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).
© 2007. Society of Petroleum Engineers
View full textPDF
(
2,066 KB
)
History
- Original manuscript received:
22 June 2004
- Meeting paper published:
16 March 2004
- Revised manuscript received:
5 December 2005
- Manuscript approved:
11 October 2006
- Version of record:
20 April 2007
View Cart
