The Interaction of Asphaltenes with Solvents Water and Clays During Bitumen Extraction through Solvent-Steam Injection
- Taniya Kar (Texas A&M University) | Berna Hascakir (Texas A&M University)
- Document ID
- Society of Petroleum Engineers
- SPE Heavy Oil Conference and Exhibition, 6-8 December, Kuwait City, Kuwait
- Publication Date
- Document Type
- Conference Paper
- 2016. Society of Petroleum Engineers
- 5.7.2 Recovery Factors, 5.7 Reserves Evaluation, 4 Facilities Design, Construction and Operation, 5 Reservoir Desciption & Dynamics, 4.3 Flow Assurance, 1.8 Formation Damage, 5.1 Reservoir Characterisation, 5.1.1 Exploration, Development, Structural Geology, 5.4.6 Thermal Methods, 4.3.3 Aspaltenes, 1.8 Formation Damage
- SARA fractions, Asphaltenes, Steam-Solvent
- 1 in the last 30 days
- 123 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
Co-injection of solvents with steam increases the oil recovery factor and reduces significantly the environmental impact of steam injection processes. Nevertheless, the quality of the extracted bitumen is important to evaluate the process performance which is affected by the solvent-bitumen interaction. This interaction might lead to emulsion formation and asphaltene precipitation. These unfavorable flow assurance problems are associated with the behavior of asphaltenes in solvent-steam processes. Thus, it is important to observe the factors affecting the interfacial forces among asphaltenes-solvents-water prior to any field application. This work investigates the fundamental aspects of the solvent-bitumen interaction during solvent-steam injection processes. A Canadian bitumen was studied. The role of individual saturates, aromatics, resins, and asphaltenes (SARA) fractions of bitumen on solvent-steam process performance was examined both at liquid and vapor water conditions. The behavior of asphaltenes was investigated through systematic microscopic analyses with the absence and presence of reservoir rock. Also, the asphaltenes behavior after toluene (asphaltene soluble aromatic hydrocarbon) and n-pentane (asphaltene insoluble aliphatic hydrocarbon) addition was observed under the microscope. While toluene completely dissolves asphaltenes immediately, n-pentane leads to asphaltenes precipitation with bigger clusters. After these control experiments, the same tests were carried out with the addition of saturates and/or aromatics fractions of crude oil to the asphaltenes fraction. It showed that saturates lead to aggregation of asphaltene clusters at a higher rate than n-pentane, while aromatics dissolve the asphaltenes at a lower rate than toluene. Hence, it was found that the asphaltenes precipitating power of saturates is higher than n-pentane. However, results reveal that asphaltenes mainly interact with water and aromatics fraction of bitumen. The water-asphaltene interaction causes the emulsion formation and the aromatics-clay interaction is responsible for clay migration and higher amount of asphaltene precipitation. The results of this study help us to understand the factors acting upon displacement of bitumen during solvent-steam processes.
|File Size||972 KB||Number of Pages||8|
Ali, S. M.; Abad, B. (1976). Bitumen recovery from oil sands, using solvents in conjunction with steam. Journal of Canadian Petroleum Technology, 15(03). PETSOC-76-03-11-P. Doi: 10.2118/76-03-11.
Binner, E. R., Robinson, J. P., Silvester, S. A., Kingman, S. W., Lester, E. H. (2014). Investigation into the mechanisms by which microwave heating enhances separation of water-in-oil emulsions. Fuel, 116, 516–521. Doi: 10.1016/j.fuel.2013.08.042.
Coelho, R.S.C., Ovalles, C., Benson, I.P., Hascakir, B. (2016). Clay-Asphaltene Interactions during Hybrid Solvent-Steam Injection into Bitumen Reservoirs, SPE Canada Heavy Oil Technical Conference, 7-9 June, Calgary, Alberta, Canada, Society of Petroleum Engineers. SPE-180723-MS. Doi: 10.2118/180723-MS.
Demir, A. B., Bilgesu, H. I., Hascakir, B. (2016). The Effect of Clay and Salinity on Asphaltene Stability. In SPE Western Regional Meeting. 2016, May. Society of Petroleum Engineers. SPE-180425-MS. Doi: 10.2118/180425-MS.
Hascakir, B. (2016). How to select the right solvent for solvent-aided steam injection processes, Journal of Petroleum Science and Engineering, 146, 746–751. Doi: 10.1016/j.petrol.2016.07.038.
Hong, J. S. (2016). Aggregation of hydrophilic/hydrophobic montmorillonites at oil-water interface. Applied Clay Science. 119, 257–265. Doi: 10.1016/j.clay.2015.10.025.
Jewell, D. M., Weber, J. H., Bunger, J. W., Plancher, H., Latham, D. R. (1972). Ion-exchange, coordination, and adsorption chromatographic separation of heavy-end petroleum distillates. Analytical Chemistry. 44(8), 1391–1395. Doi: 10.1021/ac60316a003.
Kar, T., Hascakir, B. (2015). The Role of Resins, Asphaltenes, and Water in Water-Oil Emulsion Breaking with Microwave Heating. Energy & Fuels. 29(6), 3684–3690. Doi: 10.1021/acs.energyfuels.5b00662.
Kar, T., Mukhametshina, A., Unal, Y., Hascakir, B. (2015). The Effect of Clay Type on Steam-Assisted-Gravity-Drainage Performance. Journal of Canadian Petroleum Technology. SPE-173795-PA. Doi: 10.2118/173795-PA.
