U.S. patent number 3,809,159 [Application Number 05/293,968] was granted by the patent office on 1974-05-07 for process for simultaneously increasing recovery and upgrading oil in a reservoir.
This patent grant is currently assigned to Continental Oil Company. Invention is credited to Howard H. Ferrell, Gary C. Young.
United States Patent |
3,809,159 |
Young , et al. |
May 7, 1974 |
**Please see images for:
( Certificate of Correction ) ** |
PROCESS FOR SIMULTANEOUSLY INCREASING RECOVERY AND UPGRADING OIL IN
A RESERVOIR
Abstract
A process for simultaneously increasing recovery and upgrading
oil in a reservoir by injecting gas produced by the in situ
gasification of coal to increase recovery and upgrade said oil. The
gas is also useful in the production of steam and other gaseous
materials for injection.
Inventors: |
Young; Gary C. (Ponca City,
OK), Ferrell; Howard H. (Ponca City, OK) |
Assignee: |
Continental Oil Company (Ponca
City, OK)
|
Family
ID: |
23131325 |
Appl.
No.: |
05/293,968 |
Filed: |
October 2, 1972 |
Current U.S.
Class: |
166/258;
166/401 |
Current CPC
Class: |
E21B
43/243 (20130101) |
Current International
Class: |
E21B
43/243 (20060101); E21B 43/16 (20060101); E21b
043/14 (); E21b 043/24 () |
Field of
Search: |
;166/256,258,260,261,266,267,272 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Sutherland; Henry C.
Assistant Examiner: Ebel; Jack E.
Attorney, Agent or Firm: Scott; F. Lindsey
Claims
1. A process for increasing recovery of crube oil in a reservoir
formation comprising:
a. producing a combustible gaseous mixture by in situ gasification
of neighboring coal deposits;
b. burning said combustible gaseous mixture thereby producing an
injection gas;
c. injecting said injection gas into said reservoir formation;
and
3. The process of claim 2 wherein said crude oil is recovered by a
"drive"
4. The process of claim 1 wherein said crude oil is recovered by a
"huff and puff" type process.
Description
FIELD OF THE INVENTION
This invention relates to primary, secondary and tertiary recovery
of oil from oil-bearing reservoir formations. This invention
further relates to the use of gas injection techniques in the
recovery of oil from oil bearing reservoir formations. The
invention further relates to the use of gas produced by the
gasification of coal in the recovery of oil from oil-bearing
reservoir formations.
DESCRIPTION OF THE PRIOR ART
Numerous processes and methods are known for the gasification of
coal to produce light hydrocarbons, carbon monoxide, carbon
dioxide, hydrogen and the like. The use of gas injection as a
primary, secondary, or tertiary recovery method is also known and a
typical application of such techniques is shown in U.S. Pat. No.
2,734,578 issued Feb. 14, 1966 to Walter. A technique for gasifying
oil-bearing shale sands and injecting the gas so produced to
improve secondary oil recovery is shown in U.S. Pat. No. 3,040,809
issued June 26, 1962 to Pelzer. Other references considered in a
prior art search on the concept of the present invention are: U.S.
Pat. No. 1,978,655, issued Oct. 30, 1934 to Straight; U.S. Pat. No.
2,173,556, issued Sept. 19, 1939 to Hixon; U.S. Pat. No. 3,572,436,
issued Mar. 30, 1971 to Riehl; U.S. Pat. No. 3,548,938 issued Dec.
22, 1970 to Parker; U.S. Pat. No. 3,459,265 issued Aug. 5, 1969, to
Buxton et al.; U.S. Pat. No. 3,208,514 issued Oct. 31, 1962, to Dew
et al.; U.S. Pat. No. 3,399,721 issued Sept. 3, 1968, to Strange;
U.S. Pat. No. 3,480,082 issued Nov. 25, 1969 to Gilliland; U.S.
Pat. No. 3,360,044 issued Dec. 26, 1967 to Lange; U.S. Pat. No.
3,386,508 issued June 4, 1968 to Bielstein et al.; U.S. Pat. No.
2,813,583 issued Nov. 19, 1957 to Marx et al.; and U.S. Pat. No.
3,500,913 issued to Nordgren et al. The references are considered
further illustrative of the state of the art.
