U.S. patent number 3,612,189 [Application Number 04/869,156] was granted by the patent office on 1971-10-12 for well perforating and treating apparatus.
This patent grant is currently assigned to Esso Production Research Company. Invention is credited to Fred A. Brooks, Leroy H. Simons.
United States Patent |
3,612,189 |
Brooks , et al. |
October 12, 1971 |
WELL PERFORATING AND TREATING APPARATUS
Abstract
A well completion apparatus for perforating and injecting a
fluid into a formation surrounding a cased wellbore. The apparatus
includes a body unit defining an enclosed chamber, a perforator
mounted in the chamber, a conduit in fluid communication with the
chamber and adapted to conduct fluid from the surface to the
chamber, and a mechanism for firing the perforator to form a flow
passage between the formation and the chamber.
Inventors: |
Brooks; Fred A. (Houston,
TX), Simons; Leroy H. (Houston, TX) |
Assignee: |
Esso Production Research
Company (N/A)
|
Family
ID: |
25353029 |
Appl.
No.: |
04/869,156 |
Filed: |
October 24, 1969 |
Current U.S.
Class: |
175/4.54;
166/297; 175/4.59; 166/55.1; 175/4.55 |
Current CPC
Class: |
E21B
33/138 (20130101); F42D 1/04 (20130101); E21B
43/11852 (20130101); E21B 43/117 (20130101) |
Current International
Class: |
E21B
33/138 (20060101); F42D 1/00 (20060101); F42D
1/04 (20060101); E21B 43/11 (20060101); E21B
43/117 (20060101); E21B 43/1185 (20060101); E21b
043/117 (); E21b 043/119 () |
Field of
Search: |
;166/297,298,55,55.1
;175/4.52,4.54-4.6 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Calvert; Ian A.
Claims
I claim:
1. An apparatus for treating a subterranean formation surrounding a
wellbore, said apparatus comprising a conduit, a body unit
supported on said conduit and defining an enclosed chamber, said
conduit having fluid conductor means in fluid communication with
said chamber and in fluid communication with said wellbore; a
perforator mounted in said chamber; means for actuating said
perforator in response to a predetermined pressure in said chamber;
and means for closing the conductor means in fluid communication
with said wellbore.
2. The invention as recited in claim 1 wherein said fluid conductor
means includes a tube extending through said chamber, said tube
having a lower end communicating with said wellbore and port means
communicating with said chamber.
3. The invention as recited in claim 2 wherein said means for
closing said conductor means communicating with said wellbore
includes a seat formed in said lower end of said tube and a sealing
member passable through said conduit and said tube and engageable
with said seat in sealing relationship.
4. A well completion apparatus for fluid treating a subterranean
formation surrounding a cased wellbore, said apparatus comprising:
a lower body unit defining an enclosed chamber; an upper body unit
defining an enclosed chamber, said units being assembled in
vertically spaced relationship; a conduit in fluid communication
with each of said chambers and adapted to conduct a treating fluid
to each of said chambers; perforating means mounted in each of said
chambers; and means for actuating said perforating means in said
upper and lower units at selected times.
5. The invention as recited in claim 4 wherein each of said
perforating means includes a perforator gun and firing mechanism
operatively responsive to a predetermined fluid pressure in said
conduit, the predetermined fluid pressure for actuating the lower
unit firing mechanism being substantially lower than the
predetermined fluid pressure for actuating the upper unit firing
mechanism, and said means for actuating said perforating means
includes means for increasing the pressure in said conduit to
actuate said lower unit firing mechanism and then to increase the
pressure in said conduit to actuate said upper unit firing
mechanism.
6. The invention as recited in claim 5 wherein said lower unit
perforating means includes means for arming said upper unit firing
mechanism responsive to actuation of said first unit firing
mechanism.
7. The invention as recited in claim 6 wherein said means for
increasing the pressure in said conduit includes a sealing member
passable through said conduit and lodgeable in said lower unit to
interrupt fluid communication between said lower unit chamber and
said conduit.
8. The invention as recited in claim 8 wherein said conduit
includes a tube extending through said upper unit chamber and being
connected in fluid communication with said lower unit chamber, said
tube having port means communicating with said upper unit chamber,
said sealing member being adapted to lodge in said tube to
interrupt fluid communication between said upper unit chamber and
said lower unit chamber.
9. The invention as recited in claim 8 wherein each unit perforator
gun includes a plurality of vertically spaced jet perforators, the
unit spacing and jet perforator spacing being such to provide a
shot density of about one shot per foot of thickness of the
formation to be treated.
