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Author : Huazhou Li
Publisher :
ISBN 13 :
Total Pages : pages
Book Rating : 4.:/5 (13 download)
Download or read book Phase Behaviour and Mass Transfer of Solvent(s)-CO2-heavy Oil Systems Under Reservoir Conditions written by Huazhou Li and published by . This book was released on 2013 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:
Author : Yu Shi
Publisher :
ISBN 13 :
Total Pages : 0 pages
Book Rating : 4.:/5 (133 download)
Download or read book Nonequilibrium Phase Behaviour and Mass Transfer of Alkane Solvents(s)-CO2-Heavy Oil Systems Under Reservoir Conditions written by Yu Shi and published by . This book was released on 2017 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: During primary heavy oil recovery, a unique phenomenon has been found to be closely associated with an unexpected high recovery factor, a remarkably low gas-oil ratio, and a higher-than-expected well production rate due mainly to the foamy nature of viscous oil containing gas bubbles. Even for secondary and tertiary recovery techniques, it is possible to artificially induce foamy oil flow in heavy oil reservoirs by dissolution with injected gases (e.g., CO2 and alkane solvents), which is characterized by time-dependent (i.e., nonequilibrium) phase behaviour. The entrained gas bubbles in the heavy oil are considered as the main mechanism accounting for such distinct phase behaviour. Therefore, it is of fundamental and practical importance to quantify the nonequilibrium phase behaviour and mass transfer of alkane solvent(s)-CO2-heavy oil systems under reservoir conditions. A novel and pragmatic technique has been firstly developed and validated to accurately quantify the preferential diffusion of each component in alkane solvent(s)- assisted recovery processes with consideration of natural convection induced by the heated and diluted heavy oil. The Peng-Robinson equation of state, heat transfer equation, and diffusion-convection equation are coupled to describe both mass and heat transfer for the aforementioned systems. The individual diffusion coefficient between each component of a gas mixture and liquid phase is respectively determined once either the deviation between the experimentally measured and theoretically calculated mole fraction of CO2/solvents or the deviation between the experimentally measured dynamic swelling factors and the theoretically calculated ones has been minimized. ii A robust and pragmatic technique has also been developed to quantify nonequilibrium phase behaviour of alkane solvent(s)-CO2-heavy oil systems at a constant volume expansion rate and a constant pressure decline rate, respectively. Experimentally, constant-composition expansion (CCE) tests have been conducted for alkane solvent(s)-CO2-heavy oil systems with a PVT setup, during which not only pressure and volume are simultaneously monitored and measured, but also gas samples were respectively collected at the beginning and the end of experiments to perform compositional analysis. Theoretically, mathematical formulations have been developed to quantify the amount of the evolved gas as a function of time, while mathematical models for compressibility and density of the oleic phase mixed with the entrained gas (i.e., foamy oil) are respectively formulated. In addition to a mechanistic model for quantifying a single gas bubble growth, a novel and pragmatic technique has been proposed and validated to quantify dynamic volume of foamy oil for the aforementioned systems under nonequilibrium conditions by taking preferential mass transfer of each component in a gas mixture into account. The individual diffusion coefficient of each gas component with consideration of natural convection is found to be larger than that obtained with conventional methods. An increase in either volume expansion rate or pressure decline rate would increase the critical supersaturation pressure, whereas a high temperature leads to a low critical supersaturation pressure. When pressure is below the pseudo-bubblepoint pressure, density and compressibility of foamy oil are found to sharply decrease and increase at the pseudo-bubblepoint pressure, respectively. Also, pseudo-bubblepoint pressure and rate of gas exsolution is found to be two mechanisms dominating the volume-growth rate of the evolved gas, which is directly proportional to supersaturation pressure, pressure decline rate, and concentration of each gas component under nonequilibrium conditions.