Prior attempts at the use of gas for secondary recovery have been
limited by the difficulty and expense in obtaining the gas at the
site of the secondary recovery operation. By their nature, such
recovery techniques require that the injected materials must be
available at relatively low expense and in relatively large
quantities to allow successful gas injection process operations. As
a result much time and effort has been directed to methods which do
not suffer the shortcomings of the methods disclosed above.
OBJECTS OF THE INVENTION
It is the object of the present invention to provide a method
whereby gas injection techniques may be utilized to increase oil
recovery and upgrade heavy crude oils without encountering the
difficulties inherent in producing the injection gas from surface
sources or transporting the gas substantial distances to the
injection site.
SUMMARY OF THE INVENTION
It has now been found that the object of the present invention is
realized in a process for increasing recovery and upgrading heavy
crude oil in a reservoir comprising producing a gaseous mixture by
in situ gasification of neighboring coal deposits; injecting the
gaseous mixture into oil reserviors to increase recovery of and
upgrade the oils in said reservoir and recovering said oil. The
gaseous mixture is also used to generate steam and other gaseous
injection materials.
DESCRIPTION OF THE DRAWING
FIG. 1 is a sketch of the Continental United States showing
selected oil fields and coal fields and the areas in which said
coal fields neighbor said oil fields.
FIG. 2 is a sketch of a typical embodiment of the present
invention.
FIG. 3 is a sketch of an embodiment of the present invention
wherein the coal deposit overlies the oil formation.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
In primary, secondary and tertiary recovery operations for the
recovery of crude oils, it has long been known that numerous
process utilizing gas injection are useful for such recoveries. The
primary difficulty in the use of such techniques is that it
oftentimes is difficult to provide large volumes of gaseous
material at the oil field to be treated. The primary difficulties
are economic as well as the simple handling difficulties in
transferring large volumes of gas to remote areas.
It has been observed that, as shown in FIG. 1, in many areas in the
Continental United States oil fields are located adjacent to coal
deposits. It has now been discovered that an effective and
efficient method for the primary, secondary and tertiary recovery
of oil from such formations consists of the in situ gasification of
the coal in said coal deposits to generate injection gas for the
oil recovery operation.
The in situ coal gasification may be achieved by numerous methods
well known in the art and no particular novelty is claimed in the
method by which the coal is gasified. In particular, coal may be
gasified by the injection of air or oxygen enriched air. The
injection gas may also contain water since the injection of water
with air has been shown to increase the BTU value of the produced
gas.
The oil recovery process may be selected from a variety of known
methods, such as "drive" processes, steam drive processes, "huff
and puff" processes, and the like. The "drive" methods typically
consist of the injection of gases, liquids and the like at one well
in a formation and the recovery of gas, condensed gas, liquids, oil
and the like at a second well in the same formation. Steam drive
processes are similar with the major differences being that steam
is used as the injection gas rather than other gases and latent
heat is transferred to the formation. "Huff and puff" operations
are well known in the art and typically comprise the injection of
steam, heated gases and the like following which the well is sealed
and time is allowed for the heat to permeate the formation,
following which the well is reopened and oil is produced from said
well. No particular novelty is claimed in the method for secondary,
tertiary or primary recovery of oil, but rather, the present
invention comprises a method whereby in situ gasification of coal
may be utilized to provide a readily available source of gaseous
injection materials for oil recovery techniques requiring an
injection gas material.
FIG. 1 is a sketch of the Continental United States showing
selected oil fields and coal fields and the areas in which said
coal fields neighbor said coal fields.
FIG. 2 discloses an embodiment of the present invention wherein a
gas drive process is used. Air is introduced through line 20, line
24, and well 3 into coal deposit 4. The gas produced by the
gasification of coal deposit 4 is produced through well 5 and line
26. The gas is then passed through line 26, to well 6 and through
well 6 into oil formation 7. The gas flow in oil formation 7 is
from well 6 to well 8 and oil and gas are produced through well 8
and line 28. The oil-gas mixture so recovered is passed to oil
recovery where the stream is separated into its respective
components, i.e., gas, water and oil.
As will be obvious to those skilled in the art, the injection gas
may be ignited at the base of well 6 to generate heat in oil
formation 7, thus aiding the oil recovery operation. The ignition
of the gas at the base of well 6 may be conducted in such a manner
that well 6 is completely coked in as is well known to those
skilled in the art. Numerous other modifications and variations of
the gas drive process are possible and may be readily apparent to
those skilled in the art upon review of the foregoing description.
