding area. No such research has been carried out in the city of Abadan. To this end, Aloha software (Aloha software is a special computer program that helps professionals understand what will happen in the event of a hazardous release, such as a chemical or fire. This helps them make plans to keep people safe.) Was used to assess the magnitude of the release, the various risk zones and the population at risk. The research shows that in the event of damage to the 1-inch outlet valve of the tank, the gas release could be felt up to a radius of 2 km, 6.2 km and 10 km. Due to the probability of occurrence and the location of the station in the wind direction, it is possible to reach a large number of residents within a 5 km radius of the station. Therefore, based on the FMEA model evaluation, the work prior to the chlorine gas meeting was prioritized to prevent the release of chlorine in the event of the tank settling.
Safety and Technical Protection Engineering
Abdolrahim Taheri; Soleimani torfi Soleimani torfi
Abstract
Pipelines are considered the most practical way to transport oil and gas. However, some factors such as corrosion, third party damage, etc. can lead to serious incidents. Appropriate risk assessment can help reduce the risk of pipeline systems. Prioritizing repairs, scheduling physical integrity assessments, ...
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Pipelines are considered the most practical way to transport oil and gas. However, some factors such as corrosion, third party damage, etc. can lead to serious incidents. Appropriate risk assessment can help reduce the risk of pipeline systems. Prioritizing repairs, scheduling physical integrity assessments, and developing emergency plans can’t be done properly without implementing an appropriate Risk Assessment Method. Risk consists of the Probability of Failure (PoF) and Consequence of Failure (CoF) and in many cases is obtained from the failure statistics published by the pipeline operators. In an endeavor to apply more engineering concepts to the highly statistics-dominated concept of risk assessment, the PoF can be calculated using Finite Element and Monte Carlo methods. This paper is specifically concerned with finding the PoF caused by excavations that are done neighboring a buried pipeline. which is a form of failure that is rarely considered, as most of the studies conducted about third party damages are concerned with the direct hit as a failure cause. Hence, a Python script was written that models the excavations using ABAQUS; The soil is modelled using the Mohr-Coulomb plasticity approach, while the pipe is modelled as a shell. The excavation adjacent to the pipe will cause the pipe to deflect due to gravity. The stress caused by this deflection is compared to the yield stress to determine whether or not it will fail. In order to determine the probability of failure (PoF), this iterative process is carried out for excavations of different sizes using a Monte Carlo method. Additionally, a methodology has been implemented to address the issue of computationally expensive models. The method proposed in this paper is compared and weighted against other common methods to determine whether the advantages of FEA-based risk assessment can justify its complexity.
Safety and Technical Protection Engineering
Danial Khodoli zangeneh; Hakimeh Amanipoor; Sedigheh Battaleb-Looie
Abstract
The importance of the study of Quaternary deposits has increased to such an extent that it now occupies a significant part of research in different parts of the world. In oil-rich countries, including Iran, pollution caused by oil industry activities such as drilling and exploitation has seriously threatened ...
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The importance of the study of Quaternary deposits has increased to such an extent that it now occupies a significant part of research in different parts of the world. In oil-rich countries, including Iran, pollution caused by oil industry activities such as drilling and exploitation has seriously threatened the sediments and soils around these areas. The Abteymour oilfield is one of the big fields in southwestern Iran, located in the area of agricultural lands. As a result, it is very important to evaluate its environmental effects. In this research, 33 surface soil samples were collected and in addition to measuring the concentration of heavy metals, some physical and chemical characteristics of the soil were measured. To identify the source of pollutants, statistical analyses such as correlation coefficient, principal component analysis, and cluster analysis were used. To determine the level of heavy metal pollution, environmental geological indices such as Igeo, EF, Cf, and NIP were used. The results of cluster analysis showed that the studied elements are clustered in two groups. Also, the results of the factor analysis showed that 89% of the variation of the studied parameters is affected by two factors. In total, the results of the statistical analysis showed that the pollution in the region is of anthropogenic origin and the activities related to the extraction and exploitation of the Abteymour oilfield, agricultural activities, and wastewater have an impact on the quality of the soil in the area. Investigation of the pollution level of the samples based on the Igeo, EF, Cf, and NIP indices showed that the samples are unpolluted for most of the studied elements. For the Na, Mg, Cr, Ni, Sr, Cu, Li, and Pb elements, some samples have low levels of pollution
Geophysics
Mahammad Laribaghal; mehdi khorasanian; mostafa eskandari; seyyed rezareza alavi zaree
Abstract
In steel production plants, such as those manufacturing sheets, pipes, and round bars, raw materials are annealed in preheating furnaces at approximately 1200 oC before undergoing hot deformation process. Substantial oxidation and loss of raw steel materials occur in preheating furnaces, resulting in ...
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In steel production plants, such as those manufacturing sheets, pipes, and round bars, raw materials are annealed in preheating furnaces at approximately 1200 oC before undergoing hot deformation process. Substantial oxidation and loss of raw steel materials occur in preheating furnaces, resulting in significant economic losses. A potential solution to reduce losses in this scenario is the application of protective ceramic coatings. This research investigates the effect of a ceramic coating based on Al2O3-SiO2 on the oxidation behavior of steel sheets. The industrial-scale effect of the coating on the oxidation of steel slabs is also examined. The coating was applied using a spray method with slurry ceramic materials dispersed through a compressed air flow. Thickness measurement tests, scanning electron microscopy, and EDS analysis were conducted to evaluate the kinetics, microstructure and the oxidation behavior of the coatings. The findings indicate that the oxidation kinetics for uncoated steel sheets follow a parabolic trend, while the kinetics for ceramic coated samples exhibit a slower logarithmic behavior. The application of the coating resulted in a reduction of the oxide layer thickness by less than 30% compared to the uncoated samples, attributed to a lower diffusion coefficient in the coated samples. In industrial Test, the application of the ceramic coating on St52 slabs led to a significant reduction in the oxide layer thickness and easier peel of the oxide layers. These show that the use of such ceramic coating for materials in preheating furnaces can effectively reduce oxidation losses and enhance mechanical quality of final products.