Release:
2020. Vol. 6. № 1 (21)About the authors:
Alexander Ya. Gilmanov, Second Category Engineer, Department of Modeling of Physical Processes and Systems, Institute of Physics and Technology, University of Tyumen; a.y.gilmanov@utmn.ruAbstract:
This article discusses the construction of a physical and mathematical model of the steam cycle effect on oil reservoirs. Existing models require calculations in hydrodynamic simulators or significantly simplify the description of the motion of the heat front. Within the framework of the proposed model, a number of assumptions are introduced regarding the movement of the thermal interface between the heated oil located in the bottomhole zone and the oil whose temperature is equal to the initial one. It is assumed that this boundary has the form of a straight line in a rectangular coordinate system. Moreover, at the initial moment of time, the straight line is determined by two points: the value of the maximum power taken on the vertical axis, directed downward, and the maximum radius of heating on the horizontal axis. In the future, these parameters are reduced. It is assumed that over time, the interface between the “cold” and heated oil shifts parallel to its initial position with a decrease in the parameters that determine it. This approach to describing the displacement over time of this boundary is proposed for the first time.
The purpose of the article is to determine the flow rate of the well in the case of steam-thermal treatment of the formation, taking into account the size of the heated zone. In particular, the coolant injection cycle time and the characteristic time of the steam and thermal impregnation for the proposed model are determined.
The physical processes considered during the construction of this model are described by conservation laws.
The calculation of the area in which the heated oil will be located takes into account parameters such as flow rate and heat content of the coolant, reservoir thickness and thermal properties of the surrounding rocks. The article discusses the issues related to the relevance of the application of the methodology of vapor-cyclical effects on oil reservoirs.
The result of the developed model is the dependence of the oil production rate on time for the cyclic treatment of bottom-hole zones of wells. The proposed method allows us to analyze the development efficiency depending on the main technological parameters. Such calculations allow you to choose the most optimal development strategy, and therefore, increase oil recovery.
Keywords:
References:
Amerkhanov M. I. 2010. “Recovery of ultra-heavy oil”. Neftegazovaya vertical, no. 11, pp. 88-91. [In Russian]
Garushev A. R. 2008. “Analysis of the current state of the methods for producing high-viscosity oils and bitumen in the world”. Neftepromyslovoye delo, no. 10, pp. 4-8. [In Russian]
Mitrushkin D. A., Khabirova L. K. 2010. “Mathematical modeling for problems of recovery of high-viscosity oil”. Vestnik CKR Rosnedra, no. 1, pp. 52-59. [In Russian]
Osipov A. V., Solomatin A. G. 2011. “The influence of the duration of the period of oil production on the efficiency of cyclic steam stimulation of bottom-hole zones of wells”. Burenie i neft, no. 2, pp. 42-44. [In Russian]
Shevelev A. P. 2005. “Mathematical modeling of cyclic steam stimulation on oil reservoirs”. Cand. Sci. Phys-Math. diss. abstract. Tyumen: University of Tyumen. 23 pp. [In Russian]
Chen F., Liu H., Dong X., Wang Y., Zhang Q., Zhao D., Gai P., Yin F., Qu L. 2019. “A new analytical model to predict oil production for cyclic steam stimulation of horizontal wells”. Society of Petroleum Engineers. SPE-195291-MS. 19 pp. DOI: 10.2118/195291-MS
Han P., Chen K., You Y., Zhang X. 2019. “A new scheme of thermal properties for VOF method in heat transfer problems”. Proceedings of the 29^{th} International Ocean and Polar Engineering Conference (16-21 June, Honolulu, Hawaii, USA,), pp. 3030-3035.
Hoffman B. T., Rutledge J. M. 2019. “Mechanisms for huff-n-puff cyclic gas injection into unconventional reservoirs”. Society of Petroleum Engineers. SPE-195223-MS. 13 pp. DOI: 10.2118/195223-MS
Ji D., Harding T., Chen Z., Dong M., Liu H. 2019. “Modelling of electromagnetic heating process and its applications in oil sands reservoirs”. Society of Petroleum Engineers. SPE-193905-MS. 16 pp. DOI: 10.2118/193905-MS
Meziou A., Khan Z., Wassar T., Franchek M. A., Tafreshi R., Grigoriadis K. 2019. “Dynamic modeling of two-phase gas/liquid flow in pipelines”. SPE Journal, vol. 24, no. 5, pp. 1-25. DOI: 10.2118/194213-PA
Sobecki N., Wang S., Ding D.-Y., Draghi C. N., Wu Y.-S. 2019. “Tight oil and shale gas PVT modelling for flow simulation with matrix-fracture interaction”. Society of Petroleum Engineers. SPE-193867-MS. 39 pp. DOI: 10.2118/193867-MS
Ssembatya H., Ershaghi I. 2019. “A prediction method for estimating time to convert from cyclic to drive in steam injection processes”. Society of Petroleum Engineers. SPE-195301-MS. 16 pp. DOI: 10.2118/195301-MS.
Wu Y.-S., Yu X., Wang S., Winterfeld P. H. 2019. “Modeling thermal-hydraulic-mechanical processes in enhanced or engineered geothermal systems”. ARMA-CUPB Geothermal International Conference (5-8 August, Beijing, China). 18 pp.
Xu J., Deng J. G., Lin H., Chen Y., Jia L. X., Liu W. 2019. “Numerical modeling of wellbore stability and sand production of heavy oil reservoir with cyclic steam stimulation”. 53^{rd} US Rock Mechanics/Geomechanics Symposium (23-26 June 2019, New York, USA). 10 pp.
Zhou Y., Li G., Zapata V. 2019. “A natural variable well model for advanced thermal simulation”. Society of Petroleum Engineers. SPE-193835-MS. 21 pp. DOI: 10.2118/193835-MS.