It will, of course, be noted that water may be supplied through
lines 22 and 24 to coal deposit 4. As noted hereinbefore, the
produced gas has a higher BTU content in many instances when water
is injected with the air. It will, of course, be understood that
air is used to generally include any oxygen-containing gas such as
air, oxygen enriched air, and the like.
The produced gas may optionally be used to generate steam which may
be injected into oil formation 7. The steam is generated by
combustion of the gas produced by the gasification of the coal in
conventional steam boilers and the like. The generated steam is
then passed to oil formation 7 and the oil recovery is conducted in
a manner similar to that described above wherein the gas from the
coal gasification is used. As will be obvious to those skilled in
the art, many variations and modifications of the above procedures
are possible, for instance, water may be introduced into oil
formation 7 with the produced gas, with the steam and the like.
Steam may be added with the gas produced by the gasification of the
coal so that the injection gas at the bottom of well 6 may be gas
produced by gasification of coal, a combination of steam and the
gas produced by gasification of coal, or either of the streams may
be used in conjunction with water, and the like.
FIG. 3 discloses a preferred embodiment of the present invention
wherein the coal deposit overlies the oil formation. Air, oxygen
enriched air, or an oxygen-containing stream mixed with water, is
produced by introducing air and the like through line 22 and water
through line 24 into line 20 for injection into well 1 and well 3.
The injection gas is then passed into coal deposit 4 to produce
producer gas by the gasification of coal deposit 4. The flow of the
oxygen containing gaseous mixture is shown by arrows 30 and the
producer gas flow is shown by arrows 36. The producer gas flows
down the bore of well 2 and through oil formation 7 thus resulting
in the production of oil and producer gas through wells 1 and 3.
The producer gas and oil flow are shown by arrows 40.
The oil-gas mixture is then produced from wells 1 and 3 through
lines 26 and 28, and passed to oil and gas recovery. The combustion
of the coal deposit is in a reverse direction to the flow of the
injection gas. The combustion front 32 is shown by arrows 34 to
move in a direction opposite the flow of the oxygen-containing gas
which flows as shown by arrows 30.
In a variation of the above-described method the burn rate in the
coal deposit may be reduced to a minimum and the well closed in for
a period of time to allow the heat to permeate oil formation 7.
After the heat has permeated oil formation 7, well 2 is opened and
produced. This operation is similar to a "huff and puff" operation
in the sense that the heated gaseous mixture is injected into oil
formation 7, allowed to permeate the formation, and thereafter oil
is produced at intermittent intervals. It should also be noted that
when shale layer 17 is relatively thin, heat from the gasification
of the coal deposit 4 will be transmitted to oil formation 7, thus
further aiding recovery. Many variations and modifications of the
foreging procedures are possible and may be obvious to those
skilled in the art. Such modifications are considered within the
scope of the present invention and as heretofore noted the primary
novelty in the present invention lies in the gasification of
neighboring coal deposits to provide an economical and readily
available source of gaseious mixtures for primary, secondary, and
tertiary oil recovery operations.
The particular method for the gasification of coal is of no
particular importance to the process of the present invention so
long as a product gas comprising from about 15 to about 60 mole
percent carbon dioxide, from about 1 to about 10 mole percent
methane, from about 0.0 to about 0.4 mole percent oxygen, from
about 5 to about 60 mole percent hydrogen, from about 2 to about 51
mole percent carbon monoxide, from about 10 to about 80 mole
percent nitrogen, and from about 0.1 to about 3.0 moles of water
per mole of dry gas is produced. Such gases are useful in the
process of the present invention although a preferred gas
composition is from about 10 to about 36 mole percent carbon
dioxide, from about 2.0 to about 7.6 mole percent methane, from
about 0.3 to about 0.4 mole percent oxygen, from about 10 to about
50 mole percent hydrogen, from about 10 to about 15 mole percent
carbon monoxide, from about 10 to about 70 mole percent nitrogen,
and from about 0.13 to about 2.0 mole of water per mole of dry
gas.
It will be further recognized by those skilled in the art that
wells may be coked to the point of consolidating unconsolidated
formations by simply combusting the gas mixture at the bottom of
the well. Such is not considered the primary objective of the
present invention and normally gas would be injected and sealed in
to allow recovery of oil cyclically or gas would be injected
continuously and oil recovered continuously.