Author : Hyun Woong Jang
Publisher :
ISBN 13 :
Total Pages : 0 pages
Book Rating : 4.:/5 (137 download)
Download or read book Mass Transfer of Alkane Solvents-CO2-Heavy Oil Systems in the Absence and Presence of Porous Media Under Reservoir Conditions written by Hyun Woong Jang and published by . This book was released on 2021 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: For a thin heavy oil reservoir where thermal methods are not applicable due to heat loss to over- and under-burdens, gas injection is considered to be an effective alternative. One of the major mechanisms associated with gas injection is the molecular diffusion of dissolved gas(es) which reduce the viscosity of heavy oil while inducing oil swelling. Physically, addition of a less volatile gas to a more volatile gas enhances both viscosity reduction and oil swelling, while the presence of porous media complicates such mass transfer processes. Diffusivity of dissolved gas(es) in heavy oil is often estimated as a constant, while limited attempts have been made to determine it as a function of concentration in the absence and presence of porous media. In this study, a power-law mixing rule is firstly developed to correlate apparent diffusivity of a binary gas mixture in heavy oil with the diffusivity of each pure gas based on the principle of corresponding states. Comparison of the correlated results with the measured data from literature proves that the correlation can be used to accurately predict the apparent diffusivities of binary gas mixtures. To verify the effect of a gas component on the other in a binary gas mixture diffusing in heavy oil, the cross-term diffusivities are estimated for a CO2-C3H8 mixture as well as its main-term diffusivities using the experimental data from Li et al. (2017b). It is found that the existence of a gas with a high concentration at the gas-heavy oil interface enhances the mass transfer of the other gas component through the cross-term diffusivity by generating a high concentration gradient. Then, a generalized methodology has been developed to determine the diffusivity of a gas (e.g., CO2) in a heavy oil as an exponential function of gas concentration with consideration of oil swelling applying the test data from Li et al. (2017b) and Li and Yang (2016). The obtained concentration-dependent diffusivity of CO2 is reasonable and accurate as well as it can be converted for use at different pressures and temperatures. Further, a robust and pragmatic technique has been developed for the first time to implicitly evaluate the concentration-dependency of diffusivity for each component in a binary gas mixture diffusing in heavy oil as a power function of oil viscosity. As for the C3H8/CO2-heavy oil systems, the dependency of C3H8 diffusivity on the gas concentration is significantly higher than that of CO2 diffusivity. Lastly, the conventional pressure decay technique has been improved and extended to determine the effective diffusivity of either a pure gas or each component in a binary gas mixture in an unconsolidated porous medium saturated with heavy oil. Effective diffusivities are determined by matching the measured gas compositions in liquid-phase at the end of pressure decay tests with the calculated ones. Such determined effective diffusivity of C3H8 is found to be larger than that of CO2, which is in accordance with previous studies performed for the same gases diffusing in the same bulk heavy oil, although the porous medium hinders the mass transfer of gas(es).
Author : Sixu Zheng
Publisher :
ISBN 13 :
Total Pages : 0 pages
Book Rating : 4.:/5 (133 download)
Download or read book Enhanced Heat and Mass Transfer for Alkane Solvent(s)-CO2-Heavy Oil Systems at High Pressures and Elevated Temperatures written by Sixu Zheng and published by . This book was released on 2016 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The tremendous heavy oil reserves have recently attracted considerable attention for sustaining the increasing global oil consumption. Heavy oil reservoirs are characterized by high oil viscosity and drastic drop of reservoir pressure in a short period during production, imposing great challenges to recover such heavy oil resources. In practice, conventional steam-based thermal recovery techniques are generally ineffective or uneconomical in thin heavy oil reservoirs due to operational and environmental constraints. Since CO2 is a highly soluble, low cost, and environment-friendly injectant, hot CO2 injection is alternatively considered to be a promising technique for enhancing heavy oil recovery from these thin reservoirs. Not only does it take advantages of both thermal energy and dissolution of solvents to recover heavy oil resources, but also it contributes to the alleviation of carbon footprint. Compared with the CO2-alone processes, addition of alkane solvents to the CO2 stream leads to enhanced viscosity reduction and swelling effect of heavy oil. Thus, it is of fundamental and practical importance to study the underlying mechanisms of hot alkane solvent(s)-CO2 processes for enhancing heavy oil recovery at high pressures and elevated temperatures. In order to more accurately determine the equilibrium phase properties for alkane solvent(s)-CO2-heavy oil systems with the Peng-Robinson equation of state (PR EOS), heavy oil is characterized as multiple pseudocomponents, while a volume translation strategy is employed to improve its prediction performance. The binary interaction parameter (BIP) correlations are tuned with the experimentally measured saturation pressures for the same heavy oil. Such volume-translated PR EOS with a modified alpha function incorporating the tuned BIP correlations is capable of accurately predicting the saturation pressures and swelling factors of the aforementioned systems. The alkane solvent-CO2-heavy oil pressure decay systems under a constant temperature have been theoretically modelled to not only examine the effect of adding alkane solvents into CO2 stream, but also determine both apparent diffusion coefficient of a gas mixture and individual diffusion coefficient of each component in heavy oil. It is found that alkane solvents (i.e., C3H8 and n-C4H10) diffuse much faster than CO2 in heavy oil at reservoir temperature. Compared to pure CO2, addition of C3H8 into the CO2 stream tends to accelerate the swelling of heavy oil under similar conditions. Experimental and theoretical techniques have also been developed to couple heat and mass transfer for hot CO2-heavy oil systems with and without addition of alkane solvents. Both molecular diffusion coefficient of each component and apparent diffusion coefficients of alkane solvent(s)-CO2 mixtures are determined once the discrepancy between the measured and calculated dynamic swelling factors has been minimized. The thermal equilibrium is found to achieve in a much shorter time than mass equilibrium. CO2 diffusion coefficient in heavy oil increases with temperature at a given pressure. Compared with hot CO2 injection, addition of C3H8 into hot CO2 stream contributes to an enhanced swelling effect of heavy oil. A higher concentration of C3H8 in the CO2-C3H8 mixture tends to accelerate gas diffusion and thus induce a stronger oil swelling. Among the n-C4H10-heavy oil system, n-C4H10-CO2-heavy oil system, and C3H8-n-C4H10-CO2- heavy oil system, smaller dynamic swelling factors are obtained for the n-C4H10-heavy oil system, while the largest dynamic swelling factor of 1.118 at the end of diffusion test is achieved for the C3H8-n-C4H10-CO2-heavy oil system.
Author : Desheng Huang
Publisher :
ISBN 13 :
Total Pages : 0 pages
Book Rating : 4.:/5 (133 download)
Download or read book Phase Behaviour of Solvent(s)/Water/Heavy Oil Systems at High Pressures and Elevated Temperatures Based on Isenthalpic Flash written by Desheng Huang and published by . This book was released on 2020 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The hybrid steam-solvent injection processes have been proved to be a promising technique for enhancing heavy oil recovery as they combine the advantages from both heat transfer of steam and mass transfer of solvent(s) to further reduce the viscosity of heavy oil. Multiphase isenthalpic flash calculation is required in compositional simulations of the aforementioned processes, which involve vapour, oleic, and aqueous three-phases since water is inevitably associated with steam injection processes. As such, it is of fundamental and pragmatic importance to accurately quantify the phase behaviour of solvent(s)/water/heavy oil systems at high pressures and elevated temperatures by use of isenthalpic flash algorithms. A modified correlation and a new enthalpy determination algorithm have been developed to more accurately predict ideal gas heat capacities and enthalpies for normal alkanes/alkenes and hydrocarbon fractions, respectively. By assuming that only the presence of water and solvents with high solubilities in water is considered in the aqueous phase, a robust and pragmatic water-associated isenthalpic flash (WAIF) model has been developed to perform multiphase isenthalpic flash calculations for solvent(s)/water/heavy oil mixtures at high pressures and elevated temperatures. The new isenthalpic flash model developed in this work can handle multiphase equilibria flash calculations at high pressures and elevated temperatures. Subsequently, phase boundaries of C3H8/CO2/water/heavy oil mixtures in both the pressure-temperature (P-T) and enthalpy-temperature (H-T) phase diagrams have been determined, respectively. Experimentally, the phase boundary pressures are determined for three C3H8/CO2/water/heavy oil mixtures by using a conventional pressurevolume- temperature (PVT) setup in the P-T phase diagram. Theoretically, the previously developed WAIF model and the new isenthalpic determination algorithm together with the new alpha functions for water and non-water components are applied as the thermodynamic model to reproduce the multiphase boundaries of the aforementioned systems. The water-associated model is able to provide a good prediction of the experimental measurement in terms of phase boundaries and phase compositions. In addition, a new algorithm is developed to determine vapour/liquid/ liquid (VL1L2) phase boundaries of alkane solvent(s)/CO2/heavy oil mixtures. A new thermodynamic model based on the modified Peng-Robinson equation of state (PR EOS) together with the Huron-Vidal mixing rule is developed to experimentally and theoretically quantify the phase behaviour of dimethyl ether (DME)/water/heavy oil mixtures which include polar components. The new model is capable of accurately reproducing the experimentally measured multiphase P-T and H-T boundaries, phase volumes, and swelling factors, while it can also be used to determine DME partition coefficients and DME solubility.
Author : Ali Kavousi
Publisher :
ISBN 13 :
Total Pages : pages
Book Rating : 4.:/5 (13 download)
Download or read book Dynamic and Static CO2 Mass Transfer Processes in Bulk Heavy Oil and Heavy Oil Saturated Porous Media written by Ali Kavousi and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:
Author : Xiaoli Li
Publisher :
ISBN 13 :
Total Pages : pages
Book Rating : 4.:/5 (13 download)
Download or read book Phase Behaviour of Alkane Solvent(s)-CO2- Water-Heavy Oil Systems at High Pressures and Elevated Temperatures written by Xiaoli Li and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:
Author : Zulong Zhao
Publisher :
ISBN 13 :
Total Pages : 0 pages
Book Rating : 4.:/5 (137 download)
Download or read book Quantification of Nonequilibrium Phase Behaviour of Alkane Solvents/CO2/alkaline Water-heavy Oil Systems Under Reservoir Conditions written by Zulong Zhao and published by . This book was released on 2022 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: During the primary stage, the in-situ generated foamy oil has been found to be responsible for an unexpected high recovery factor, a remarkably low gas-oil ratio (GOR), and a higher-than-expected well production rate. Such a phenomenon can also be artificially induced by injecting alkane solvents (e.g., methane and propane) or CO2 to a heavy oil reservoir; however, the gas exsolution of foamy oil is not yet well understood due mainly to the complicated physical processes. On the other hand, the associated emulsifications resulted from the in-situ generated surfactant(s) during alkaline flooding in a heavy oil reservoir lead to an increase in oil recovery, though no theoretical models have been made available to quantify such physical phenomena at high pressures and elevated temperatures. Physically, both gas exsolution and emulsification are closely associated with the nonequilibrium phase behaviour. Therefore, it is of fundamental and pragmatic importance to accurately quantify the nonequilibrium phase behaviour of the alkane solvent(s)-CO2/alkaline water-heavy oil systems under reservoir conditions. A novel and pragmatic technique has been developed and validated to quantify gas exsolution of alkane solvent(s)-CO2-heavy oil systems under nonequilibrium conditions. Experimentally, constant composition expansion (CCE) tests of alkane solvent(s)-CO2- heavy oil systems are conducted with a visualized PVT cell. Theoretically, a mathematical model which integrates the Peng-Robinson equation of state (PR EOS), Fick's second law, and nonequilibrium boundary conditions has been developed. It is found that the rising of experiment temperature and pressure has negative effects on diffusion coefficient during gas exsolution processes. At a higher temperature, a larger CO2 diffusion coefficient is observed, whereas, for alkane solvents (i.e., CH4 and C3H8), a lower diffusion coefficient is attained. Also, experimental and theoretical techniques have been developed to quantify the emulsion behaviour of alkaline water-heavy oil systems at high pressures and elevated temperatures. Experimentally, oil in water (O/W) emulsions with different settling times were prepared in order to track the continuous water content distribution along time. Theoretically, two groups of population balance equations (PBEs) were applied to quantify the phase behaviour during the emulsion destabilization. By applying the emulsion inversion point (EIP) as the boundary condition, the newly developed model is able to reproduce the dynamic water content distribution in the dual-emulsion systems. Due to the corresponding changes of oil viscosity and interfacial tension (IFT), either an increase in temperature or a decrease in pressure leads to a smaller EIP and higher coalescence efficiency. As a weak alkali, Na2CO3 facilitates the stabilization of the emulsion and inhibits the influence of higher temperatures, while NaOH solution-heavy oil systems achieve emulsion inversion more easily.
Author : Jianchao Cai
Publisher : MDPI
ISBN 13 : 3038977942
Total Pages : 258 pages
Book Rating : 4.0/5 (389 download)
Download or read book Emerging Advances in Petrophysics written by Jianchao Cai and published by MDPI. This book was released on 2019-04-18 with total page 258 pages. Available in PDF, EPUB and Kindle. Book excerpt: Due to the influence of pore-throat size distribution, pore connectivity, and microscale fractures, the transport, distribution, and residual saturation of fluids in porous media are difficult to characterize. Petrophysical methods in natural porous media have attracted great attention in a variety of fields, especially in the oil and gas industry. A wide range of research studies have been conducted on the characterization of porous media covers and multiphase flow therein. Reliable approaches for characterizing microstructure and multiphase flow in porous media are crucial in many fields, including the characterization of residual water or oil in hydrocarbon reservoirs and the long-term storage of supercritical CO2 in geological formations. This book gathers together 15 recent works to emphasize fundamental innovations in the field and novel applications of petrophysics in unconventional reservoirs, including experimental studies, numerical modeling (fractal approach), and multiphase flow modeling/simulations. The relevant stakeholders of this book are authorities and service companies working in the petroleum, subsurface water resources, air and water pollution, environmental, and biomaterial sectors.
Author : Xiaomeng Dong
Publisher :
ISBN 13 :
Total Pages : 0 pages
Book Rating : 4.:/5 (133 download)
Download or read book Quantification of Mutual Mass Transfer of Gas-Light Oil Systems at High Pressures and Elevated Temperatures written by Xiaomeng Dong and published by . This book was released on 2019 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Numerous tight oil resources that are characterized by both low porosity and permeability have been found in North America during past decades. Due to the extremely low permeability, water injection has found its limitation with its relatively low injectivity. Alternatively, gas injection, such as CO2, N2, hydrocarbon gas, and flue gas, has been made physically possible for enhancing oil recovery under certain conditions, during which molecular diffusion is of great importance. Due to the affordability and sustainability of CO2, N2 and flue gas have been found to be costeffective for enhancing hydrocarbon recovery to a certain extent. Physically, there exists two-way mass transfer between the injected gas and light oil, though the light component extraction has been theoretically neglected. Therefore, it is essential to quantify the mutual mass transfer of gas-light oil systems under reservoir conditions. In this study, a novel and pragmatic technique has been developed to quantify mutual mass transfer between a gas and light oil by dynamic volume analysis. Experimentally, diffusion tests for a CO2-light oil system, a N2-light oil system, and two flue gas-light oil systems, have been conducted at a constant temperature and pressure with a pressure/volume/temperature (PVT) system, while the dynamic swelling factors of oil phase are measured and recorded continuously during the experiments. Gas samples have been collected at end of each diffusion experiment to measure gas compositions by performing gas chromatography (GC) analysis. Theoretically, by combining Fick's second law and Peng-Robinson equation of state, the diffusion coefficients of both gas components and oil phase can be determined once the discrepancies between the measured and calculated dynamic swelling factors and gas compositions have been minimized simultaneously. At end of diffusion experiments, the swelling factor measured for the CO2-light oil system is 1.029, which is higher than that of N2-light oil system (i.e., 1.005). For the two flue gas-light oil systems, the enriched flue gas, which