Download or read book Numerical Simulation of Carbonated Water Injection CWI Process in Live Oil Systems and Its Influences on Enhanced Oil Recovery written by Ali Hassan Mohamed Al Basri Almesmari and published by . This book was released on 2019 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Investigation of Carbonated Water Injection CWI for Enhanced Oil Recovery at the Pore and Corescale written by Sadigheh Mahdavi and published by . This book was released on 2019 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Oil recovery by CO2 injection has been studied in the laboratory and applied in the field, however, for the most part, CO2 injection lacks acceptable sweep efficiency. Various CO2 injection strategies such as CO2 alternating water and gas (CO2-WAG) and CO2 simultaneous alternating water and gas (CO2-SWAG) have been suggested to alleviate this problem and improve oil recovery. The amount of CO2 required can be a limiting factor especially in offshore applications. Thus, carbonated water injection (CWI) has recently been given considerable attention as it requires less CO2 for the injection and increases the sweep efficiency. This study provides an overview of previous work on the topic and outlines the results of an integrated experimental, theoretical, and simulation investigation of the CWI for enhanced oil recovery (EOR). The effect of carbonated water injection on vertical displacement (gravity effect) at both the pore-scale and core-scale was investigated in this study. The novelty of this research is to investigate the performance of water flooding (WF) and CWI in the presence of gravity using homogeneous and heterogeneous (fractured) porous media. The first phase of this research investigates the pore-scale displacement phenomena which occurs in the presence of CWI in a glass micromodel. Although the effects of many parameters have been studied, an investigation of the effect of gravity displacement and heterogeneous porous media on trapped oil extraction using CWI, is deficient in the current literature. To evaluate the potential use of CWI for vertical displacement and oil extraction, a series of experiments in medium pressure homogeneous and heterogeneous (fractured) micromodels were designed at 2.1 MPa (305 psi) and 21°C (69.8 °F). The oil saturation profile, fluid flow pattern, pore-scale mechanisms, and trapped oil mobilization were analyzed during the experiments. The results of CWI showed an increased vertical sweep efficiency compared to water flooding. The fluid flow pattern in both water flooding and CWI showed that the carbonated water phase has a better sweep efficiency. Secondary CWI resulted in 16.8% additional oil recovery compared to water flooding. After a visual investigation of the impact of CWI on oil recovery and oil distribution in micromodels, core flooding experiments were designed to qualify and compare the effectiveness of water flooding, water alternating CO2 gas (CO2-WAG), and CWI at reservoir conditions considering the solubility of CO2 in seawater and oil. The results of the core flooding experiments were evaluated using a simulation study. The results of core flooding experiments showed that secondary CWI obtained the highest recovery factor of 74.8% compared to 66.5% in CO2-WAG and 64.2% in tertiary CWI processes. The third phase the research was to simulate and predict the experimental results using Computer Modeling Group (CMG version 2014) software. The fluid model was constructed using CMG-WinPropTM to create the compositions and properties of the CO2-oil and CO2-brine mixtures. The fluid model was incorporated into the compositional and unconventional reservoir simulator, CMG-GEMTM, in order to reproduce the CWI and CO2-WAG flooding tests conducted in this study. The simulation results indicated that CWI had a higher oil recovery factor compared to water flooding and CO2-WAG. In summary, this comprehensive study highlights the CWI applicability for vertical oil sweep efficiency and enhanced oil recovery in homogeneous and heterogeneous porous media.

Download or read book Utilization of Carbonated Water Injection CWI as a Means of Improved Oil Recovery in Light Oil Systems written by Nader Mosavat and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book New Insights Into Transport Phenomena Involved in Carbonated Water Injection written by Cleverson Ebeagbor Esene and published by . This book was released on 2019 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbonated water injection (CWI) is a promising enhanced oil recovery (EOR) method that provides an efficient and a more environmentally friendly alternative to meet the ever-increasing demand for energy. An additional benefit from the implementation of CWI is the storage of anthropogenic CO2 and this has made it even more attractive. Over the years, several attempts have been made to model CWI as an EOR process but have been of very little success due to the underlying assumptions used or the modelling strategy. There are several multi-physics involved during CWI and to have an accurate model to investigate CWI, these physics need to be adequately captured. In this thesis, we have attempted to model CWI adequately by using more realistic and practical assumptions to present a novel modeling strategy. This thesis shows our research in a manuscript-based format which is presented in each chapter as major contributions. Firstly, a comprehensive review of CWI where the behavior of fluids, fluid-rock interactions and challenges associated with CWI technique have been thoroughly discussed. Secondly, the modelling investigation to capture the critical salinity which plays an important role in EOR techniques for sandstones and carbonate as well as the solubility of CO2 during CWI is presented. Thirdly, a 3-D modeling method to investigate CWI which considers important terms such as gravity, non-instantaneous equilibrium, heterogeneity, anisotropy and well orientation is presented. Fourthly, a 1-D core modelling approach which considers the reaction term and rock dissolution in an improved attempt to capture CWI is presented. Finally, a deterministic approach is presented to effectively predict oil recovery factor based on pattern recognition and artificial intelligence. To facilitate this, the use of artificial neural network (ANN), least square support vector machine (LSSVM) modelling and gene expression programming (GEP) are adopted.

