U.S. patent number 3,666,014 [Application Number 04/888,699] was granted by the patent office on 1972-05-30 for method for the recovery of shale oil.
This patent grant is currently assigned to Shell Oil Company. Invention is credited to Thomas N. Beard.
United States Patent |
3,666,014 |
Beard |
May 30, 1972 |
METHOD FOR THE RECOVERY OF SHALE OIL
Abstract
A method for recovering shale oil from a subterranean oil shale
formation by forming a rubbled zone therein and emplacing first and
second layers of fluid therein. The first fluid layer overlies the
second fluid layer which is of a higher specific gravity and is
largely immiscible therewith. A shale oil-extractive fluid of a
specific gravity intermediate that of the first two fluids is then
circulated through the zone between the first and second layers and
in contact therewith until shale oil is entrained in the shale-oil
extractive circulating fluid layer. Shale oil is then recovered
from the shale oil-extractive fluid.
Inventors: |
Beard; Thomas N. (Denver,
CO) |
Assignee: |
Shell Oil Company (New York,
NY)
|
Family
ID: |
25393705 |
Appl.
No.: |
04/888,699 |
Filed: |
December 29, 1969 |
Current U.S.
Class: |
166/271; 166/306;
166/247; 166/400; 166/272.6 |
Current CPC
Class: |
E21B
43/2405 (20130101); E21B 43/2635 (20130101) |
Current International
Class: |
E21B
43/24 (20060101); E21B 43/263 (20060101); E21B
43/25 (20060101); E21B 43/16 (20060101); E21b
043/20 (); E21b 043/24 (); E21b 043/26 () |
Field of
Search: |
;166/271,272,273,247,299,303,306,269 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Novosad; Stephen J.
Claims
I claim as my invention:
1. In a method for recovering shale oil from a subterranean oil
shale formation comprising the steps of:
rubblizing a portion of said subterranean oil shale formation
thereby forming a rubbled zone therein;
emplacing at least first and second layers of fluids in said zone,
said first fluid layer overlying said second fluid layer and said
second fluid having a specific gravity higher than said first fluid
and being largely immiscible therewith; and
circulating a layer of a shale oil-extractive fluid having a
specific gravity intermediate that of each of said first and second
fluids through said zone between said first and second layers and
in contact therewith until shale oil is entrained in said
circulating extractive fluid.
2. The method of claim 1 including the step of imparting heat to
said shale oil-extractive fluid prior to circulating it through
said zone.
3. The method of claim 1 wherein the step of circulating a shale
oil-extractive fluid through said zone includes the step of
circulating a solvent through said zone.
4. The method of claim 1 wherein the step of emplacing a first
fluid through said zone includes the step of circulating a gas
therethrough and the step of emplacing a second fluid through said
zone includes the step of circulating water therethrough.
5. The method of claim 4 including the step of moving said shale
oil-extractive fluid layer upwardly within said zone by increasing
the amount of water being circulated therethrough.
6. The method of claim 4 including the step of moving said shale
oil-extractive fluid layer upwardly within said zone by decreasing
the amount of gas being circulated therethrough.
7. The method of claim 1 including the step of recovering shale oil
from said circulating shale oil-extractive fluid.
8. The method of claim 1 wherein the steps of circulating said
shale oil-extractive fluid is carried out by the step of extending
at least a pair of well boreholes downwardly through said zone; and
circulating said shale oil-extractive fluid down one end of said
well boreholes and out the other of said well boreholes.
9. The method of claim 1 including the step of moving said shale
oil-extractive fluid layer vertically within said zone until shale
oil is recovered from substantially the entire zone.
Description
BACKGROUND OF THE INVENTION
1. Field of the Invention
This invention relates to the recovery of hydrocarbons from
relatively impermeable subterranean earth formations. More
particularly, it relates to oil shale recovery by in-situ retorting
and/or kerogen conversion within a rubbled portion of a
subterranean oil shale formation.
2. Description of the Prior Art
Large deposits of oil in the form of oil shale are found in various
sections of the United States, and, particularly, in Colorado and
surrounding states and in Canada. Various methods of recovery of
oil from these shale deposits have been proposed and the principal
difficulty with these methods is the high cost which renders the
recovered oil too expensive to compete with petroleum crudes
recovered by more conventional methods. The in-situ retorting or
conversion of oil shale to recover the oil contained therein is
made difficult because of the non-permeable nature of the oil shale
and the difficulty of applying heat thereto without extensive
mining or drilling operations. The mining and removal of the oil
shale for retorting of the shale in furnaces outside the formation
is commercially uneconomical in most cases.