As shown in FIG. 1, in numerous areas in the Continental United
States, coal deposits neighbor oil fields. This situation makes it
possible to utilize the process of the present invention to gasify
coil in situ and utilize the gaseous mixture for gas injection
recovery techniques with neighboring oil fields. Neighboring as
used in the context of the present specification refers to coal
fields which overlie, underlie, or are near the oil fields to be
treated by the gas injection procedures. The use of such
neighboring coal and oil fields allows the use of gas produced in
situ to provide a large volume of low cost gaseous material at the
site of the injection treatment. Such a process has not been
available heretofore. The advantages of such a process over
processes utilizing surface generation of gas, the piping of gas
over long distances, and the like are obvious to those skilled in
the art. A further advantage is that in many situations a low-grade
coal deposit may be utilized to generate the gaseous mixture,
thereby utilizing a resource which is not economically useful
otherwise. Although it is shown that in the Continental United
States, many areas are adapted to the use of the process of the
instant invention, it should be understood that the scope of the
invention is not so limited and that any area anywhere in the world
having coal deposits neighboring oil fields is adapted to the
application of the process of the present invention.
The use of the gaseous mixtures described above achieves thermal
stimulation of the oil formation, since the injection gas may be
hot as produced or can be readily heated and the carbon dioxide and
methane are readily absorbed by the crude oils, thereby reducing
the viscosity. In addition, it should be pointed out that while
applicants wish to be bound by no particular theory, it is believed
that the hydrogen in the gaseous mixture reacts catalytically at
the sand-crude oil surfaces to reduce the viscosity of the crude
oil further, thereby improving the crude oil quality and increasing
recovery. There are thus three mechanisms acting to increase
recovery and improve crude oil quality, i.e., thermal stimulation,
absorption of light materials by the crude oil, and hydrogenation
of the crude oil. A further advantage is that the hydrogenation of
the crude oil tends to reduce the sulfur content of the oil,
thereby further improving the product quality. The use of such a
mixture and a showing of synergistic qualities in improving oil
recovery is shown in U.S. Pat. No. 2,734,578 issued Feb. 14, 1956
to Walter. The fact that such a mixture has been used heretofore,
merely emphasizes further the utility of applicants' process.
Applicants have found a novel, reliable, and economical method for
providing such desirable gaseous mixtures at low cost and in large
quantities to oil fields wherein gas injection techniques result in
increased oil recovery and upgrade the crude oil products. Many
modifications and variations are possible within the scope of the
present invention and in light of the foregoing description of
preferred embodiments and the following examples, it is expected
that those skilled in the art will envision many such desirable
modifications and process variations in the present process.
EXAMPLES
Example 1
In an embodiment of the present invention as shown in FIG. 2, one
million standard cubuc feet per day of air is injected into ignited
coal bed 4 through well 3. The coal bed is gasified by the air at
combustion temperatures greater than about 1,500.degree.F and the
product gas is removed from the coal bed through well 5 and
typically has the following composition:
Mole % Carbon Dioxide 11.0 Oxygen 0.3 Illuminants 0.3 Hydrogen 10.0
Carbon Monoxide 13.0 Methane 3.0 Nitrogen 62.4 Water/Mole Dry Gas
0.1
The heating value of such gas is typically from about 25 to about
175 BTU/standard cubic foot (SCF) with an average value being about
100 BTU/SCF. The specific gravity of such gases is approximately
0.9 based upon the specific gravity of air at standard
conditions.
During the coal gasification process the composition of the gas
will vary therefore, the heating value will vary somewhere between
about 25 and about 175 BTU/SCF but averaging about 100 BTU/SCF at
an air injection rate of 1,000,000 SCF per day about 1,000,000 SCF
of coal gas per day will be produced. The coal gas is inejcted into
oil formation 7 through well 6 and is mixed with air at the base of
well 6. The combustion at the base of well 6 generates
approximately 100,000,000 BTU/day of heat in the oil formation.
This technique is continued for some time and thereafter well 6 is
placed on production. Assuming that oil is produced at the ratio of
one barrel of oil per million BTU, then it is seen that the average
oil production in response to thermal stimulation would be about
100 barrels of oil per day upon producing well 6. It is noted that
100 percent efficiency in the transmission of heat and the like has
been assumed in the present example, whereas in practice lower
efficiencies will be realized, but since such variations are
dependent to a large degree upon the particular formation, the
particular method and the like, it is not necessary to further
define those parameters well known to those skilled in the art.
* * * * *