Download or read book Pore Scale Mechanisms of Carbonated Water Injection in Oil Reservoirs written by Masoud Riazi and published by . This book was released on 2011 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Concerns over the environmental impact of carbon dioxide (CO2) have led to a resurgence of interest in CO2 injection (CO2I) in oil reservoirs, which can enhance oil recovery from these reservoirs and store large quantities of CO2 for a long period of time. Oil displacement and recovery by CO2I has been studied and applied in the field extensively. However, CO2I lacks acceptable sweep efficiency, due to the large viscosity contrast between CO2 and resident reservoir fluids. Various CO2I strategies e.g. alternating (WAG) or simultaneous injection of CO2 and water have been suggested to alleviate this problem. An effective alternative strategy is carbonated (CO2-enriched) water injection. In carbonated water, CO2 exists as a dissolved as opposed to a free phase, hence eliminating the problems of gravity segregation and poor sweep efficiency. In this thesis, the results of an integrated experimental and theoretical investigation of the process of carbonated water injection (CWI) as an injection strategy for enhanced oil recovery (EOR) with the added value of CO2 storage are described. High-pressure micromodel technology was used to physically simulate the process of CWI and visually investigate its EOR potential, at typical reservoir conditions. Using the results of these flow visualisation experiments, the underlying physical processes and the pore-scale mechanisms of fluid-fluid and fluid-solid interactions during CWI were demonstrated to be oil swelling, coalescence of the isolated oil ganglia, wettability alteration, oil viscosity reduction and flow diversion due to flow restriction in some of the pores as a result of oil swelling and the resultant fluid redistribution. A mathematical model was developed that accounts for the pore-scale mechanisms observed during the micromodel experiments. In this study, some of the micromodel experimental observations were interpreted and the impact of some of the pertinent parameters on CWI and CO2I processes was studied. The results predicted by the model were linked to the results obtained using a new relationship developed based on the dimensional analysis technique. To examine and investigate the effect of CWI on wettability, micromodel experiments, designed only to observe possible variation of contact angles and spontaneous imbibition displacement mechanisms due to CW, were performed. Contact angle measurements were also conducted to quantify different tendencies of CW and water to wet solid surfaces, using three different solid plates with different salinity of the aqueous phase, under different pressure and temperature conditions. Two other important parameters affecting the performance of CWI, i.e. CO2 solubility in water and its CO2 diffusion coefficient, were also experimentally studied and estimated. A mathematical model was developed to estimate CO2 diffusion coefficient from the corresponding experimental results. The results of this research show that CWI is an effective and efficient injection strategy that offers great potential for enhanced oil recovery and at the same time a unique solution to the problem of reducing CO2 emission.

Download or read book A Study of Water and Carbonated Water Injection with Constant Pressure Boundaries written by Huan Yang and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The Buckley-Leverett theory for one-dimensional constant fluid velocity is widely used in the oil and gas industry. However, given a changing fluid velocity with fixed pressure boundary conditions, limitations arise. This work is based on an existing extension of the Buckley-Leverett theory in a water-oil system with fixed pressure boundary conditions. This allows the Buckley-Leverett theory to be applied to situations of injecting water at a constant bottom-hole pressure and producing oil at a fixed bottom-hole pressure. Based on mass conservation, numerical simulation is performed in Matlab® using the Implicit Pressure Explicit Satuation (IMPES) method for two-phase flow. The numerical solution is compared to the recently developed analytical solution for different case studies. The comparison is also used to illustrate the effect of numerical dispersion and round-off errors. This extension of the Buckley-Leverett theory has significant consequences in its applicability to more realistic operating scenarios and computational savings through analytical solutions. Carbonated water injection is studied numerically based on the validated water injection model. In carbonated water injection, CO2 is dissolved in water phase before injection. After injection, the properties of reservoir fluids will change due to the partitioning of CO2 between both the water and oil phases. Therefore, the reduction of oil viscosity and oil-water interfacial tension would be the main factors affecting the oil recovery. However, there is minimal research on carbonated water flooding combining both thermodynamics and reservoir simulation models. This research aims to study the effect for oil recovery in carbonated water injection based on both physical and numerical perspectives.