10. A well completion apparatus for fluid treating a subterranean
formation surrounding a cased wellbore, said apparatus comprising:
a lower body unit defining an enclosed lower chamber; at least one
upper body unit defining an enclosed upper chamber; means for
assembling said lower body unit and said upper body unit in axial
and spaced-apart alignment; a conduit adapted to support and locate
the assembled units opposite said formation and providing conductor
means for delivering treating fluid to each of said chambers;
perforating means mounted in each of said chambers; means for first
actuating said perforating means of said lower unit to form a fluid
passage between said lower chamber and said formation, and then
actuating said perforating means of said upper unit to form a fluid
passage between said upper chamber and said formation.
Description
BACKGROUND OF THE INVENTION
1. Field of the Invention
This invention relates to an apparatus for placing a treating fluid
in a formation surrounding a wellbore.
2. Description of the Prior Art
In completing wells in unconsolidated formations, consideration
must be given to the sand problems likely to arise during operation
of the wells. The migration of formation fines can be controlled by
a variety of sand control techniques, all of which in effect
establish a sand exclusion zone through which the formation fluids
must pass en route to the wellbore. The sand exclusion zone can be
provided by mechanical means, e.g., liners, screens, gravel packs,
or by consolidation with plastics.
The present invention is concerned with fluid-treating subterranean
formations and has particular application in the placement of sand
consolidating plastics. The concept of forming a coherent permeable
sheath about the wellbore by use of thermosetting plastics has long
been known. However, widespread application of the plastic
consolidating principle awaited development of techniques and tools
for performing the consolidation process. One such tool recently
developed is the so-called "shoot-and-inject" tool. This tool
obviated many of the problems previously experienced in performing
sand consolidation treatment, particularly in the placement of the
plastic. The tool is designed to selectively and incrementally
place plastic in the formation. Its components include a perforator
for forming a single isolated perforation in the casing and an
assembly for injecting the treating fluids through the
perforation--hence, the name "shoot-and-injects " tool. The
assembly for injecting the chemicals includes a reservoir provided
with a valve system for maintaining the chemical components
segregated during running and injection operations. All of the
components are self-contained, permitting running and operation on
conventional wire line equipment.
The self-containment construction of the "shoot-and-inject" tool
limits the treatment volume to the relatively small capacity of the
reservoir. Field experience has indicated that the success of a
plastic consolidation treatment depends to a large extent upon the
volume of plastic injected. Generally the recommended chemical
volume is in the range from 20 to 50 gallons for each foot of
formation to be treated. This size of treatment requires that the
chemicals be placed in the formation by the conventional
"through-tubing" technique. This technique places the chemical in
the formation by surface pumping through the tubing and permits
surface control of injection volumes, rates, and pressures.
However, it sacrifices the selectivity feature offered by the
"shoot-and-inject" tool.
In addition to the capacity limitation described above, the
"shoot-and-inject" tool presents certain operational problems. It
is essential to the operation of the tool that the target area be
isolated prior to the actuation of the perforator. Target isolation
generally is provided by an annular sealing member which, when
pressed against the interior surface of the casing by the action of
a hydraulic ram, establishes a pressure seal between the passage
formed by the perforator and the wellbore. The sealing member,
hydraulic ram, and ram actuator increase the complexity of the tool
construction and tool operation.
SUMMARY OF THE INVENTION
The well completion apparatus constructed according to the present
invention combines the selectivity of the "shoot-and-inject" tool
and the injection capabilities of the "through-tubing" placement
technique. The apparatus includes a body unit which defines an
enclosed chamber, perforating means mounted in the chamber, and a
conduit in fluid communication with the chamber. With the body
located opposite the zone to be consolidated, the conduit extends
to the surface, providing a fluid conductor to the unit chamber.
When the perforator is actuated, a passage is formed between the
unit chamber and the formation permitting the injection of treating
fluid into the chamber via the conduit, the unit chamber, and the
passage. A plurality of the body units can be arranged in stacked
relation and selectively actuated so that the formation is treated
in vertically adjacent intervals. Moreover, since the injection
volume is controlled by surface facilities, the dimensions of the
tool are restricted only to that which will house the internal
components, e.g., perforating means. Using conventional-shaped
charges as the perforating means, the outside diameter of each unit
can be sized to pass readily through 21/3 inch casing. Thus the
"shoot1and-inject" technique can be used in tubingless
completions.
Since the apparatus does not require the isolation of the target
area, the annular seal and hydraulic ram required on the presently
known "shoot-and-inject" tools can be eliminated, thereby greatly
simplifying the structure and operation of the tool.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a sectional view of a wellbore showing the completion
apparatus constructed according to the present invention disposed
opposite an unconsolidated formation.
FIGS. 2 and 3 are views similar to FIG. 1 showing the apparatus and
hole conditions at various stages in the treating process.
