U.S. patent number 3,814,187 [Application Number 05/360,222] was granted by the patent office on 1974-06-04 for subsurface formation plugging.
This patent grant is currently assigned to Amoco Production Company. Invention is credited to George B. Holman.
United States Patent |
3,814,187 |
Holman |
June 4, 1974 |
SUBSURFACE FORMATION PLUGGING
Abstract
This invention concerns a method of selectively plugging
fractures in an underground formation without permanently plugging
the "secondary porosity," e.g., vugs, etc., which may be in
communication with the wellbore. A slurry of finely divided
limestone is first pumped through the well to fill the secondary
porosity. Then a second slurry of finely divided solids, such as
flyash, which is not soluble in most acids, is injected into the
well to plug the interwell fracture system. Thereafter, to aid
injectivity, the well is given a low pressure acid treatment to
remove the limestone from the secondary porosity.
Inventors: |
Holman; George B. (Tulsa,
OK) |
Assignee: |
Amoco Production Company
(Tulsa, OK)
|
Family
ID: |
23417097 |
Appl.
No.: |
05/360,222 |
Filed: |
May 14, 1973 |
Current U.S.
Class: |
166/281;
166/292 |
Current CPC
Class: |
E21B
43/261 (20130101); E21B 33/138 (20130101) |
Current International
Class: |
E21B
33/138 (20060101); E21B 43/26 (20060101); E21B
43/25 (20060101); E21b 033/138 () |
Field of
Search: |
;166/281,292,271 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Brown; David H.
Attorney, Agent or Firm: Hawley; Paul F. Gassett; John
D.
Claims
I claim:
1. A method of plugging a fracture in an interwell area of an
underground formation having secondary porosity penetrated by a
wellbore without permanently plugging said secondary porosity which
comprises the steps of:
a. injecting a liquid slurry in which the finely divided solid
particles are limestone dust;
b. thereafter injecting a slurry in which the finely divided
particles are not soluble in acid, at a pressure in the range from
the fracture opening pressure to below the pressure required to
create a fracture therein;
c. thereafter acid flushing the wellbore to remove limestone
particles from the secondary porosity.
2. A method as defined in claim 1 in which the slurry of limestone
particles is injected at a pressure in the range of the fracture
opening pressure to below the pressure required to create a
fracture therein and in which the acid flush is applied at a
pressure less than the fracture opening pressure.
3. A method as defined in claim 1 in which the finely divided
particles of step b) are flyash.
4. A method as defined in claim 3 in which the flyash slurry
includes water as a carrier fluid, containing about 18 to 26 lbs of
flyash per gallon of water.
Description
BACKGROUND OF THE INVENTION
1. Field of Invention
This invention relates to improved processes for plugging fissures
or fractures in underground penetrated by a wellbore without
permanently plugging the secondary porosity. It particularly
concerns the use of such plugging processes for use of secondary
recovery operations in which fluid is injected into the formation
through one well to displace another fluid, usually oil, to a
second well.
2. Setting of the Invention
The secondary or tertiary recovery operation for which this
invention is most suitable is the liquid-displacement type, such as
waterflood. In waterflood operations, water is injected through an
input well into the formation to drive oil toward an output or
producing well. In many waterflood projects, the formation has many
fractures, either naturally occurring or man-made, existing
therein. Too frequently the injected water travels dominantly
through such existing fractures. When this occurs, the injected
water fails to reach the matrix or rock outside the fractures.
Consequently, hydrocarbons in such rock or matrix outside the
fissures or fractures are largely bypassed or "unswept" by the
injected water. Thus, poor sweep efficiency and ineffective
hydrocarbon recovery are experienced from the waterflood
operation.
The water bypass problem in those situations has been at least
reduced by plugging such fissures. Two patents which disclose such
processes are U.S. Pat. Nos. 3,486,559 and 3,713,489. Those two
patents are also the closest prior art of which I am aware. Both
patents relate to method of plugging fractures by injecting a
liquid containing finely divided low-density, nonsettling solids
into the formation. Those patents suggest several suitable finely
divided solids, such as nutshell flour, flyash, limestone dust,
blow sand. While those systems have been quite successfully
employed in the field, there are nevertheless some areas in which
those methods need improvement to improve the efficiency of the
overall operations. One such area is in those formations having
secondary porosity.
A BRIEF SUMMARY OF INVENTION
This is a method of selectively plugging fractures in an interwell
area of an underground formation penetrated by a wellbore without
permanently plugging the secondary porosity. A liquid slurry
comprised of water and limestone dust is injected into the
formation via the wellbore and at a pressure varying up to nearly
the fracturing pressure. Pressures of this range are required to
stress the dominant fracture and insure filling of "secondary
porosity." A volume of limestone slurry is pumped into the well to
fill the estimated volume of the secondary porosity and enter the
dominant fracture. Thereafter, a second slurry is injected through
the wellbore at a pressure above that required to open existing
fractures but below that required to create a new fracture therein.
The second slurry is preferably water and flyash. The second slurry
is then pumped into the well until the desired amount has been
injected to give adequate inter-well plugging of the opened
fracture. After this, steps are taken to remove the plugging
material of limestone from the secondary porosity. This is
accomplished by a low-pressure acid treatment such as an acid wash
or jet washing. This does not affect the flyash plug in the
interwell area, but re-establishes injectivity through the
secondary porosity.
Secondary porosity includes vugs and small fractures near the
wellbore, which extend at most only a few feet in any direction.