Download or read book Enhanced Oil Recovery by Carbon Dioxide and Diethyl Ether as Mutual Solvents written by Ahmed Jamal AlZayer and published by . This book was released on 2017 with total page 180 pages. Available in PDF, EPUB and Kindle. Book excerpt: Increasing the oil recovery factor from existing fields is the key towards meeting future oil demand. The injection of solvents, an established EOR technique, has shown significant improvement in oil recovery over conventional water floods. However, the injection of pure solvent slugs can be quite costly for field operators. To mitigate this problem, recent literature has suggested the use of brines that are saturated with mutual solvents (dissolve in both oil and water) such as Carbon Dioxide (CO2) and Dimethyl Ether (DME). This practice minimizes the amount of used solvent since it is governed by its limited solubility in water. The solubility of CO2 and DME is much higher in oil than in water. Therefore, a mass transfer takes place once CO2 or DME saturated brines come into contact with oil. As these solvents go into the oil phase, they promote oil swelling and reduce the oil viscosity, thereby making it movable and increasing the oil recovery as a result. Although there has been recent lab work performed with this EOR method, most of the work performed so far involved short cores, high injection rates and in some cases limited to sandstone cores. In this thesis, we investigated the effect of using brines that were saturated with CO2 and Diethyl ether (DEE) on oil recovery. The results came out to be mixed and not completely in line with previous literature for CO2 rich brine (Carbonated Water). Injecting carbonated water into sandstone cores did not improve the oil recovery. However, there was an improvement in oil recovery as a result of carbonated water injection in carbonate cores, which also displayed effluent line plugging. For the case of DEE-rich brine, there was a noticeable improvement in oil recovery but it took more pore volumes to have an effect in comparison to DME-rich brine literature results. The experimental work was further supplemented with numerical modeling. The simulator was not able to capture the effects of carbonated water observed in the experiment, due to the absence of rock–fluid interaction in the modeling mechanism. In contrast, the DEE rich brine case was successfully matched with the compositional simulator since it did not involve rock reactions and was strictly based on fluid–fluid interactions

Download or read book Feasibility Study Through Numerical Simulation of Waterflooding and Gas Injection for a Carbonate Oil Field written by Eghonghon Ojeifo and published by . This book was released on 2012 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The goal of the project was to select between the application of waterflooding and gas injection in an actual carbonate field to ascertain which method would yield the highest recovery. This was done by performing reservoir simulation studies to observe the reservoir's response to each of these methods. Various injection schemes, which included injection rates and location of injection wells, were simulated to obtain optimal recovery based on the setup of the injection wells, allowing for observation of the effects of injection rate, injection location, and injection start time on recovery. The performance of these enhanced oil recovery methods applied to the carbonate field studied in this report are captured and described.

