Physical Modeling of Heavy Oil Production Rate in a Vapour Extraction Process

2006 ◽  
Author(s):  
H. Zhang ◽  
P. Luo ◽  
Y. Gu
Keyword(s):  
Production Rate ◽  
Heavy Oil ◽  
Physical Modeling ◽  
Oil Production ◽  
Extraction Process ◽  
Vapour Extraction

Steam Alternating Solvent Process

2007 ◽  
Vol 10 (02) ◽  
pp. 185-190 ◽  
Author(s):  
Litong Zhao
Keyword(s):  
Energy Consumption ◽  
Water Treatment ◽  
Production Rate ◽  
Heavy Oil ◽  
Energy Input ◽  
Oil Production ◽  
Viscosity Reduction ◽  
Hydrocarbon Solvent ◽  
The Past

Summary A new heavy-oil-recovery process, the steam alternating solvent (SAS) process, is proposed and studied using numerical simulation. The process is intended to combine the advantages of the steam-assisted gravity drainage (SAGD) and vapor-extraction (vapex) processes to minimize the energy input per unit oil recovered. The SAS process involves injecting steam and solvent alternately, and the basic well configurations are the same as those in the SAGD process. Field-scale simulations were conducted to assess the SAS process performance under typical Cold Lake, Alberta, reservoir conditions. These results suggested that the oil-production rate of an SAS process could be higher than that of a SAGD process, while the energy input was 18% less than that of a SAGD process. By varying the length of the steam- and solvent-injection periods in a cycle, a different set of steam/oil and solvent/oil ratios may be obtained because the temperature profiles and solvent-concentration distributions in the vapor chamber can be affected by the injection pattern. The process therefore can be optimized for a specific reservoir under certain economic conditions. Introduction There are large heavy-oil and bitumen deposits in many areas of the world. The resources are especially enormous in northern Alberta, Canada. However, the high viscosity of these oils, usually more than 10 000 mPa×s, hinders the recovery of these resources. To recover such petroleum resources, two types of methods exist for the reduction of oil viscosity. The first is to increase oil temperature. This can be achieved by injecting a hot fluid, such as steam, into the formation, or by in-situ combustion through injecting oxygen-containing gases. The second method is to dilute the viscous petroleum by lower-viscosity hydrocarbon solvent. This method involves injecting a hydrocarbon solvent, such as propane or butane, or a mixture of hydrocarbons into the oil reservoir. As the solvent dissolves into viscous oil, the viscosity of the mixture becomes much lower than the original viscosity of the heavy oil. The diluted oil then can be recovered. The combinations of the above viscosity reduction methods and the horizontal-well technology have been the focus of research for the past 20 years. Two processes, SAGD and vapex, have been developed for the recovery of heavy-oil and bitumen resources (Butler et al. 1981; Butler and Mokrys 1991; Frauenfeld and Lillico 1999). The first has been tested successfully in the field and is currently the process of choice for commercial in-situ recovery (Edmunds et al. 1994; Mukherjee et al. 1995), while the second is starting initial field testing (Butler and Yee 2000). The advantage of the SAGD process is its high recovery and high oil-production rate. However, the high production rate is associated with excessive energy consumption, CO2 generation, and expensive post-production water treatment. The vapex process has the advantage of lower energy consumption (and, therefore, less CO2 generation) and much lower water-treatment costs. The major drawback of the vapex process, however, is its expected relatively lower oil-production rate and the uncertainty on reservoir retention of solvent. In the past several years, modifications have been proposed to improve SAGD's energy efficiency, either through injection of noncondensable gas with steam for reducing heat loss (Jiang et al. 1998) or through injection of solvents and steam together for increasing production rate (Nasr and Isaacs 2001). The combination of solvent with steam also has been studied in the steamflooding process (Farouq Ali and Abad 1976; Venturini and Mamora 2003).

An Experimental Study of the Post-CHOPS Cyclic Solvent Injection Process

2015 ◽  
Vol 137 (4) ◽  
Author(s):  
Zhongwei Du ◽  
Fanhua Zeng ◽  
Christine Chan
Keyword(s):  
Production Rate ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Early Time ◽  
Oil Production ◽  
The Other ◽  
Late Time ◽  
Solvent Injection ◽  
Injection Process ◽  
Different Diameters

Cold heavy oil production with sand (CHOPS) has been applied successfully in many oil fields in Canada. However, typically only 5–15% of the original oil in place (OOIP) is recovered during cold production. Therefore, effective follow-up techniques are of great importance. Cyclic solvent injection (CSI), as a post-CHOPS process, has greater potential than continuous solvent injection to enhance heavy oil recovery. Continuous solvent injection results in early breakthrough due to the existence of wormholes; while in CSI process, the existence of wormholes can increase the contact area of solvent and heavy oil and the wormholes also provide channels that allow diluted oil to flow back to the wellbore. In this study, the effects of wormhole and sandpack model properties on the performance of the CSI process are experimentally investigated using three different cylindrical sandpack models. The length and diameter of the base model are 30.48 cm and 3.81 cm, respectively. The other two models, one with a larger length (i.e., 60.96 cm) and the other with a larger diameter (i.e., 15.24 cm), are used for up-scaling study in the directions parallel and perpendicular to the wormhole, respectively. The porosity and permeability of these models are about 35% and 5.5 Darcy typically. A typical western Canadian oil sample with a viscosity of 4330 mPa·s at 15 °C is used. And pure propane is selected as the solvent. The experimental results suggest that the existence of wormhole can significantly increase the oil production rate. The larger the wormhole coverage is, the better the CSI performance obtained. In terms of the effect of wormhole's location, a reservoir or well with wormholes developed at bottom is more favorable for post-CHOPS CSI process due to the gravity effect. The production of the CSI process can be divided into two phases: early time chamber rising and late time chamber spreading phases. The oil recovery factor in the chamber rising phase is almost independent of the sandpack model diameter; and the oil relative production rates (the oil production rate divided by the OOIP) in two models with different diameters are close during the chamber spreading phase due to similar solvent dispersion rate. It is also found that if the wormhole length is the same, the sandpack model length hardly affects the oil production rate in the earlier stage. In terms of the effects of the wormhole orientation, the well with a horizontal wormhole is inclined to get a good CSI performance. Through analyzing the experimental data, a relationship of oil production rate to drainage height is also obtained and verified.

An up-scaling approach for vapour extraction process in heavy oil reservoirs

2015 ◽  
Vol 10 (1) ◽  
pp. 60 ◽  
Author(s):  
Tayebeh Jamshidi ◽  
Fanhua Zeng ◽  
Mehdi Mohammadpoor ◽  
Zeinab Movahedzadeh
Keyword(s):  
Heavy Oil ◽  
Extraction Process ◽  
Oil Reservoirs ◽  
Heavy Oil Reservoirs ◽  
Vapour Extraction ◽  
Up Scaling

Study of heavy oil production ceasing options using laboratory research and mathematical modeling

2019 ◽  
pp. 32-35
Author(s):  
A.T. Zaripov ◽  
◽  
D.K. Shaikhutdinov ◽  
Ya.V. Zakharov ◽  
A.A. Bisenova ◽  
...  
Keyword(s):  
Mathematical Modeling ◽  
Heavy Oil ◽  
Oil Production ◽  
Laboratory Research
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