Kar, T., Ovalles, C., Rogel, E., Vien, J., Hascakir, B. (2016). The residual oil saturation determination for Steam Assisted Gravity Drainage (SAGD) and Solvent-SAGD. Fuel, 172, 187–195. Doi: 10.1016/j.fuel.2016.01.029.
Kokal, S. L. (2005). Crude oil emulsions: A state-of-the-art review. SPE Production & facilities 20(01): 5–13. SPE 77497-PA. Doi: 10.2118/77497-PA.
Kovscek, A. (2012). Emerging challenges and potential futures for thermally enhanced oil recovery. Journal of Petroleum Science and Engineering 98: 130–143. Doi: 10.1016/j.petrol.2012.08.004.
Leontaritis, K., Amaefule, J., Charles, R. E. (1994). A systematic approach for the prevention and treatment of formation damage caused by asphaltene deposition. SPE Production & Facilities 9(03): 157–164. SPE 23810-PA. Doi: 10.2118/23810-PA.
Magic Sand Movie: MAGICSA3. MOV (2000). Journal of Chemical Education, 77(1), 40A. Doi: 10.1021/ed077p40.3.
McLean, J. D.; Kilpatrick, P. K. (1997). Effects of asphaltene aggregation in model-toluene mixtures on stability of water-in-oil emulsions. Journal of Colloid and Interface Science, Vol. 196, p 23–34. Doi: 10.1006/jcis.1997.5177.
Mohammadzadeh, O., Rezaei, N., Chatzis, I. (2010). Pore-Level Investigation of Heavy Oil and Bitumen Recovery Using Solvent? Aided Steam Assisted Gravity Drainage (SA-SAGD) Process. Energy & Fuels 24(12): 6327–6345. Doi: 10.1021/ef100621s.
Mojelsky, T. W., Ignasiak, T. M., Frakman, Z., McIntyre, D. D., Lown, E. M., Montgomery, D. S., Strausz, O. P. (1992). Structural features of Alberta oil sand bitumen and heavy oil asphaltenes. Energy & Fuels, 6(1), 83–96. Doi: 10.1021/ef00031a013.
Mukhametshina, A., Hascakir, B. (2014). Bitumen extraction by expanding solvent-steam assisted gravity drainage (ES-SAGD) with asphaltene solvents and non-solvents. SPE Heavy Oil Conference, Canada, 10-12 June, Calgary, Alberta. Society of Petroleum Engineers. SPE 170013-MS. Doi: 10.2118/170013-MS.
Mukhametshina, A., Kar, T., Hascakir, B. (2016). Asphaltene Precipitation During Bitumen Extraction With Expanding-Solvent Steam-Assisted Gravity Drainage: Effects on Pore-Scale Displacement. SPE Journal, 21(02), 380–392. SPE-170013-PA. Doi: 10.2118/170013-PA.
Mullins, O. C. (2008). Review of the molecular structure and aggregation of asphaltenes and petroleomics. SPE Journal. 13(01), 48–57. Doi: 10.2118/95801-PA.
Nasr, T. N., Beaulieu, G., Golbeck, H., (2003). Novel Expanding Solvent-SAGD Process "ES-SAGD". Journal of Canadian Petroleum Technology 42 (1). PETSOC-03-01-TN. Doi: 10.2118/03-01-TN.
Nciri, H., Benna-Zayani, M., Stambouli, M., Kbir-Ariguib, N., Trabelsi-Ayadi, M., Rosilio, V., Grossiord, J. L. (2009). Influence of clay addition on the properties of olive oil in water emulsions. Applied Clay Science. 43(3), 383–391. Doi: 10.1016/j.clay.2008.11.006.
Prakoso, A. A., Punase, A. D., Hascakir, B. (2015). A Mechanistic Understanding of Asphaltene Precipitation from Varying Saturate Concentration Perspective. In SPE Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers. SPE-177280-MS. Doi: 10.2118/177280-MS.
Prakoso, A., Punase, A., Klock, K., Rogel, E., Ovalles, C., Hascakir, B. (2016). Determination of the Stability of Asphaltenes Through Physicochemical Characterization of Asphaltenes. In SPE Western Regional Meeting, Anchorage, Alaska. May. Society of Petroleum Engineers. SPE-180422-MS. Doi: 10.2118/180422-MS.
Punase, A., Prakoso, A., Hascakir, B. (2016). The Polarity of Crude Oil Fractions Affects the Asphaltenes Stability. In SPE Western Regional Meeting, Anchorage, Alaska. Society of Petroleum Engineers. SPE-180423-MS. Doi: 10.2118/180423-MS.
Shultz, M. J., Vu, T. H., Meyer, B., Bisson, P. (2011). Water: A responsive small molecule. Accounts of chemical research. 45(1), 15–22. Doi: 10.1021/ar200064z.
Stape, P., Ovalles, C., Hascakir, B. (2016). Pore Scale Displacement Mechanism of Bitumen Extraction with High Molecular Weight Hydrocarbon Solvents, 20th SPE Improved Oil Recovery Conference, 9-13 April, Tulsa, Oklahoma, USA, Society of Petroleum Engineers. SPE-179608-MS. Doi: 10.2118/179608-MS.
Wiehe, I. A. (2012). Asphaltene solubility and fluid compatibility. Energy & Fuels. 26(7), 4004–4016. Doi: 10.1021/ef300276x.
Yarranton, H. W., Sztukowski, D. M., Urrutia, P. (2007). Effect of interfacial rheology on model emulsion coalescence: I. Interfacial rheology. Journal of Colloid and Interface Science, Vol. 310 (1), p 253–259. Doi: 10.1016/j.jcis.2007.01.071.