Download or read book In Situ Investigations of Wettability and Pore scale Displacements During Two and Three phase Flow in Oil wet Carbonates written by Ziqiang Qin and published by . This book was released on 2021 with total page 161 pages. Available in PDF, EPUB and Kindle. Book excerpt: Preferentially oil-wet characteristics of carbonate reservoir rocks hinder oil recovery due to conventional waterflooding. The remaining oil in these reservoirs is the target of enhanced oil recovery (EOR) techniques such as low-salinity waterflooding (LSWF), immiscible/near-miscible gas injection, Water-Alternating-Gas (WAG) flooding, and carbonated water injection (CWI). An improved fundamental understanding of wettability and displacement mechanisms governing multiphase flow behavior in oil-wet carbonates is critical to ensure the success of these EOR schemes in the field. However, there is a dearth of literature focused on the displacement physics of such EOR processes at the pore scale. To fill in these research gaps, a series of miniature core-flooding experiments were performed in oil-wet carbonates at elevated temperature and pressure conditions, using a three-phase core-flooding system integrated with a high-resolution x-ray micro-CT scanner. Our observations indicated that higher temperature and lower initial water saturation established greater equilibrium in situ oil-brine contact angles during dynamic aging-induced wettability alteration process. For LSWF, wettability reversal towards neutral-wetness and the consequent reduction in threshold brine pressure required for the fluid to invade medium-sized oil-filled pores led to a higher oil recovery than that of high-salinity waterflooding. Under tertiary immiscible gas injection scheme, gas-to-oil-to-brine double displacements were the main pore-scale events responsible for the enhancement in oil production. During this process, the greater was the degree of oil-wetness of the rock, the larger became the additional oil recovery. Furthermore, WAG flooding significantly increased the displacement efficiency of both gas and brine phases because of the shield effect of the trapped gas ganglia. In the first WAG cycle, oil was produced through a series of direct and double displacements. Multiple displacements started taking place and further contributed to oil recovery as more WAG cycles were implemented. As for the CWI scheme, we found that pore-scale mechanisms governing oil mobilization included decrease in the threshold brine pressure of displacements due to wettability reversal, swelling and coalescence of oil ganglia, and brine flow diversion. After CWI, as the in situ CO2 exsolution progressed due to depressurization, gas bubbles preferably formed, grew, and resided in larger pores. The synergistic effects of spreading oil layers and double displacements prompted the isolated oil globules to coalesce and facilitated the oil mobilization. Finally, in near-miscible supercritical CO2 (scCO2) injection scheme, we observed a distinct wettability state where the wetting preference of the solid to scCO2, oil, and brine phases was similar. Consequently, pore sizes neither dictated any preferential invasion order nor restricted the displacement efficiency. Furthermore, we identified a new type of spreading system where spreading oil layers formed but did not exist globally across the pore space between the scCO2 and brine phases. In this experiment, the frequencies of double and multiple displacements were much higher than those observed during N2 injection in oil-wet systems. The interplay of scCO2-oil miscibility, the distinctive wettability state, favorable fluid connectivity, and frequent double/multiple displacements resulted in an exceptional displacement efficiency.

Download or read book Compositional Modelling of Imbibition Oil Recovery Processes in Naturally fractured Reservoirs written by Shamsuddin H. Shenawi and published by . This book was released on 1994 with total page 334 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Effect of Oil Type on the Performance of Carbonated Water Injection for Enhanced Oil Recovery Under Consistent Operating Condition written by Samia Muhammad AL-Riyamiyah and published by . This book was released on 2016 with total page 122 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book An Investigation of Parameters Affecting Oil Recovery Efficiency of Carbon Dioxide Flooding in Cross sectional Reservoirs written by Mansour Saleh Almalik and published by . This book was released on 1988 with total page 378 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Performance Evaluation of Ionic Liquids in Enhanced Oil Recovery Using Numerical Simulation written by Mostafa Elaghoury and published by . This book was released on 2019 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Given the rise in oil productivity from conventional and unconventional resources in Canada and North America, using enhanced oil recovery technique, the need to understand and characterize these techniques, for the purpose of recovery optimization, has taken a prominent role in resource management. Chemical flooding has proved to be one of the most efficient EOR techniques. This study investigated the potential of employing Ionic Liquids (ILs) as alternative chemical agents for improving oil recovery. There is very little attention paid to employing this technique as well as few experimental and simulation studies. Consequently, very limited data is available. Since pilot and field studies are relatively expensive and time consuming, a numerical simulation study using CMG-STARS simulator was utilized to explore the efficiency of employing 1-Ethyl-3-Methyl-Imidazolium Acetate ([EMIM][Ac]) and 1-Benzyl-3- methlimidazolium chloride ([BenzMIM][Cl]) with respect to improving medium oil recovery. Eight different lab-scale core flooding experiments were selected with the objective to develop a numerical model to obtain the history matching of the experimental flooding results. To fulfill this objective; mainly, two-phase relative permeability curves were tuned. In this dissertation, the simulation results are presented in the form of oil recovery factor (RF), well bottom-hole pressure, oil cut, water cut and two-phase relative permeability curves. A sensitivity analysis was performed for the chemical injection rate, the chemical concentration, the slug size, and the initiation time while studying the effects of changing the oil viscosity, the polymer viscosity, and the reservoir temperature on oil recovery. In addition, the effect of changing the chemical adsorption and combining IL with low salinity water were considered. The results have shown a noticeable increase in the oil RF when injecting IL compared to conventional waterflooding. Furthermore, combining IL with alkaline and polymer led to higher oil recovery than injecting IL alone. Finally, the numerical model was upscaled to qualitatively examine the sustainability and efficiency of this technique in a field scale. The results emphasize the potential of applying IL flooding in a field scale. The increase in oil recovery is also consistent with the lab-scale model.

