U.S. patent number 3,557,871 [Application Number 04/763,608] was granted by the patent office on 1971-01-26 for insulated casing and tubing string in an oil well for a hot fluid drive.
This patent grant is currently assigned to Phillips Petroleum Company. Invention is credited to Harry W. Parker.
United States Patent |
3,557,871 |
Parker |
January 26, 1971 |
INSULATED CASING AND TUBING STRING IN AN OIL WELL FOR A HOT FLUID
DRIVE
Abstract
Tubing and casing strings in a well penetrating an oil stratum
to be produced by hot fluid drive, such as with steam, are coated
on the walls thereof forming the annulus by packing off the annulus
adjacent or near the stratum, filling the annulus with an aqueous
solution of a water-soluble inorganic salt, such as borax, sodium
carbonate, sodium sulfate, and mixtures thereof, preferably
containing a binder, and injecting a hot fluid through the tubing
string into the stratum to evaporate water from the solution in the
annulus while venting steam therefrom at the wellhead and deposit a
substantial coat of the salt in solid form on the walls of the
annulus.
Inventors: |
Parker; Harry W. (Bartlesville,
OK) |
Assignee: |
Phillips Petroleum Company
(N/A)
|
Family
ID: |
27094701 |
Appl.
No.: |
04/763,608 |
Filed: |
September 30, 1968 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
|
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645442 |
Jun 12, 1967 |
3451479 |
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Current U.S.
Class: |
166/57;
166/242.4; 138/145 |
Current CPC
Class: |
E21B
36/003 (20130101); E21B 36/00 (20130101) |
Current International
Class: |
E21B
36/00 (20060101); E21b 017/00 (); E21b 043/24 ();
E16b 009/14 () |
Field of
Search: |
;166/1,39,40,57,242,272,302,303 ;252/62 ;138/145 ;106/306 |
References Cited
[Referenced By]
U.S. Patent Documents
Other References
willhite, G. Paul, et al. Design Criteria For Completion Of Steam
Injection Wells. In J. Petroleum Technology, Jan., 1967. pp. 18--21
relied on. (Copy in 166--40) .
Owens, W. D., et al. Steam Stimulation For Secondary Recovery. In
Producers Monthly, 29(4), Apr. 1965. pp. 8, 10--13 (Copy in
166--303) .
Uren, Lester C. Petroleum Production Engineering: Oil Field
Development, 4th Ed., 1956, p. 443 Oil Field Exploitation, 3d. Ed.,
1953, p. 277 N. Y., McGraw-Hill (Copies in Group 350).
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Primary Examiner: Calvert; Ian A.
Parent Case Text
This application is a division of my copending application Ser. No.
645,442, filed June 12, 1967, now U.S. Pat. No. 3,451,479.
Claims
I claim:
1. A string of metal tubing in a well extending from the wellhead
to an oil stratum, said string comprising a plurality of tubing
lengths connected by collars, and an insulating layer of solid,
water-soluble, inorganic salt covering the outside wall of said
tubing string, including said collars, said insulating layer having
an average thickness of at least one-sixteenth inch.
2. The string of tubing of claim 1 wherein said salt is selected
from the group consisting of borax, sodium carbonate, sodium
sulfate, and mixtures thereof.
3. The string of tubing of claim 1 including in said insulating
layer a binder in minor but effective concentration.
4. The string of tubing of claim 1 in combination in said well with
a surrounding casing string extending from the wellhead into said
stratum, the inside wall of said casing string being covered with
an insulating layer corresponding to that on said tubing
string.
5. The strings of claim 4 wherein said salt is selected from the
group consisting of borax, sodium carbonate, sodium sulfate, and
mixtures thereof.
6. The strings of claim 4 including in said layer on both said
tubing and said casing strings a binder in minor but effective
concentration.
7. The strings of claim 4 including a packer sealing off the
annulus between said tubing and said casing adjacent the upper
level of said stratum, the upper surface of said packer being
coated with a corresponding insulating layer.
8. The strings of claim 4 including a binder in said insulating
layer on both said tubing and casing strings comprising sodium
silicate.
9. The string of tubing of claim 1 wherein said salt is borax.
Description
This invention relates to a method for insulating the walls of a
casing and tubing string forming the annulus of a well penetrating
an oil stratum to be used in a hot fluid drive process and to the
resulting insulated tubing and casing strings.
The production of oil from underground oil-bearing strata by hot
fluid drive such as steam, hot water, and in situ combustion is
conventional in the petroleum industry. In hot steam drive at
temperatures above 400.degree. F. and as high as 750.degree. F.,
the casing is subjected to these extreme temperatures, resulting in
casing buckling and severe damage to the cement around the casing.
Similar deterioration and damage to the casing often results from
reverse burning in situ combustion wherein the hot gases from the
combustion zone pass through hot sand or rock in passing to the
production well and are at temperatures up to 1,000.degree. F. and
higher. In addition to the damage to the downhole casing, there is
also a substantial and expensive heat loss to the strata
surrounding the casing generally termed the "overburden." Slip-on
and wrap-on insulation of various types have been proposed and it
is estimated that such insulation will reduce thermal losses by
more than 80 percent and provide adequate protection for the
downhole casing.
This invention is concerned with a method of insulating the walls
of the casing and tubing strings forming the annulus of a well
which is simple, practical, and economically feasible and with the
resulting insulated tubing and casing strings.
Accordingly, it is an object of the invention to provide a simple
and effective method for insulating the inner wall of a casing
string and the outer wall of a tubing string forming the annulus of
a well, while the strings are in place in the well. Another object
is to provide a tubing string in a well coated on its outer wall
with a layer of insulating material comprising solid inorganic
salt. A further object is to provide a casing string in a well
having a corresponding insulating layer of salt on its inner wall
in combination with the insulated tubing string. Other objects of
the invention will become apparent to one skilled in the art upon
consideration of the accompanying disclosure.