FIG. 4 is an enlarged longitudinal sectional view of the unit shown
in FIGS. 1 through 3.
FIG. 5 is a transverse sectional view of FIG. 4 taken generally
along the cutting plane indicted by the line 5--5 thereof.
FIG. 6 is a wiring diagram for the perforating means used in the
assembly of units shown in FIGS. 1 through 3.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
With reference to FIG. 1, the well completion apparatus, referred
to generally as 10, is shown suspended in a cased wellbore 11
opposite an unconsolidated formation 12. The wellbore 11 has been
drilled from the earh's surface and is provided with a casing
string 13 surrounded by a cement sheath 14. Preparatory to
completing the well, the casing is filled with a light completion
fluid, e.g., diesel oil, with a lower section (rat hole 16)
remaining occupied with salt water.
The apparatus 10 includes generally an assembly comprising a
conduit 17 and a plurality of body units, e.g., a first unit 18, a
second unit 19, and a third unit 20. The units 18, 19, and 20 are
arranged in axially aligned and stacked relation so that when the
assembly is located opposite the formation 12, the units confront
vertically spaced intervals thereof.
Since each unit is identical in structure to permit interchangeable
use, only the lower unit 18 will be described, with like-primed and
double-primed reference numerals being assigned to corresponding
parts of the middle and upper units, 19 and 20 respectively.
As shown in FIGS. 4 and 5 each unit, e.g., 18, includes a
cylindrical hollow body 22 having top and bottom closure members 23
and 24. The assembled body 22 defines an enclosed chamber 25. An
angulated tube 26 extends through the chamber 25 terminating in
threaded ends on either side of closure members 23 and 24. The
angulated configuration of tube 26 provides clearance within
chamber 25 for the perforating means. The tube has port means in
the form of a perforated section 27 communicating with the chamber
25. As described below, the perforated section 27 provides fluid
communication between the conduit 17 and the chamber 25. The
angular portions of the tube 26 are smoothly rounded to permit the
passage of sealing members through the interior of the tube 26.
A perforator gun 28 mounted in chamber 25 is detonated by an
electric firing mechanism 29 comprising a battery 30, a detonator
31, and a pressure switch 32. The perforator gun 28 can be of any
conventional construction but preferably the perforators shown as
33 and 34 are jet perforators contained in an enclosed carrier 36
so that the firing thereof will not damage other unit components.
With the carrier 36 secured to the inner wall of body 22, the
perforaters 33 and 34 are oriented to fire in a direction which
lies in a plane passing through the axes of body 22 and carrier 36
away from tube 26.
The units 18-20 are identical in structure and operations.
Therefore any number of units can be assembled in any order by
merely coupling together the exposed threaded ends of the
respective tubes 26 (see FIG. 1). The upper exposed end of tube 26"
can be coupled to the conduit 17 for running-in operations, the
lower exposed end of member 26 being provided with a perforated cap
37. Thus when the assembly is located opposite the formation 12,
the conduit 17 in fluid communication with each unit chamber 25,
25', 25" through tubes 26, 26' and 26" provides fluid conductor
means for delivering treating fluid to each of the units 18-20 and
to the wellbore 11. The total number of units in the assembly will
depend upon the thickness of the zone to be treated. The spacing of
the perforators 33, 34; 33', 34'; etc. of the entire assembly
preferably should provide a perforation density of about one hole
per foot. If the thickness of the zone to be consolidated
approximates 6 feet, the assembly will normally comprise three
units as shown in FIGS. 1-3.
The pressure switch 32 wired into the electric firing circuit as
shown in FIG. 6, serves the dual function of detonating the
associated perforating gun 28 and arming the firing mechanism of
the vertically adjacent unit. Each pressure switch 32 closes in
response to a predetermined fluid pressure in its associated
chamber 25. The pressure switch 32 of the bottom unit 18 is preset
to close at a pressure substantially above the wellbore static
pressure.