Download or read book Numerical Simulation Study written by Mahmod Mjahead Hwessa and published by . This book was released on 2009 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Conventional and Carbonated Water Flooding in Heavy Oil Systems written by Tayebeh Jamshidi and published by . This book was released on 2018 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Despite the severe viscosity contrast and low displacement efficiency in heavy oil reservoirs, conventional waterflooding is still considered as one of the feasible recovery processes for such reservoirs. On the other hand, conventional waterflooding has been well studied and has been suggested for light oil reservoirs. However, viability of carbonated waterflooding for heavy oil reservoir and impact of operational parameters, reservoir characteristics, and fluid properties on the performance of this technique are yet to be fully understood. In this study, the performances of conventional and carbonated waterflooding in heavy oil reservoirs were analyzed through various micromodel and coreflooding experiments. Prior to the main tests, a series of experiments were performed to investigate the effect of various parameters such as temperature, pressure, and oil API gravity on the fluid interactions in the binary systems of brine-CO2 and oil-CO2. The solubility of carbon dioxide in 20,000 ppm brine solution was measured at various experimental conditions and compared with previous studies. Furthermore, the solubility of CO2 in oil and the swelling factor for two heavy oils (Type-I, oAPI=20.44 and Type-II, oAPI=15.49) were experimentally measured at various conditions. In this regard, CO2 solubility was measured to be 10.13 and 5.72 (gr CO2/100 gr oil) in Type-I crude oil when temperature increased from T=21oC to 45oC at the constant pressure of Pexp=3.44 MPa. When pressure increased from Pexp=1.38 MPa to 3.44 MPa at the constant temperature of T=21oC, solubility of CO2 in Type-II crude oil was increased from 2.37 to 7.84 (gr CO2/100 gr oil). A reduction in oil API gravity had adverse effect on the CO2 solubility. For example, at the temperature of T=21oC and Pressure of Pexp=3.44 MPa, CO2 solubility decreased from about 10.13 (g CO2/100 gr in oil) Type-I to 7.84 (gr CO2/100 gr ii oil) in oil Type-II. Measured values of swelling factor showed that Type-I and Type-II crude oils could swell to the maximum of 1.079 and 1.052 times of their initial volume at the temperature of T=21oC and Pressure of Pexp=3.44 MPa. Effect of key parameters such as injection rate, temperature, oil API gravity and extreme heterogeneity on the performance of both conventional and carbonated waterflooding in heavy oil systems were extensively studied through series of experiments. Results of conventional waterflooding conducted with 1.6 PVs of injected water in the single permeability porous media showed ultimate recovery factors of 48%, 62% and 53.7% for water injection rates of qinj=0.025, 0.05, and 0.075 (cm3/min), respectively. Increasing the temperature from Texp=21oC to 30oC and 45oC improved the ultimate recovery factor of conventional waterflooding in single permeability porous media from 61% to 69.3% and 73%, respectively. These values were achieved at nearly 1.6 PVs of injected water. Analysis of the experimental results at qinj=0.05 (cm3/min) and Texp=21oC revealed an improvement of 2.44% in ultimate recovery factor when oil API gravity increased from oAPI=15.49 to 20.44. Results of this study showed that carbonated waterflooding (CWF) could improve the ultimate recovery factor by 24% compared to WF. Conventional and carbonated waterflooding tests conducted in a sand-packed model revealed that injection at higher carbonation pressure of 3.1 MPa results in 16.5% additional recovery factor in type-I heavy oil compared to heavier oil of type-II. Among API gravity, carbonation pressure, temperature and injection rate, it was found that the key success for CWF is oil API gravity and carbonation pressure.

Download or read book Enhanced Oil Recovery written by Marcel Latil and published by Butterworth-Heinemann. This book was released on 1980 with total page 260 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Enhanced Oil Recovery by Carbonated Co2 enriched Water Injection written by Seyyed Mojtaba Seyyedi Nasooh Abad and published by . This book was released on 2017 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: