Documents disponibles écrits par cet auteur

Determination of water-in-oil emulsion viscosity in porous media / Mohamed Arhuoma in Industrial & engineering chemistry research, Vol. 48 N° 15 (Août 2009) 

Public ISBD [article]  in Industrial & engineering chemistry research > Vol. 48 N° 15 (Août 2009) . - pp. 7092–7102 Titre : Determination of water-in-oil emulsion viscosity in porous media Type de document : texte imprimé Auteurs : Mohamed Arhuoma, Auteur ; Mingzhe Dong, Auteur ; Daoyong Yang, Auteur Année de publication : 2009 Article en page(s) : pp. 7092–7102 Note générale : Chemical engineering Langues : Anglais (eng) Mots-clés : Water-in-oil  emulsions  Porous  media Résumé : Experiments have been conducted to determine the viscosities of water-in-oil (W/O) emulsions in porous media. W/O emulsions were first prepared for different volume fractions of the dispersed phase and then characterized for their properties and rheological parameters including flow index and consistency constant. All prepared W/O emulsions with volume fractions between 6.78% and 33.48% were found to behave as non-Newtonian shear-thinning fluids at fairly high viscosities. The viscosities of the emulsions were measured during emulsion flow in three types of sandpacks. A correlation of the viscosities of the W/O emulsions in porous media was developed by performing a regression on the experimentally measured data. The newly developed correlation was validated, and a sensitivity analysis was performed to examine the effects of tortuosity and emulsion quality. The emulsion quality has a dominant effect on the viscosity of the W/O emulsions and has been included in the correlation for the first time to achieve accurate predictions of the viscosities of W/O emulsions in porous media. The existing correlations for oil-in-water (O/W) emulsions provide underestimated predictions for the viscosities of W/O emulsions, whereas the droplet size distribution does not have a significant impact on the viscosity of the W/O emulsions tested in this study. En ligne : http://pubs.acs.org/doi/abs/10.1021/ie801818n [article] Determination of water-in-oil emulsion viscosity in porous media [texte imprimé] / Mohamed Arhuoma, Auteur ; Mingzhe Dong, Auteur ; Daoyong Yang, Auteur . - 2009 . - pp. 7092–7102. Chemical engineering Langues : Anglais (eng) in Industrial & engineering chemistry research > Vol. 48 N° 15 (Août 2009) . - pp. 7092–7102 Mots-clés : Water-in-oil  emulsions  Porous  media Résumé : Experiments have been conducted to determine the viscosities of water-in-oil (W/O) emulsions in porous media. W/O emulsions were first prepared for different volume fractions of the dispersed phase and then characterized for their properties and rheological parameters including flow index and consistency constant. All prepared W/O emulsions with volume fractions between 6.78% and 33.48% were found to behave as non-Newtonian shear-thinning fluids at fairly high viscosities. The viscosities of the emulsions were measured during emulsion flow in three types of sandpacks. A correlation of the viscosities of the W/O emulsions in porous media was developed by performing a regression on the experimentally measured data. The newly developed correlation was validated, and a sensitivity analysis was performed to examine the effects of tortuosity and emulsion quality. The emulsion quality has a dominant effect on the viscosity of the W/O emulsions and has been included in the correlation for the first time to achieve accurate predictions of the viscosities of W/O emulsions in porous media. The existing correlations for oil-in-water (O/W) emulsions provide underestimated predictions for the viscosities of W/O emulsions, whereas the droplet size distribution does not have a significant impact on the viscosity of the W/O emulsions tested in this study. En ligne : http://pubs.acs.org/doi/abs/10.1021/ie801818n

Experimental study of carbon dioxide diffusion in oil-saturated porous media under reservoir conditions / Zhaowen Li in Industrial & engineering chemistry research, Vol. 48 N° 20 (Octobre 2009) 

Public ISBD [article]  in Industrial & engineering chemistry research > Vol. 48 N° 20 (Octobre 2009) . - pp. 9307–9317 Titre : Experimental study of carbon dioxide diffusion in oil-saturated porous media under reservoir conditions Type de document : texte imprimé Auteurs : Zhaowen Li, Auteur ; Mingzhe Dong, Auteur Année de publication : 2010 Article en page(s) : pp. 9307–9317 Note générale : Chemical engineering Langues : Anglais (eng) Mots-clés : CO2  diffusion  coefficient  Oil-saturated  porous  media Résumé : For both CO2 enhanced oil recovery and CO2 sequestration in oil reservoirs, the diffusion of injected CO2 into oil-saturated porous media is of great significance in project design, risk assessments, economic evaluation, and performance forecast. However, the measurement of CO2 diffusion coefficient in liquid-saturated porous media under reservoir conditions has not been well-established due to the complications caused by density-induced natural convection in the CO2−oil systems. This paper presented a new method for measuring the effective CO2 diffusion coefficient in oil-saturated porous media under reservoir conditions. A core plug with the two end faces sealed was designed as the physical model for radial diffusion process. The measurement was conducted in a high-pressure diffusion cell with an oil-saturated core sample placed in the middle and the remaining void space of the cell filled by high-pressure CO2 sample. A small-pressure decay technique was employed to record the pressure change of the gas phase during the diffusion measurement. Because the oil phase contained in the porous medium swells as CO2 diffuses into it, the experiment essentially involves both diffusion and swelling-induced convection. To describe these processes involved in the measurement, a mathematical model along with numerical solutions was derived. The effective diffusion coefficient was determined by matching the experimental pressure decay curve with the corresponding mathematical model. The proposed method was demonstrated for oil-saturated Berea core samples at pressures ranging from 2.2 to 6.5 MPa. The measured pressure decay curves showed good agreement with the mathematical predictions using the best-fitted effective diffusion coefficients. The derived method can be readily implemented in laboratories that can handle high-pressure fluids; thus, this study provides a tool for studying CO2 diffusion in oil-saturated porous rocks. En ligne : http://pubs.acs.org/doi/abs/10.1021/ie900145c [article] Experimental study of carbon dioxide diffusion in oil-saturated porous media under reservoir conditions [texte imprimé] / Zhaowen Li, Auteur ; Mingzhe Dong, Auteur . - 2010 . - pp. 9307–9317. Chemical engineering Langues : Anglais (eng) in Industrial & engineering chemistry research > Vol. 48 N° 20 (Octobre 2009) . - pp. 9307–9317 Mots-clés : CO2  diffusion  coefficient  Oil-saturated  porous  media Résumé : For both CO2 enhanced oil recovery and CO2 sequestration in oil reservoirs, the diffusion of injected CO2 into oil-saturated porous media is of great significance in project design, risk assessments, economic evaluation, and performance forecast. However, the measurement of CO2 diffusion coefficient in liquid-saturated porous media under reservoir conditions has not been well-established due to the complications caused by density-induced natural convection in the CO2−oil systems. This paper presented a new method for measuring the effective CO2 diffusion coefficient in oil-saturated porous media under reservoir conditions. A core plug with the two end faces sealed was designed as the physical model for radial diffusion process. The measurement was conducted in a high-pressure diffusion cell with an oil-saturated core sample placed in the middle and the remaining void space of the cell filled by high-pressure CO2 sample. A small-pressure decay technique was employed to record the pressure change of the gas phase during the diffusion measurement. Because the oil phase contained in the porous medium swells as CO2 diffuses into it, the experiment essentially involves both diffusion and swelling-induced convection. To describe these processes involved in the measurement, a mathematical model along with numerical solutions was derived. The effective diffusion coefficient was determined by matching the experimental pressure decay curve with the corresponding mathematical model. The proposed method was demonstrated for oil-saturated Berea core samples at pressures ranging from 2.2 to 6.5 MPa. The measured pressure decay curves showed good agreement with the mathematical predictions using the best-fitted effective diffusion coefficients. The derived method can be readily implemented in laboratories that can handle high-pressure fluids; thus, this study provides a tool for studying CO2 diffusion in oil-saturated porous rocks. En ligne : http://pubs.acs.org/doi/abs/10.1021/ie900145c

Experimental study of diffusive tortuosity of liquid-saturated consolidated porous media / Zhaowen Li in Industrial & engineering chemistry research, Vol. 49 N° 13 (Juillet 2010) 