SUMMARY OF THE INVENTION
It is an object of this invention to provide an economical in-situ
recovery method for recovering shale oil from a subterranean oil
shale formation.
It is a further object of this invention to provide a method of
using largely immiscible fluids of divergent specific gravities to
remove shale oil from rubbled oil shale formations.
It is a still further object of this invention to provide an
in-situ oil shale recovery method wherein the zone of activity
within a rubbled zone formed in an oil shale formation may be
controlled.
These and other objects are preferably accomplished by forming a
rubbled zone within a subterranean oil shale formation and
emplacing first and second layers of fluid therein. The first layer
overlies the second layer which is of a higher specific gravity and
immiscible therewith. A shale oil-extractive fluid of a specific
gravity intermediate that of the first two fluids is then
circulated through the zone between the first and second layers and
in contact therewith until shale oil is entrained in the
circulating fluid layer. Shale oil is then recovered from the
circulating fluid layer.
BRIEF DESCRIPTION OF THE DRAWING
FIG. 1 is a vertical cross-sectional view of an oil shale formation
prior to detonating a relatively high energy explosive device
within the formation;
FIG. 2 is a vertical cross-sectional view of the oil shale
formation of FIG. 1 after the explosive device has been
detonated;
FIG. 3 is a vertical cross-sectional view of the final rubbled zone
created by detonating the explosive device of FIG. 1;
FIG. 4 is a vertical sectional view of a method of treating the
rubbled zone of FIG. 3 in accordance with the teachings of my
invention; and
FIG. 5 is a vertical sectional view of an oil recovery process
applied to the treated rubbled zone of FIG. 4.
DESCRIPTION OF THE PREFERRED EMBODIMENT
FIG. 1 shows a subterranean oil shale formation 11 having a
relatively high energy explosive device 12 located within the
formation 11. The device 12 may be either nuclear or non-nuclear;
if a nuclear device is detonated within the oil shale formation 11,
a strong shock wave from the nuclear device begins to move radially
outwardly, vaporizing, melting, crushing, cracking and displacing
the oil shale formation 11. After the shock wave has passed, the
high pressure vaporized material expands, and a generally spherical
cavity 14 (FIG. 2) is formed which continues to grow until the
internal pressure is balanced by lithostatic pressure. The cavity
14 persists for a variable time depending on the composition of the
oil shale formation 11. The cavity roof 20 then collapses to form a
"chimney" or rubbled zone 15 (FIG. 3). Collapse progresses upwardly
until the volume initially in cavity 14 is distributed between the
fragments of the oil shale of formation 11. The size of the
substantially cylindrical rubble zone 15, formed by the collapse of
the cavity 14, may be estimated from the fact that the initial
cavity 14 (FIG. 2) expands until the pressure within the cavity is
about equal to the lithostatic pressure.
A zone of permeability 17 within and around the fragmented oil
shale formation is formed surrounding the chimney 15 as can be seen
in FIG. 3. If desired, the permeability of the zone 17 may be
increased by surrounding the primary explosive device of FIG. 4
which forms the central cavity with a plurality of devices of
lesser explosive energy, subsequently detonated in the manner
disclosed in U.S. Pat. No. 3,448,801.
A subsequently void space 18 is formed at the top of the chimney of
rubble 15. When used throughout this specification, the terms
"fragmented zone" and "fragmented zone of rubble" refer to the
rubbled zone 15 or any other rubbled or fracture-permeated zone
formed by any means well known in the art. For example, although
the formation of a specific type rubbled zone has been discussed
hereinabove, such a rubbled zone may be formed by any means well
known in the art.
Referring now to FIG. 4, a well bore 1 is extended through
over-burden 16 into communication with fragmented zone 15. Well
borehole 1 is preferably cased at casing 2 which may be cemented
therein, if desired (not shown). An annulus outlet 3 is disposed at
the top of casing 2. A tubing string 4 is disposed in well borehole
1 packed off at packing means 5. Casing 2 is perforated at
perforation 6. In this manner, fluid may be injected down tubing
string 4, past packing means 5 and out the bottom of the casing 2
into zone 15. In this fashion the fragmented zone 15 may be filled
with either fluid layers 7 or 8 displacing the fluid initially
present in the fragmented zone 15 out perforation 6 up the annulus
and out the annulus outlet 3. By means well known in the art,
varying proportions of fluid layers 7 and 8 may be introduced and
maintained in the fragmented zone 15. Because the fluid layers 7
and 8 are not totally miscible and have different specific
gravities, they segregate into layers with the lightest fluid at
the top. For example, the fluid of layer 7 may be a gas or mixture
of gases such as water vapor, hydrocarbon vapor, carbon dioxide,
nitrogen, etc., overlying a layer of water. Although the fluid
layers 7 and 8 are shown in FIG. 4 as occupying approximately equal
portions of zone 15, the relative proportions of such layers is a
matter of choice and the boundary between the layers 7 and 8 may be
located at any position within zone 15 by varying the relative
amounts of fluids in the system. The system described for
introducing the two fluid layers 7 and 8 into the fragmented zone
15 is only one of many possible choices involving one or more
wells.
