Simulation of Water and Condensate Blockage and Solvent Treatments in Tight Formations Using Coupled Three-Phase Flash and Capillary Pressure Models
- Sajjad S. Neshat (The University of Texas at Austin) | Ryosuke Okuno (The University of Texas at Austin) | Gary A. Pope (The University of Texas at Austin)
- Document ID
- Society of Petroleum Engineers
- SPE Improved Oil Recovery Conference, 14-18 April, Tulsa, Oklahoma, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 5.1 Reservoir Characterisation, 4 Facilities Design, Construction and Operation, 5.1 Reservoir Characterisation, 5.2.2 Fluid Modeling, Equations of State, 5.2.1 Phase Behavior and PVT Measurements, 4.1 Processing Systems and Design, 5.5 Reservoir Simulation, 5 Reservoir Desciption & Dynamics, 4.1.2 Separation and Treating, 5.2 Fluid Characterization
- phase behavior, Heterogeneity, capillary pressure, unconventional, compositional simulation
- 6 in the last 30 days
- 273 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
Water and condensate blockage near production wells in unconventional reservoirs can significantly reduce oil and gas production rates. This paper presents a new approach for more accurate modelling of liquid blockage in tight oil and gas reservoirs and investigates the use of solvents for blockage removal. A cubic equation of state is used to model the phase behavior of three-phase mixtures of solvent, hydrocarbons and water. The three-phase flash model is coupled with a rigorous three-phase capillary pressure model to account for the effect of capillary pressure. The capillary pressure function includes the impact of several important petrophysical properties such as pore size distribution and wettability. A compositional simulator is used to simulate the effectiveness of using methanol, dimethyl ether or CO2 to remove liquid blockage and increase production rate.
|File Size||1 MB||Number of Pages||14|
Abouei, A., Darabi., H., Sepehrnoori, K., 2018. "Risk management of miscible gas flooding in asphaltic reservoirs," presented at SPE Improved Oil Recovery, Tulsa, OK, 14-18 April. SPE-190295-MS. https://doi.org/10.2118/190295-MS.
Al-Anazi, H. A., Walker, J. G., Pope, G. A., ., 2005. "A successful methanol treatment in a gas/condensate reservoir: field application," SPE Prod & Fac 20 (1): 60-69. SPE-80901-PA. http://dx.doi.org/10.2118/80901-PA.
Bang, V., Pope, G.A., Sharma, M. M., 2010. "Phase -behavior study of hydrocarbon/water/methanol mixtures ar reservoir conditions" SPEJ 15(04): 952-962. SPE-102100-PA. https://doi.org/10.2118/102100-PA.
Bang, V., Pope, G.A., Sharma, M. M., Baran, J., Ahmadi, M., 2010. "A new solution to restore productivity of gas wells with condensate and water blocks" SPE Res. Eva. & Eng. 13(02): 323-331. SPE-102100-PA. https://doi.org/10.2118/116711-PA.
Bertoncello, A., Wallace, J., Blyton, C., Honarpour, M., Kabir, S., 2014. "Imbibition and water blockage in unconventional reservoirs: well-management implications during flowback and early production," SPE Res Eva & Eng 17 (04): 497-506. SPE-167698-PA. https://doi.org/10.2118/167698-PA.
Dria, D., Pope, G., and Sepehrnoori, K., 1993. "Three-phase gas/oil/brine relative permeabilities measured under CO2 flooding conditions," SPE Res Eng 8(02): 143-150. SPE-20184-PA. http://dx.doi.org/10.2118/20184-PA.
Ganjdanesh, R., Rezaveisi. R.Pope, G., Sepehrnoori, K. 2016. "Treatment of condensate and water blocks in hydraulic-fractured shale-gas/condensate reservoirs," SPE J 21(02): 665-674. SPE-175145-PA. http://dx.doi.org/10.2118/175145-PA.
Gupta, D. V. S., 2009 "Unconventional fracturing fluids for tight gas reservoirs," presented at the SPE hydraulic fracturing technology conference, Woodlands, Texas, 19-21 January. SPE-119424-MS. https://doi.org/10.2118/119424-MS.