Public ISBD [article]  in Industrial & engineering chemistry research > Vol. 49 N° 13 (Juillet 2010) . - pp. 6231–6237 Titre : Experimental study of diffusive tortuosity of liquid-saturated consolidated porous media Type de document : texte imprimé Auteurs : Zhaowen Li, Auteur ; Mingzhe Dong, Auteur Année de publication : 2010 Article en page(s) : pp. 6231–6237 Note générale : Chemical engineering Langues : Anglais (eng) Mots-clés : Diffusive  tortuosity  Liquid-saturated  porous  media Résumé : Diffusive tortuosity factor is one of the key parameters in modeling solute diffusion in liquid-saturated porous media. However, the determination of diffusive tortuosity factor has to involve a diffusion process in liquid-saturated porous media, which was usually found complicated in laboratories. The incorrect use of diffusive tortuosity factor may cause significant errors in certain circumstances. This paper presents a method to evaluate the diffusive tortuosity factors for liquid-saturated consolidated porous media, i.e., sandstones, which are the typical porous media commonly encountered in contaminant transport in underground water and gas migration in liquid-saturated reservoirs. The proposed method applies two specific experiments to determine the diffusion coefficient in bulk liquid phase and the effective diffusion coefficient in liquid-saturated porous media, respectively. Diffusive tortuosity factor of the porous media is obtained by comparing the effective diffusion coefficient in porous media to the diffusion coefficient in bulk liquid. This study provides a procedure to evaluate the diffusive tortuosity factor for consolidated porous media and also the measured values of diffusive tortuosity factors for selected sandstone samples which can be used as input data for further studies. Another application of the proposed method is to determine the diffusion coefficient in bulk liquid phase for CO2 from the measured effective diffusion coefficients in porous media. En ligne : http://pubs.acs.org/doi/abs/10.1021/ie901765d [article] Experimental study of diffusive tortuosity of liquid-saturated consolidated porous media [texte imprimé] / Zhaowen Li, Auteur ; Mingzhe Dong, Auteur . - 2010 . - pp. 6231–6237. Chemical engineering Langues : Anglais (eng) in Industrial & engineering chemistry research > Vol. 49 N° 13 (Juillet 2010) . - pp. 6231–6237 Mots-clés : Diffusive  tortuosity  Liquid-saturated  porous  media Résumé : Diffusive tortuosity factor is one of the key parameters in modeling solute diffusion in liquid-saturated porous media. However, the determination of diffusive tortuosity factor has to involve a diffusion process in liquid-saturated porous media, which was usually found complicated in laboratories. The incorrect use of diffusive tortuosity factor may cause significant errors in certain circumstances. This paper presents a method to evaluate the diffusive tortuosity factors for liquid-saturated consolidated porous media, i.e., sandstones, which are the typical porous media commonly encountered in contaminant transport in underground water and gas migration in liquid-saturated reservoirs. The proposed method applies two specific experiments to determine the diffusion coefficient in bulk liquid phase and the effective diffusion coefficient in liquid-saturated porous media, respectively. Diffusive tortuosity factor of the porous media is obtained by comparing the effective diffusion coefficient in porous media to the diffusion coefficient in bulk liquid. This study provides a procedure to evaluate the diffusive tortuosity factor for consolidated porous media and also the measured values of diffusive tortuosity factors for selected sandstone samples which can be used as input data for further studies. Another application of the proposed method is to determine the diffusion coefficient in bulk liquid phase for CO2 from the measured effective diffusion coefficients in porous media. En ligne : http://pubs.acs.org/doi/abs/10.1021/ie901765d

A Model for direct estimation of wetting phase relative permeabilities using a multistep drainage process / Shengdong Wang in Industrial & engineering chemistry research, Vol. 51 N° 47 (Novembre 2012) 

Public ISBD [article]  in Industrial & engineering chemistry research > Vol. 51 N° 47 (Novembre 2012) . - pp. 15472-15483 Titre : A Model for direct estimation of wetting phase relative permeabilities using a multistep drainage process Type de document : texte imprimé Auteurs : Shengdong Wang, Auteur ; Mingzhe Dong, Auteur ; Jun Yao, Auteur Année de publication : 2013 Article en page(s) : pp. 15472-15483 Note générale : Industrial chemistry Langues : Anglais (eng) Mots-clés : Permeability  Wetting  Modeling Résumé : A new analytical model has been developed for determining the wetting phase relative permeabilities in a multiple gas―liquid drainage process. The multistep drainage process consists of a series of drainage processes with a tiered pressure-difference profile. With this model, the wetting phase relative permeabilities can be readily obtained through regression of the wetting phase recovery history. The assumptions used in deriving the analytical model are examined by numerical simulations. The agreement between the analytical and the numerical results indicates that these assumptions are reasonable and valid. Numerical simulations and laboratory results demonstrate that this model is effective for direct estimation of the wetting phase relative permeabilities in the multistep drainage process. ISSN : 0888-5885 En ligne : http://cat.inist.fr/?aModele=afficheN&cpsidt=26679668 [article] A Model for direct estimation of wetting phase relative permeabilities using a multistep drainage process [texte imprimé] / Shengdong Wang, Auteur ; Mingzhe Dong, Auteur ; Jun Yao, Auteur . - 2013 . - pp. 15472-15483. Industrial chemistry Langues : Anglais (eng) in Industrial & engineering chemistry research > Vol. 51 N° 47 (Novembre 2012) . - pp. 15472-15483 Mots-clés : Permeability  Wetting  Modeling Résumé : A new analytical model has been developed for determining the wetting phase relative permeabilities in a multiple gas―liquid drainage process. The multistep drainage process consists of a series of drainage processes with a tiered pressure-difference profile. With this model, the wetting phase relative permeabilities can be readily obtained through regression of the wetting phase recovery history. The assumptions used in deriving the analytical model are examined by numerical simulations. The agreement between the analytical and the numerical results indicates that these assumptions are reasonable and valid. Numerical simulations and laboratory results demonstrate that this model is effective for direct estimation of the wetting phase relative permeabilities in the multistep drainage process. ISSN : 0888-5885 En ligne : http://cat.inist.fr/?aModele=afficheN&cpsidt=26679668