Referring now to FIG. 5, a preferred arrangement for producing
shale oil from the fragmented zone 15 of FIG. 4 is illustrated. A
well borehole 19 is extended through overburden 16 into
communication with rubbled zone 15. The lower end of well borehole
19 is disposed substantially adjacent the juncture of layers 7 and
8. Well borehole 19 may be cased at least along the portion
traversing the overburden 16 and oil shale formation 11, as at well
casing 20, with casing 20 cemented therein, if desired (not shown),
as is well known in the art. Well borehole 19 is preferably
equipped with a tubing string 27, packed off from casing 20 as at
packer 24.
A like well borehole 30 is also extended into zone 15 adjacent the
juncture of layers 7 and 8. Well borehole 30 includes a casing 32
which may be cemented (not shown), if desired. A tubing string 33
is disposed in well borehole 30, packed off at packer 34. However,
tubing string 33 and packer 34 may be eliminated, if desired.
Although well borehole 30 is shown in FIG. 5, the well borehole of
FIG. 4 may of course be used.
In operation, a shale oil-extractive fluid, such as a solvent, of a
specific gravity intermediate that of the fluid within layers 7 and
8, is injected down well borehole 19, through zone 15 and in
contact with layers 7 and 8 thus forming a third fluid layer 9.
This injection is continued for a period of time sufficient to
entrain shale oil in the circulating third fluid layer 9.
Preferably, as illustrated, such fluid may be preheated as
indicated by heater 31 so as to impart thermal properties
thereto.
As the third fluid layer 9 circulates up tubing string 33 and out
of well borehole 30, shale oil and gas entrained in the fluid
recovered from the third fluid layer 9 pass through a heat
exchanger 28 and into a separator 29. At this point, the shale oil
and gas components are separated as is well known in the art. The
recovered combustion-supporting gas may be recirculated from
separator 29 through pump 26 and heater 31 as is also well known in
the art.
By increasing or decreasing the total amount of the fluids in
layers 7 and 8, such as gas and water, respectively, layer 9 may be
moved vertically upwardly or downwardly through zone 15 so as to
recover shale oil from various levels of zone 15. The layer 9 of
solvent will always be between layers 7 and 8 thus the volume and
direction of flow of the fluid in layer 9 may be controlled through
zone 15. Improved recovery thus results over conventional full
formation flush methods. The upper and lower layers, that is layers
7 and 8, may or may not be circulated as layer 9 is being
circulated. This may be accomplished by extending well boreholes 19
and 30 through zone 15 and perforating at the desired fluid levels
with subsequent fluid circulation therethrough (not shown), as is
well known in the art. If desired, extractive properties may also
be imparted to the fluids in layers 7 and 8.
The solvent or extractive fluid in layer 9 may be any liquid or gas
which, by means of thermal, chemical and/or solvent action,
interacts with the kerogen components of an oil shale to produce
and entrain shale oil, as long as its specific gravity is
intermediate that of the fluids in layers 7 and 8. Such a fluid may
comprise steam, hot hydrocarbons, hot gases, and/or mixtures of
such fluids with chemicals such as acids and/or organic solvents.
This fluid may be heated by surface or borehole-located heating
devices and/or by means of in-situ combustion within the shale
formation. This extractive fluid may advantageously comprise or
contain a solvent for the soluble mineral, such as a steam
condensate or a hot aqueous solution or organic and/or inorganic
acid, having a temperature, such as at least several hundred
degrees farenheit. Where the kerogen-pyrolyzing fluid contains or
forms aqueous components, its circulation through the treated oil
shale formation 11 may enlarge the zone 15, by solution-mining the
kerogen therein, while shale oil is being produced. Preheating the
fluid in layer 9 also provides a significant reduction in the total
amount of extractive fluid required.
* * * * *