U.S. patent number 3,692,111 [Application Number 05/054,721] was granted by the patent office on 1972-09-19 for stair-step thermal recovery of oil.
Invention is credited to John T. Breithaupt, Raymond T. Garcia.
United States Patent |
3,692,111 |
Breithaupt , et al. |
September 19, 1972 |
STAIR-STEP THERMAL RECOVERY OF OIL
Abstract
A method for producing a viscous oil from a reservoir having a
number of permeable oil saturated layers separated by impermeable
barriers through which heat may be conducted. According to the
method, a water zone and a zone of saturation transition between a
water zone and an overlying oil zone of a first formation are used
as conduits for carrying heat into the formation. This heat is
employed to reduce the viscosity of oil in the formation thus
improving the injectivity of the formation and facilitating the
initiation of a steam flood therein. Hear from this stream flood is
conducted, through an adjoining impermeable barrier and into an
adjacent formation which is then steam flooded.
Inventors: |
Breithaupt; John T. (Houston,
TX), Garcia; Raymond T. (Houston, TX) |
Family
ID: |
21993072 |
Appl.
No.: |
05/054,721 |
Filed: |
July 14, 1970 |
Current U.S.
Class: |
166/252.1;
166/269; 166/272.3 |
Current CPC
Class: |
E21B
43/24 (20130101) |
Current International
Class: |
E21B
43/24 (20060101); E21B 43/16 (20060101); E21b
043/24 () |
Field of
Search: |
;166/269,272,274,252 |
References Cited
[Referenced By]
U.S. Patent Documents
Other References
frick; Petroleum Production Handbook, Vol. II, Reservoir
Engineering, McGraw-Hill Book Co., 1962, pp. 21-1; 22-1. .
Uren; Petroleum Production Engineering, Oil Field Exploitation, 3rd
Ed. McGraw-Hill Book Co., N.Y., 1953, pp. 12, 30, 31,
38-41..
|
Primary Examiner: Novosad; Stephen J.
Claims
We claim as our invention:
1. In a process for the recovery of oil from a subsurface
oil-bearing reservoir which includes at least two productive
formations, a first productive formation having three zones -- an
upper zone predominately saturated with a viscous relatively
immobile oil, a lower zone predominately saturated with water, and
a saturation transition zone where in oil saturation decreases and
water saturation increases with increasing depth -- and an adjacent
second productive formation separated therefrom by a substantially
impermeable barrier through which heat may be conducted, the method
comprising the steps of:
extending at least a first well and a second well to each at least
partially traverse said first and second productive formations;
determining the location in said first formation of said first
zone, second zone and transition zone;
opening said first well and said second well into fluid
communication with the upper zone, the lower zone, and the
transition zone of said first productive formation;
preheating at least some of the oil in the upper zone and heating
at least some of the oil in said transition zone of said first
productive formation by injecting a hot fluid into said first
productive interval through said first well whereby said hot fluid
moves into said transition zone and said predominately
water-saturated lower zone carrying heat into said first productive
formation which conductively preheats said upper zone;
entraining in hot fluid moving through said transition zone of said
first productive formation at least a portion of said preheated oil
in the transition zone;
producing said entrained oil through said second well along with
said fluid;
after said preheat step, driving oil to said second well and
conductively preheating said adjacent second productive formation
by continuously injecting steam simultaneously into the upper,
lower, and transition zones of said first productive formation
through a single flow path in said first well; and
producing fluid from said upper, lower, and transition zones of
said first formation through a single flow path in said second
well;
whereby said steam injected into said transition zone and said
lower zone moves toward said second well and rises carrying heat
into said first productive formation further heating the oil in
said upper zone and entraining at least some heated oil draining
from said upper zone into said transition zone and said lower zone,
whereby said steam injected into said upper zone further heats the
preheated oil in said upper zone and drives said oil in said upper
zone to the second well, and whereby the adjacent second productive
formation is preheated by heat conducted from said first productive
formation through said impermeable barrier;
opening said first well and said second well into fluid
communication with said adjacent second productive formation;
providing a separate confined path for fluid flow into said
adjacent second productive formation through said first well;
driving oil from said adjacent second productive formation by
injecting a heated fluid into said second productive formation
through said separate confined path for fluid flow in said first
well while continuing to inject steam into said first productive
formation;
producing oil from said second productive formation through said
second well;
determining when steam breakthrough into said second well from said
first productive formation occurs; and
when said steam breakthrough occurs, plugging back at least some of
that portion of said second well open into fluid communication with
said first productive formation to shut off at least some of said
steam breakthrough.