The common secondary porosity development is found in cores
containing crystalline secondary dolomite with inter-crystalline
pores connecting large vugs. These vugs are irregular but can
amount to open space of up to 2 or 3 inches across the opening.
Large fossil molds and solution channels are also included in the
term "secondary porosity." Since many injection wells are converted
oil producting wells, prior acid stimulation to increase
productivity has resulted in enlarging these channels near the
wellbore. The wellbores of injection wells are drilled or extend
through these channels or portions of the "vuggy porosity." The
walls of these vugs then, insofar as injection considerations are
concerned, have the same function as an enlarged wellbore. This
secondary porosity aids injection rates but does not cause
bypassing of large quantities of matrix or rocks, such as interwell
fractures.
BRIEF DESCRIPTION OF THE DRAWINGS
A better understanding of the invention and various modifications
and objects thereof can be made from the following description
taken in conjunction with the drawings in which:
FIG. 1 is a schematic vertical section of an underground formation
penetrated by a wellbore, illustrating both an extensive fracture
and secondary porosity.
FIG. 2 is the same view as FIG. 1 but after the limestone slurry
has been injected.
FIG. 3 is the sequence from FIG. 2 in which flyash has been
injected.
FIG. 4 is similar to the other figures, but shows the removal of
limestone slurry by acid washing or jetting while the flyash slurry
is not affected due to its low solubility in acid.
DETAILED DESCRIPTION OF INVENTION
Attention is first directed to FIG. 1 which illustrates an
injection well having a borehole 10 which extends through
subsurface producing formation 12. Casing 14 is shown set through
the top of formation 12; however, the casing can be set through the
formation and is in many cases. A tubing string 16 is suspended in
the casing and a packer 18 closes the annulus between the lower end
of tubing string 16 and the casing. The tubing string 16 ends as
shown in this example at just above the lower end of casing 14.
Subsurface formation 12 has two characteristics shown which are
important to the application of this invention. One is a large
fracture 20 which extends from the wellbore for a very substantial
distance, e.g., hundreds of feet or more. If fluid is injected into
the wellbore 10, most of the injected fluid will flow through
fracture 20; thus, many call this a thief zone. The two patents
listed above, U.S. Pat. No. 3,486,559 and U.S. Pat. No. 3,713,489,
disclose means of plugging thief zone 20.
Another geological feature of the formation 12, in which I am
particularly interested, is the so-called secondary porosity as
defined above. This is illustrated by the numerous short vugular
spaces 22, which are intercepted by wellbore 10. The permeability
in these vugs is many times greater than the matrix permeability of
the formation. These vugs would normally extend for a few inches
but may, due to prior stimulation, be poorly connected over a
radius of a few feet around the wellbore. These channels are closed
off or play out or their resistance to flow becomes very great
within a few feet of the wellbore. Then, any additional flow or
injection into these vugs 22 would have to be to the matrix,
itself, which is what is desired in the secondary recovery
operations. What then is desired in this situation is to plug the
thief zone 20 but have zones 22 open so that they can receive
injection water. That is exactly what my disclosed system
contains.
Attention is next directed to FIG. 2. This figure is the same as
FIG. 1 except that it illustrates that a limestone slurry has been
injected through the wellbore into the formation, filling the
secondary porosity 22, as well as thief zone 20 near the wellbore.
I preferably inject a slurry of limestone at a pressure level above
the fracture opening pressure so that we fill the secondary
porosity 22 and open fracture 20 to receive some of the limestone
slurry. Under this system, the limestone slurry has extended to a
point 26. One can see that the secondary porosity 22 is filled with
limestone slurry and will not be able to receive any of the second
slurry which is injected, as shown in FIG. 3.
In FIG. 3 it is shown that a flyash slurry 28 now fills thief zone
20, which was first filled with the limestone dust. The limestone
slurry is now illustrated as having been driven to point 30, an
increased distance from the well. The flyash slurry is continued to
be injected into the formation until a sufficient quantity is
injected. U.S. Pat. No. 3,713,489, supra., describes the technique
for injecting flyash slurry. The flyash slurry normally comprises
water as the carrier fluid, containing about 18 to 26 lbs of flyash
per gallon of water. Various additives and flow injection
procedures are described in that patent. Those directions for
injecting flyash will not be repeated here.
Attention is next directed to FIG. 4. After the desired quantity of
flyash slurry is injected, that injection is stopped. This is then
followed by an acid treatment. Shown in FIG. 4 is a macaroni string
32, which extends downwardly through the tubing 16 and has jets 34
at the lower end. A jet stream 36 of acid is forced out jets 34 and
cleans a good portion of the limestone dust from secondary porosity
22. The initial slurry of limestone dust is 80 percent soluble in
acid (such as 15 percent hydrochloric acid) while flyash is only
very slightly to not soluble at all in that acid.
While I have given limestone slurry as an example of the first
slurry to be injected, the important thing is that the small
particles or dust to be carried in the first slurry into the
secondary porosity be of such nature that it can be removed by
treatment which will not remove the second slurry particles.
Limestone dust is really the only practical material which I have
found for the first slurry. I prefer to use flyash as the finely
divided solids in the second slurry; however, other materials, such
as nutshell flour, can be used. The principal criteria is that it
be capable of being carried into the thief zone 20 and not be
removed by the cleaning process which removes the limestone from
the secondary porosity 22.
While the above invention has been disclosed in detail, other
embodiments may be made without departing from the spirit and scope
of the invention.
* * * * *