has a higher CO2 concentration, results in a higher swelling factor (i.e., 1.013) at end of diffusion experiment, comparing with that of flue gas-light oil system (i.e., 1.009). Besides, based on the GC analysis results, light components have been found in the gas phase, which proves that there exists two-way mass transfer between gas and oil phases. For the CO2-light oil system and N2-light oil system, at temperature of 336.15 K, the diffusion coefficients of CO2 and N2 are determined to be 12.87×10-9 m2/s at pressure of 2170 kPa and 1.35×10-9 m2/s at pressure of 5275 kPa, respectively. The diffusion coefficients of light oil in gas phase are determined to be 6.04×10-11 m2/s for the CO2- light oil system and 0.26×10-11 m2/s for the N2-light oil system under the corresponding conditions. Similarly, for the enriched flue gas-light oil system, the individual diffusion coefficients determined for CO2 and N2 are 8.35×10-9 m2/s and 1.52×10-9 m2/s at temperature of 336.15 K and pressure of 5275 kPa, respectively, while that of oil in gas phase is 0.07×10-11 m2/s. For the flue gas-light oil system, at the same condition, the individual diffusion coefficients calculated for CO2 and N2 are 6.42×10-9 m2/s and 2.19×10-9 m2/s, respectively, while that of oil in gas phase is 0.08×10-11 m2/s.
Author : Karen Schou Pedersen
Publisher : CRC Press
ISBN 13 : 1420018256
Total Pages : 423 pages
Book Rating : 4.4/5 (2 download)
Download or read book Phase Behavior of Petroleum Reservoir Fluids written by Karen Schou Pedersen and published by CRC Press. This book was released on 2006-11-01 with total page 423 pages. Available in PDF, EPUB and Kindle. Book excerpt: Understanding the phase behavior of the various fluids present in a petroleum reservoir is essential for achieving optimal design and cost-effective operations in a petroleum processing plant. Taking advantage of the authors' experience in petroleum processing under challenging conditions, Phase Behavior of Petroleum Reservoir Fluids introdu
Author : Vijitha Mohan
Publisher :
ISBN 13 :
Total Pages : 98 pages
Book Rating : 4.:/5 (992 download)
Download or read book Mass Transfer Studies in Heavy Oil Recovery Using Solvents written by Vijitha Mohan and published by . This book was released on 2017 with total page 98 pages. Available in PDF, EPUB and Kindle. Book excerpt: "Heavy oil, sometimes called bitumen, is known for its high viscosity (above 100 cp) and low API gravity (below 22°). In most cases, viscosity reduction is needed for the final product. There is a considerable amount of heavy oil in Alberta, Canada and the world's largest heavy oil deposit is in Venezuela. Yet less than 1% of it can be recovered because of its high viscosity. For shallow reservoirs, it is possible to resort to open cast mining. For deeper reservoirs, steam is used at ~ 350 °C which gets the oil viscosity reduced to 1cp, which can now be drained out. This process requires large amount of water to make steam, the used water cannot be reused due to presence of high levels of bitumen in it and is currently leading to pollution. The recovered bitumen being highly viscous needs a diluent like naphtha for transportation. Therefore another method is devised which involves using gaseous or liquid solvents directly to bring down the viscosity of bitumen. One such method, vapor extraction (VAPEX) process uses gaseous solvents like hydrocarbon solvents and CO2 to reduce bitumen viscosity. Vaporized solvents is introduced laterally to bitumen to reduce its viscosity and the less viscous bitumen drains under gravity. Solubility of solvents in bitumen is analyzed first. As solvents solubilize, it diffuses into bitumen and the diffusivity is strongly concentration dependent. The concentration dependence of solvent diffusivity in bitumen is measured next. Knowing the solubility and diffusivity of solvents, a model is used next to simulate oil recovery. It predicts an optimum solvent for this oil recovery process"--Abstract, page iv.