2. The method of claim 1 wherein said fluid is hot water.
Description
BACKGROUND OF THE INVENTION
1. Field of the Invention
This invention relates to a method for producing hydrocarbons from
a subsurface reservoir. More particularly, this invention relates
to a method for treating an oil-bearing reservoir with steam and/or
hot water to increase the recovery of hydrocarbons therefrom.
2. Description of the Prior Art
In many areas of the world, reservoirs of low A.P.I. gravity crude
oil exist which are difficult to produce because the high viscosity
of such low gravity oils makes them substantially immobile within
the reservoir. It is well known that the viscosity of most crude
petroleum is temperature dependent and that the viscosity of the
oil in a given reservoir may be decreased by a factor often on the
order of 50 to 1,000 times by an increase in the temperature of
that oil above the reservoir temperature on the order of
100.degree. F. To this end, a number of methods for heating oil in
a petroleum reservoir have been successfully employed. Among these
is the injection of steam and/or hot water into the reservoir to
heat the oil, thereby lowering its viscosity, and to drive the
heated oil to a producing well.
Some oil reservoirs which contain viscous crudes are composed of a
number of layers or formations of sandstone or other permeable
oil-bearing rocks separated by relatively thin impermeable barriers
through which heat may be conducted such as layers of shale. It has
been suggested that heat may be provided by conduction to one of
two adjacent oil-bearing layers of such a reservoir by carrying out
a conventional steam flood in the other of the adjacent layers.
However, in some layered reservoirs, the oil in each of the
oil-bearing layers may be so viscous and immobile at the naturally
occurring reservoir temperature that it is difficult or impossible
to initiate a steam and/or hot water flood in any of the layers by
injecting a hot aqueous fluid solely into a predominately
oil-saturated zone.
It has also been suggested that an oil-bearing layer may be warmed
by heat conducted from a steam flood of an adjacent water sand.
However, in some cases it may be economically impractical to heat
an adjacent oil-bearing layer by steam flooding a water-saturated
layer because it may take a substantial preheat period before
significant amounts of oil are produced from the adjacent oil
zone.
SUMMARY OF THE INVENTION
It is not uncommon for at least one oil-bearing sand in a reservoir
having a number of oil-bearing layers separated by impermeable
barriers to include at least one oil-bearing layer which has a
predominately water-saturated interval or zone near the bottom of
that layer.
The present invention provides a method for producing oil from a
viscous oil containing reservoir having a number of oil-bearing
layers or formations separated by impermeable barriers through
which heat may be conducted and having at least one layer or
formation (the "first treated formation") which includes an upper
zone predominately saturated with viscous oil, a lower zone
predominately saturated with water, and a zone of saturation
transition between the upper and lower zones in which oil
saturation decreases and water saturation increases with increasing
depth. According to the present invention, the transition zone and
the water zone of the oil-bearing formation are used as conduits
for carrying a heated fluid into the formation. Heat from this
fluid is employed to reduce the viscosity of at least some oil in
the upper and transition zones. The heated oil is then driven to a
producing well, or is then entrained in the fluid passing through
the water zone and the transition zone and carried to a producing
well. Heat from this thermal treatment of the first treated
formation is conducted through the adjoining impermeable barrier to
an adjacent oil-bearing formation thereby reducing the viscosity
and increasing the mobility of oil in that layer. This conductively
heated formation may then be treated according to a hot water
and/or steam flood recovery process.