A broad aspect of the invention comprises setting a packer downhole
on a tubing string in a well leading to a stratum containing oil to
seal off the annulus between the tubing string and the surrounding
casing, substantially filling the annulus above the packer with a
concentrated aqueous solution of a water-soluble inorganic salt,
injecting a hot fluid through the tubing string into the stratum so
as to heat and boil said solution while venting steam from the
annulus at the wellhead, and continuing the injection of hot fluid
through the tubing string so as to deposit said salt in solid form
on the outside wall of the tubing string and the inside wall of the
casing string substantially to the packer. The salt solution can be
saturated and contain undissolved salt. The salt solution may also
contain a suitable binder for binding the particles of salt
together and for binding the salt to the walls of the tubing and
casing strings. One or more salts of the group borax, sodium
carbonate, and sodium sulfate are generally utilized. Concentrated
solutions of these salts are effective in forming porous insulating
coatings on the strings. Sodium silicate and metal stearate soaps
provide suitable binders for the salt particles and for binding the
salt particles to the metal in the well. It is also feasible to
incorporate in the salt solution solid polymers in particulate
form, such as in short fiber form, as well as fibers of other
materials which deposit on the walls of the casing and tubing
strings in admixture with the solid salt with or without a binder.
The concentration of binder or filler is generated in the range of
about 5 to 20 weight percent of the salt in the solution.
A more complete understanding of the invention may be had by
reference to the accompanying schematic drawing of which FIG. 1 is
an elevation in partial section through an oil-bearing stratum
penetrated by a well and FIG. 2 is an enlarged partial section of
the insulated tubing and casing of FIG. 1.
Referring to the drawing, and particularly to FIG. 1, a stratum 10
containing oil is penetrated by a well 12 which is provided with a
casing string 14 and a tubing string 16. Casing 14 is cemented at
18 and is perforated at 20. Valved conduit 22 connects with the
annulus 24 between the casing and tubing strings at the wellhead. A
packer 26 seals off annulus 24 just above stratum 10. The inner
wall of the casing string is provided with a layer 28 of insulating
material formed of solid inorganic salt including a binder and/or a
filler. A similar insulating layer 30 is provided on the outer wall
of tubing string 16.
In applying the insulation to the tubing and casing strings, the
selected solution or slurry of salt with or without a binder and/or
filler is injected through conduit 22 into annulus 24 so as to
substantially fill the annulus from packer 26 to the wellhead.
Steam or other hot fluid is injected through tubing string 16 and
through perforations 20 into stratum 10 at such a rate as to raise
the temperature of the aqueous solution in the annulus to its
boiling temperature and evaporate water therefrom, the same being
vented through conduit 22. As the level of the solution in annulus
24 is progressively lowered due to evaporation, solid salt is
deposited on the outer wall of tubing string 16 and the inner wall
of casing 14 to form substantial layers of insulating material on
these strings. Even a one-sixteenth inch or a one-eight inch layer
of porous salt on the walls of the strings substantially reduces
heat losses from the injected steam during steam flooding of
stratum 10 or, in the event that well 12 is a production well of a
reverse in situ combustion operation, during venting of hot
produced gases and vapors through tubing string 16. However, it is
feasible to deposit substantially thicker layers of insulating
material on the walls of the annulus by the method of the
invention. It is also feasible to substantially fill the annulus
with water-soluble insulating salt. The water-soluble nature of the
insulating material facilitates the removal of the insulating
material by passing water through the annulus at any time that it
is desired to remove the insulation. In order to do this, packer 26
may be released or unsealed so that flushing water may be injected
down the tubing string and up the annulus to remove the insulating
salt layer. It is also feasible to lower a waterline or hose down
the annulus substantially to packer 26 and flush water up the
annulus and out through conduit 22 to dissolve and remove the salt
layer.
To illustrate the invention, 400 g. of sodium carbonate were mixed
with 250 cc. of water, using "Osterizer" on high speed for about 10
minutes. This produced a viscous slurry of sodium carbonate in
water. A steel pipe nipple 4 inches long and 1/4-inch ID was
cleaned by grinding off dirt and rust and one end thereof was
plugged and the pipe was dipped into the sodium carbonate slurry.
The plug was removed from the end of the pipe and the pipe was
clamped at a 45.degree. angle on a ringstand. The pipe was then
heated by directing a flame of an oxygen-natural gas torch through
the pipe for about 5 minutes. A substantial layer of sodium
carbonate insulation was produced on the outer surface of the pipe.
It is quite obvious that a substantially heavier layer of
insulating salt can be coated onto the pipe strings in the well by
filling the annulus with a concentrated aqueous solution of the
salt and evaporating the water therefrom. Layers up to 3/8-inch in
thickness and even thicker layers can be produced by the method of
the invention.
It is desirable to clean the walls of the annulus to be coated with
insulating material by flushing with water or cleaning solution
prior to the filling of the annulus with the concentrated salt
solution. This enhances the adherence of the salt to the wall of
the iron pipe.
When producing the stratum with hot steam, the injected steam
utilized in evaporating the water from the annulus can be a part of
the steam injection operation, the steam and condensate from the
injection operation passing from the well below packer 26 directly
into the stratum through perforations 20.
It is also feasible to start a reverse burning in situ combustion
process around well 12 with the annulus filled with salt solution
and effect the evaporation and deposition of salt with resulting
hot produced gases passing up the tubing string as the combustion
is continued.
Certain modifications of the invention will become apparent to
those skilled in the art and the illustrative details disclosed are
not to be construed as imposing unnecessary limitations on the
invention.
* * * * *