Habibi, A., Yassin, M. R., Dehghanpour, H., Bryan, D., 2016. "Experimental investigation of CO2-oil interactions in tight rocks: a Montney case study," Fuel, 203 (1): 853-867. https://doi.org/10.1016/j.fuel.2017.04.077
Jiamin, J., Younis, R., 2016. "Compositional simulation of enhanced hydrocarbons recovery for fractured shale gas-condensate reservoirs with the effects of capillary pressure and multi-component mechanisms," Nat Gas Sci & Eng 34: 1,262-1,275. https://doi.org/10.1016/j.jngse.2016.08.006.
Kalla, S., Leonardi, S. A., Berry, D. W., Poore, L. D., Sahoo, H., Kudva, R., Braun, E. M. 2015. "Factors that affect gas-condensate relative permeability," SPE J 18(01): SPE-173177-PA. http://dx.doi.org/10.2118/173177-PA.
Nelson, P., 2009. "Pore-throat sizes in sandstones, tight sandstones, and shales," AAPG 93 (3). https://doi.org/10.1306/10240808059.
Neshat, S. S., Pope. G. A., 2017. "Compositional three-phase relative permeability and capillary pressure models using Gibbs free energy," presented at the SPE Reservoir Simulation Conference, Montgomery, Texas, 20-22 February. SPE-182592-MS. https://doi.org/10.2118/182592-MS.
Neshat, S. S., Okuno, R., Pope. G. A., 2017. "A rigorous solution to the problem of phase behavior in unconventional formations with high capillary pressure," presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, 9-11 November. SPE-187260-MS. https://doi.org/10.2118/187260-MS.
Pope, G., Wu, W., Narayanaswamy, G., Delshad, M., Sharma, M. M., Wang, P. 2000. "Modelling relative permeability effects in gas-condensate reservoirs with a new trapping model," J Res Eval & Eng 3(02). SPE-62497-PA. http://dx.doi.org/10.2118/62497-PA.
Ratnakar, R. R., Dindoruk, B., Wilson, L., 2017. "Phase behavior experiments and PVT modeling of DME-brine-crude oil mixtures based on Huron-Vidal mixing rules for EOR applications," Fluid Phase Equ. 24: 49-62. https://doi.org/10.1016/j.fluid.2016.11.021
Rezaveisi, M., Sepehrnoori, K., Pope, G., Johns, R., 2015 "Compositional simulation including effect of capillary pressure on phase behavior," presented at the SPE Annual Technical Conference and Exhibition, Houston, Texas, 28-30 September. SPE-187260-MS. https://doi.org/10.2118/187260-MS.
Sanaei, A., Jamili, A., Callard, J., 2014. "Effect of pore size distribution and connectivity on phase behavior and gas condensate production from unconventional resources," presented at the SPE Unconventional Resources Conference, 1-3 April, Woodlands, TX. SPE-168970-MS. https://doi.org/10.2118/168970-MS
Sayed, M. A., Al-Muntasheri, G. A., 2016. "Mitigation of the effect of condensate banking: a critical review," SPE Pro & Ope 31 (02): 85-102. SPE-168153-PA. https://doi.org/10.2118/168153-PA.
Schechter, D. S., Guo, B., 1988. "Parachors based on modern physics and their uses in IFT prediction of reservoir fluids," SPEJ 1 (03), p. 207-217. https://doi.org/10.2118/30785-PA.
Siripatrachai, N., Ertekin, T., Johns, R., 2017. "Compositional simulation of hydraulic fractured tight formation considering the effect of capillary pressure on phase behavior," SPEJ 22 (04): 1,046-1,064. SPE-149660-PA. https://doi.org/10.2118/179660-PA
Tallon, S., Fenton, K., 2010. "The solubility of water in mixture of dimethyl ether and carbon dioxide," Fluid Phase Equ 298 (1): 60-66. https://doi.org/10.1016/j.fluid.2010.07.009