BRIEF DESCRIPTION OF THE DRAWING
FIG. 1 is a diagrammatic view partially in cross-section of a
layered, subterranean, viscous oil-containing reservoir traversed
by two wells suitably equipped for the practice of this
invention.
FIG. 2 is a vertical sectional view of the reservoir at a time
after it has been treated according to the teachings of this
invention.
DESCRIPTION OF A PREFERRED EMBODIMENT
Referring to FIg. 1, we see a subsurface oil reservoir 10, which
encompasses a number of porous, permeable viscous oil-containing
formations or intervals 11-14 separated by a number of impermeable
layers or barriers 15-17 preferably less than 50 feet thick. The
permeable formations 11-14 may, for example, be composed of
sandstone while the impermeable layers 15-17 may be composed of
shale or other impervious rock capable of conducting heat. The
lowermost sand formation 14 has an upper zone 18 predominately
saturated with a viscous crude oil and a lower zone 19
predominately saturated with water. The zones 18 and 19 meet at an
oil-water contact 20. Adjacent the oil-water contact 20 may be a
zone 20a of saturation transition in which the oil saturation
decreases and the water saturation increases with increasing depth.
Within at least some of this saturation transition zone 20a, the
relative permeability to both oil and water is great enough so that
oil and water may be expected to flow simultaneously through the
zone 20a if the fluids have viscosities of similar magnitude.
However, because the viscosity of the viscous oil in the formation
14 is much greater at the naturally occuring reservoir temperature
than the viscosity of the water in the formation 14 at that
temperature, the oil in the saturation transition zone 20a is
substantially immobile when at that temperature whereas at least a
portion of the water in this zone 20a is mobile.
To recover oil from the reservoir 10 according to the method of
this invention, at least a first well 21 and a second well 22 are
extended into the oil reservoir 10. Each of the wells 21 and 22 at
least partially transverses the predominately water-saturated lower
zone 19 of permeable formation 14. The wells 21 and 22 may be
completed in a conventional manner, as for example, by extending
tubular casings 23 and 24 into well bores 25 and 26 of the wells 21
and 22 and fixing the casings 23 and 24 in place with cement 27 and
28. The wells 21 and 22 may then be opened into fluid communication
with preferably at least a portion of each of the zones 18, 19 and
20a of the formation 14 by any method in the art such as
perforating the casings 23 and 24 and the surrounding cement 27 and
28 with perforations such as those indicated by numerals 29 and 30.
The intervals of the well bores 25 and 26 which are provided with
perforations 29 and 30 preferably extend at least 2 feet above and
below the oil-water contact 20, the location of which may be
determined by methods well known in the art, such as electric
logging, as may the respective locations of the zones 18, 19 and
20a.
A flow path for injecting fluid into formation 14 through the first
well 21 may be provided as by extending a string of tubing 31 into
the well 21 to location in the borehole 25 adjacent the formation
14. A packer 32 may be set in the annulus between the tubing 31 and
the casing 23 above the perforations 29 which open the borehole 25
into fluid communication with the formation 14 to pack off the
perforate portion of the borehole 25. The second well 22 may be
equipped in any conventional manner, as with a string of tubing 39
and a pump means 40 driven by a rod means 41, to produce fluid
which flows into that well 22 from the formation 14 through the
perforations 30.
The formation 14 may first be preheated by injecting hot water or
low-grade steam (about 5 percent quality) down the first well 21,
through the perforations 29, and into the formation 14, and
producing fluid from the formation 14 through the second well 22.
Because the water in the predominately water-saturated lower zone
19 and the transition zone 20a has a greater mobility than the
viscous oil in the predominately oil-saturated zone 18, the water
in the zones 19 and 20a will move to the second well 22 relatively
rapidly compared to the rate of fluid movement in zone 18.