Author : Zehua Chen
Publisher :
ISBN 13 :
Total Pages : 0 pages
Book Rating : 4.:/5 (133 download)
Download or read book Quantification of Phase Behaviour and Physical Properties of Solvents-Heavy Oil/Bitumen-Water Systems at High Pressures and Elevated Temperatures written by Zehua Chen and published by . This book was released on 2019 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Due to the excess heat loss of steam assisted gravity drainage (SAGD) processes and low oil production rate of solvent-based processes, the expanding solvent SAGD (ES-SAGD) process has been considered as a promising technique for enhancing heavy oil/bitumen recovery. The main ES-SAGD mechanisms include the heat transferred and dissolution of solvents into the heavy oil/bitumen to swell it and reduce its viscosity, which is closely related to the phase behaviour of solvents-heavy oil/bitumen-water systems. Thus, it is of fundamental and practical importance to accurately quantify the phase behaviour and physical properties of the aforementioned systems. A pragmatic technique has been developed to optimize the reduced temperature for acentric factor for the Peng-Robinson equation of state (PR-EOS) and Soave-Redlich- Kwong equation of state (SRK-EOS) by minimizing the deviation between the measured and calculated vapour pressures. The reduced temperature has its optimum value of 0.59 for the two EOSs, while 0.60 is recommended for practical use. The mutual solubility for n-alkanes/n-alkylbenzenes-water pairs is correlated using the PR-EOS together with the two newly modified alpha functions. The binary interaction parameters (BIPs) for both aqueous phase and liquid hydrocarbon phase are generalized as functions of reduced temperatures and carbon numbers of hydrocarbons, reproducing the experimental measurements well. Then, the modified PR-EOS model is successfully applied to predict the multi-phase compositions and three-phase upper critical ending points (UCEPs) for n-alkane-CO2-water mixtures. A new correlation has been developed to calculate the redefined acentric factor for pseudocomponents (PCs), while new BIP correlations are proposed respectively for ii toluene-water pair and heavy oil/bitumen-water pairs. The BIP correlation for heavy oil/bitumen-water pairs is validated by the measured water solubility in other oils. The newly developed model is found to accurately predict the measured ALV/AL (A is the aqueous phase, L represents the oleic phase, and V denotes the vapour phase) and LV/L boundaries with an overall average absolute relative deviation (AARD) of 4.5% and solvent solubility in the oleic phase with an overall AARD of 9.4%, respectively. Two new methods have been proposed to predict the density/swelling factor for solvents-heavy oil/bitumen/water mixtures, i.e., one is a new volume translation (VT) strategy for PR-EOS, while the other is the ideal mixing rule with effective density (IME) calculated using a newly developed tangent-line method. It is found that both of these two methods are accurate enough, while the IM-E is better than the VT PR-EOS. Experiments for C3H8/CO2-Lloydminster heavy oil/water systems have been performed in a temperature range of 328.7-432.3 K. A dynamic volume analysis method is proposed to simultaneously simulate the total volume and height of vapour/oleic phase interface, while a new framework incorporated with the modified PR-EOS can be used to accurately predict the solvent solubility, phase boundary, and phase density for the aforementioned systems. Also, six widely used mixing rules have been respectively evaluated, while water is incorporated using the ideal mixing rule. The order of the best ones in their accuracy is the volume-based power law > the weight-based power law > the weight-based Cragoe's mixing rule. The effective density rather than real density of dissolved gas should be used for all the volume-based mixing rules.
