Abstract
VAPEX (vapour extraction) is a promising technique for the recovery of heavy
oil and bitumen reservoirs, especially for cases where steam-assisted gravity
drainage and other thermal recovery methods are not economical. In the VAPEX
process, a solvent is injected into the reservoir to reduce the oil viscosity
and mobilize it towards the production well. CO2-based VAPEX is an
attractive option from both economic and environmental perspectives. In
CO2-based VAPEX, unlike other hydrocarbon solvents, dissolution of
CO2 into the oil can result in a density increase of the diluted
oil. As a consequence, the diluted oil has a higher density than the immobile
oil beneath and a gravitationally unstable diffusive boundary layer is induced,
which may lead to natural convection. In this study, a mathematical model for
the diffusive boundary layer in the CO2-oil contact region in the
VAPEX process is developed and the possibility of convective mixing occurrence
is examined using linear stability analysis, based on the amplification of the
initial velocity perturbations. It is found that in field-scale cases in the
VAPEX process, the Rayleigh number is much smaller than the critical Rayleigh
number, (Rac), and natural convection cannot happen in this
process.
Introduction
The world's total reserve of heavy oil and bitumen is about six trillion
barrels, which is about six times the amount of conventional
resources(1). A major part of these resources are in Canada,
Venezuela and the United States. Most of these reserves are at such depths that
open-pit mining cannot be used economically, and in situ methods have to be
used to reduce the viscosity of the oil-in-place and mobilize it. Either
thermal methods or non-thermal methods can be used to recover these reserves.
The viscosity of oil is a strong function of temperature and decreases sharply
with increasing temperature. Currently steam-assisted gravity drainage (SAGD),
a thermal method, is a popular scheme for the recovery of heavy oil and bitumen
and has been successfully applied in several fields. Despite the success of
this process for some reservoirs, there are many reservoirs that SAGD cannot be
applied due to excess heat loss, which makes it uneconomical to operate. In
thin reservoirs, the need for steam increases and the steam-to-oil ratio (SOR)
is prohibitively high. Many oil and bitumen reservoirs have a bottom aquifer,
and heat loss to the water can make the process unfeasible(2). There
are also reservoir conditions where SAGD may not be applied, such as when water
saturation is high or porosity is low. In cases where SAGD cannot be applied,
VAPEX is an option for the recovery of these resources.
The initial development of the VAPEX process was first introduced by Butler and
Mokrys(3) as a solvent analogue to steam-assisted gravity drainage.
The steam chamber in SAGD is replaced by a solvent chamber in VAPEX. In the
VAPEX process, a solvent is injected near its dew point (where both solubility
and diffusivity of the vapour solvent into oil are at their maximums) and forms
a solvent chamber within the reservoir(4).
© 2009. Petroleum Society of Canada (now Society of Petroleum Engineers)
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History
- Original manuscript received:
28 March 2008
- Meeting paper published:
17 June 2008
- Revised manuscript received:
20 April 2009
- Manuscript approved:
6 July 2009
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