As the water moves toward the well it is at the same time replaced
by hot injected fluid which moves through the zones 19 and 20a
heating oil in the zone 20a and conductively preheating oil in the
oil-saturated zone 18. As the oil in the transition zone 20a
adjacent the oil-water contact 20 is heated, it becomes more
mobile. At least some of the heated mobile oil in the transition
zone 20a is entrained in the moving stream of hot injected fluid
and is moved along therewith to the producing well 22 where the oil
is produced along with the water in which it is entrained. Thus,
oil production from the saturation transition zone 20a may begin
during the preheat period before a substantial portion of the oil
in the upper zone 18 is significantly more mobile than it is at the
naturally occurring reservoir temperature.
Preferably, after hot water injection into the formation 14 is
commenced, the producing well 22 is at least from time to time
checked as by measuring the temperature of the produced fluids to
determine whether or not heat communication is established between
the injection well 21 and the producing well 22. The injectivity of
fluid into well 21 may also be measured for indication of
communication. Preferably after heat communication between the
injection well 21 and producing well 22 is established, the
injection of hot water or low grade steam is stopped and relatively
high grade steam (preferably of at least 75 percent quality) is
then injected into the formation 14 through the established paths
of communication in zones 19 and 20a and through the predominately
oil-saturated zone 18 making the oil in this zone 18 even more
mobile.
According to a second embodiment of this invention, such relatively
high grade steam may be injected down the first well 21 and into
the formation 14 as a preheating fluid without first injecting hot
water or low grade steam into the formation 10. This fluid
initially moves into the water-saturated lower zone 19 and the
transition zone 20a as described above to preheat oil in the upper
zone 18. Preheating with this higher quality steam has the
advantage of transfering more heat (the heat of vaporization of the
steam) to the formation 14 per unit mass of fluid injected than hot
water preheating. However, because steam is less dense than water,
the contribution to bottom hole pressure in the well 21 of the
column of fluid in the tubing 31 is less when steam is used as the
preheat fluid. Therefore, for a given injection pressure at the top
of the tubing string 31, the mass flow rate of injected preheat
fluid may be lower if the preheat fluid is steam instead of hot
water.
Whether the preheat fluid is hot water or steam, after the preheat
period, the lower zone 19 of the formation 14 may be at least
partially resaturated with heated, more mobile oil by continuing to
inject steam into the formation 14. This steam forms a front 33
(FIG. 2) which may rise as it advances through the formation 14
toward the producing well 22 forming a predominately steam
saturated zone 34 such as that illustrated. At the front 33, the
advancing steam heats oil and drives it toward the producing well
22. Simultaneously, at least some of heated oil from above the
steam zone 34 may drain down into the steam zone 34 where it may be
entrained in and carried with the steam advancing toward the
producing well 22. At least some heated oil may drain from the
steam zone 34 into the lower zone 19 resaturating this zone with
oil. As oil saturation in the zone 19 increases, oil may be
entrained in and carried with the injected fluid moving through
this zone to the well 22.
Because the steam, at least initially, moves into the formation 14
more rapidly through the predominately water-saturated lower zone
19 than through the viscous oil-saturated upper zone 18, it is to
be expected that the steam front 33 first breaks through into the
producing well 22 from the lower zone 19. The occurrence of steam
breakthrough may be determined in a well-known manner such as by
observing the temperature of the produced fluids. When steam
breakthrough occurs into the producing well 22 the steam influx
into the well may be shut off at least in part by plugging back the
lower portions of the perforated interval of the borehole 26 of the
well 22 by any method known in the art such as, for example,
filling the borehole with a gravel 35 and covering the gravel with
a cement cap 36. From time to time, as the steam zone 34 rises
through the formation 14 and steam again breaks through into the
well 22 more of the perforated interval of the producing well 22
may be plugged back.