Author : Dayanand Saini
Publisher : Springer
ISBN 13 : 3319955462
Total Pages : 115 pages
Book Rating : 4.3/5 (199 download)
Download or read book CO2-Reservoir Oil Miscibility written by Dayanand Saini and published by Springer. This book was released on 2018-06-25 with total page 115 pages. Available in PDF, EPUB and Kindle. Book excerpt: This SpringerBrief critically examines the latest experimental and non-experimental approaches used for the fast and reliable characterization and determination of CO2-reservoir oil miscibility in terms of the minimum miscibility pressure (MMP). This book serves as a one-stop source for developing an enhanced understanding of these available methods, and specifically documents, analyses, and evaluates their suitability and robustness for depicting and characterizing the phenomenon of CO2-reservoir oil miscibility in a fast and cost-effective manner. Such information can greatly assist a project team in selecting an appropriate MMP determination method as per the project’s need at a given project’s stage, be that screening, design, or implementation. CO2-Reservoir Oil Miscibility: Experiential and Non-Experimental Characterization and Determination Approaches will be of interest to petroleum science and engineering professionals, researchers, and undergraduate and graduate students engaged in CO2 enhanced oil recovery (EOR) and/or simultaneous CO2-EOR and storage projects and related research. It may also be of interest to engineering and management professionals within the petroleum industry who have responsibility for implementing CO2-EOR projects.
Author : Mohammed Almabrouk Ali Ahmad
Publisher :
ISBN 13 :
Total Pages : 94 pages
Book Rating : 4.:/5 (842 download)
Download or read book Displacement of Heavy Oil by Carbon Dioxide in a Tube written by Mohammed Almabrouk Ali Ahmad and published by . This book was released on 2012 with total page 94 pages. Available in PDF, EPUB and Kindle. Book excerpt: "After using primary and secondary oil recovery methods, about two third of the original oil in place is left behind in the reservoir. Enhanced oil recovery (EOR) methods are being used to recover that oil. CO2 flooding is one of the EOR methods that is used to recover the oil. The interest here lies in recovery of heavy oils. The dissolution of CO2 in oil reduces oil viscosity and swells it, making it easier to displace the oil. FLUENT is used to solve the problem of CO2 displacing heavy oil in a tube. Different velocities/capillary numbers (Ca) and different tube radii are used as input into FLUENT to solve different cases. The oil film thickness that left behind (h[subscript infinity]) is reported both without mass transfer and with mass transfer. The oil film thickness that is left behind, h[subscript infinity] is decreased when capillary number is decreased. When there is no mass transfer, the non-dimensional film thickness left behind h[subscript infinity]/R plotted against capillary number Ca fit Bretherton line. Even under mass transfer of CO2 into oil, bubbles show Bretherton-type behavior. Convection in this case opposes the mass transfer and limits how much CO2 can dissolve in oil"--Abstract, Leaf iii.
Author :
Publisher :
ISBN 13 :
Total Pages : 404 pages
Book Rating : 4.0/5 ( download)
Download or read book Energy Research Abstracts written by and published by . This book was released on 1992 with total page 404 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Author : Zhaomin Li
Publisher : Gulf Professional Publishing
ISBN 13 : 0128223030
Total Pages : 438 pages
Book Rating : 4.1/5 (282 download)
Download or read book Gas Injection Methods written by Zhaomin Li and published by Gulf Professional Publishing. This book was released on 2022-09-24 with total page 438 pages. Available in PDF, EPUB and Kindle. Book excerpt: The Enhanced Oil Recovery Series delivers a multivolume approach that addresses the latest research on various types of EOR. The second volume in the series, Gas Injection Methods, helps engineers focus on the latest developments in one of the fastest growing areas. Different techniques are described in addition to the latest technology such as data mining and unconventional reservoirs. Supported field case studies are included to show a bridge between research and practical application, making it useful for both academics and practicing engineers. Structured to start with an introduction on various gas types and different gas injection methods, screening criteria for choosing gas injection method, and environmental issues during gas injection methods, the editors then advance on to more complex content, guiding the engineer into newer topics involving CO2 such as injection in tight oil reservoirs, shale oil reservoirs, carbonated water, data mining, and formation damage. Supported by a full spectrum of contributors, this book gives petroleum engineers and researchers the latest research developments and field applications to drive innovation for the future. Helps readers understand the latest research and practical applications specific to foam flooding and gas injection Provides readers with the latest technology, including nanoparticle-stabilized foam for mobility control and carbon storage in shale oil reservoirs Teaches users about additional methods such as data mining applications and economic and environmental considerations