During the period of hot fluid injection into the first heated
productive formation 14, heat may be transferred by conduction
through the adjoining shale barrier 17 and into the adjacent
viscous oil-bearing formation 13. This heat reduces the viscosity
of the oil in formation 13 thus increasing the mobility and
injectivity of that interval. Preferably, after it has been
determined (as by temperature surveys, mathematical analysis or
other methods well known in the art) that the injectivity of the
formation 13 has been increased to a selected desirable value, the
wells 21 and 22 may be opened into fluid communication with the
formation 13 as by perforating the casings 23 and 24 with
perforations 37 and 38 (if this has not been previously done). A
separate confined path for fluid flow into the formation 13 may be
provided in the injection well 21 as by installing previously
referred to packer 32 in the annulus between the tubing 31 and the
casing 23 at a location in the well bore 25 which is between the
perforations 37 and 29 which open into formations 13 and 14,
respectively. This provides for the simultaneous injection of
separate columns of heated fluid down the tubing 31 and into
formation 14 and down the annulus between the tubing 31 and the
casing 23 and into the formation 13.
Preheated viscous oil may then be driven from formation 13 by
injecting hot water and/or steam into this formation through the
first well 21 while producing fluid from the formation through the
producing well 22. As hot fluid moves through formation 13, heat is
lost by conduction through shale barrier 16 to adjacent formation
12. This heat reduces the viscosity of the oil in formation 12 thus
increasing the injectivity of that formation and facilitating the
initiation of a thermal flood therein. Thus, the reservoir 10 may
be produced by a stair-step method which begins by injecting heat
into the predominately water-saturated zone 18 and the transition
zone 20a of formation 14 and leads to the thermal flooding of
adjacent formations 13, 12 and 11, respectively. It should be
understood that while in the embodiment of the invention heretofore
discussed only formations above the first treated formation 14 were
treated, it is within the concept of this invention to preheat and
subsequently thermally flood adjacent formations below the first
treated formation 14.
In summary, the present invention provides a process for the
recovery of oil from a subsurface oil-bearing reservoir which
includes at least a first and a second productive formation which
are adjacent but separated by a substantially impermeable barrier
through which heat may be conducted and wherein the first
productive formation has three zones -- an upper zone predominately
saturated with a viscous relatively immobile oil, a lower zone
predominately saturated with water and a saturation transition zone
wherein oil saturation decreases and water saturation increases
with increasing depth. An embodiment of the method comprises the
steps of: extending at least a first well and a second well to each
at least partially traverse the first and second productive
formations; opening the wells into fluid communication with the
upper zone, the lower zone, and the transition zone of the first
productive formation; preheating the oil in the upper zone of the
first productive formation by injecting hot water into the first
productive formation through the first well whereby the hot water
moves into the transition zone and into the predominately
water-saturated lower zone establishing a path of heat
communication and carrying heat into the first productive formation
which heats oil in the transition zone and which conductively heats
at least some of the oil in the upper zone; entraining in the hot
water moving through the transition zone of the first productive
formation at least a portion of the heated oil in the transition
zone, and producing said entrained oil through said second well
along with said water.
After the preheat step, one may drive oil to the second well and
conductively preheat the adjacent second productive formation by
continuously injecting steam simultaneously into the upper, lower,
and transition zones of the first productive formation through a
single flow path in the first well while producing fluid
substantially simultaneously from the upper, lower, and transition
zones of the first formation through a single flow path in the
second well.
Thereafter, one may open the first well and the second well into
fluid communication with the adjacent second productive formation,
provide a separate confined path for fluid flow into the adjacent
second productive formation through the first well, and drive oil
from the adjacent second productive formation by injecting a heated
fluid into the second productive formation through the separate
confined path for fluid flow in the first well while continuing to
inject steam into the first productive formation. This oil may be
produced from the second productive formation through the second
well. As fluid is produced, one may determine when steam
breakthrough into the second well from the first productive
formation occurs. After the steam breakthrough occurs, the steam
influx into the second well may be at least partially shut off by
plugging back at least some of that portion of the second well
which is open into fluid communication with the first productive
formation.
* * * * *