With the assembly of units 18-20 located at the proper depth, the
fluid pressure in the chambers 25, 25', 25" is gradually increased
by means described below. When the pressure in the bottom chamber
25 reaches the preset pressure of switch 32, the electric circuit
for the perforating means enclosed therein is completed, causing
the perforator gun 28 thereof to fire. In addition to firing the
perforators, the closing the switch 32 establishes a ground
connection for the firing circuit of the vertically adjacent the
unit 19 thereby placing it in condition for firing. Firing of the
middle unit perforator gun 28' is occasioned by the continued
increase in system pressure, the preset pressure of the middle unit
switch 32' being sufficiently greater than that of the bottom unit
switch 32 to ensure independent and selective response. The closing
of the middle unit switch 32' fires the middle unit perforator gun
28' and arms the top unit firing mechanism 29" in the manner
described above. The preset pressure of switch 32" is sufficiently
greater than that of the preset pressure of 32' to ensure
independent and selective response to increase in pressure in
chamber 25". The pressure switches can be conventional single-pole,
single-throw switches provided with a 5-10 second time delay to
prevent premature actuation by explosive shock waves. A pressure
gap of 30-50 p.s.i. in the settings of switches 32' and 32" is
normally sufficient to enable independent and selective actuation
of the firing mechanisms 28, 28', and 28". The switches 32, 32',
and 32" can be differential pressure switches set to close at a
predetermined pressure above the wellbore pressure.
As indicated above, the tubes 26, 26', and 26" are connected in
series, and with the conduit 17 provide conductor means from the
surface to and through each unit 18-20. During running-in
operations, circulation can be maintained between the conduit 17
and the wellbore 11 through the passage provided by the perforated
cap 37. When the assembly of units 18-20 is properly located
opposite the zone to be treated, sealing members 38 are pumped
through the conduit 17 and the tubes 26", 26', and 26. The member
38 is received in sealing relation on a suitable seat provided in
the lower end of tube 26. This interrupts fluid communication with
the wellbore so that pressure buildup in the chambers 25, and 25"
can be effected by the operation of surface pumps. The pressure is
gradually increased in the system until the lowest preset pressure
(switch 32) is reached. The ensuing detonation of perforators 33 an
34 forms two fluid passages 39, 39 between the chamber 25 and the
formation 12. This permits the injection of treating fluids into
the formation 12 via conduit 17, tubes 26", 26', 26 chamber 25 and
flow passages 39 by the surface pumps.
While a variety of wipers or plugs can satisfactorily serve as the
sealing member 38, it is preferred that the sealing member be
spherical in configuration and composed of a resilient material
such as hard rubber or neoprene.The resilient balls provide
adequate separation between different chemicals used in the
treatment and yet are deformable under differential pressure to
sealingly engage the internal wall of the tubes 26, 26', and
26".
In order to increase the pressure in the vertically adjacent unit
19, a sufficient number of balls 38 are introduced into the fluid
conducted to chamber 25 to seal the perforated section 27 of tube
26 (see FIG. 2).
The closing of the lower chamber 25 permits pressuring-up of the
middle chamber 25 by operation of surface facilities. The pressure
is gradually increased to the preset pressure of switch 32'. The
resulting actuation of the middle unit perforating means forms flow
passages 39' between the formation 12 and middle unit chamber 25'.
This interval which is vertically spaced from the lower treated
interval then can be treated by operation of surface facilities.
Again a sufficient number of sealing members are introduced into
the treating stream to effect closure of the perforated section
27'. Thus each unit can be actuated in a steplike order permitting
the sequential treatment of the formation 12 in vertically adjacent
intervals. Moreover, the separate firing mechanism for each unit
permits the firing of their associated perforators at selected time
intervals.
Under certain conditions, as where the treating fluid density is
lighter than or equal to the completion fluid density, it may be
necessary to provide packing members on either side of the zone to
be treated. In this event, flexible, annularly shaped rubber wipers
40 can be mounted on the top of unit 20 and the bottom of unit 18.
During running-in, pulling-out, and circulation operations, the
flexible wipers 40 fold back, permitting the passage of fluid
thereby.
The operations of the apparatus constructed according to the
present invention will be briefly described with reference to FIGS.
1, 2, and 3. The number of units 18-20 assembled and wired together
in the manner described above is determined by the length of the
interval to be consolidated. In this embodiment three units 18-20
are so assembled. The assembly is attached to the conduit 17, run
in the wellbore 11, and located opposite the zone to be treated.
The initial treatment volume is pumped into the conduit 17 while
taking returns on the casing 13. The leading portion of the
treating fluid is provided with a plurality of sealing balls 38
such that when the fluid reaches the perforated section 27 of unit
18, the final ball is located slightly below the perforated
section. This condition will be reflected at the surface by a
slight increase in pump pressure since the leading ball is
sealingly received in the lower end of tube 26. Fluid is slowly
pumped into the conduit 17 causing an increase in pressure in the
lower chamber 25. The pressure-responsive perforating means is
actuated forming a fluid passage 39 between the formation 12 and
chamber 25. This permits the injection of treating fluid into the
formation 12 forming a generally spherically shaped invaded zone.
The trailing portion of the treating fluid is provided with a
sufficient number of balls 38 to pressure seal the bottom unit
perforated section 27. Again the pressure is gradually increased,
actuating the pressure responsive perforating means of the middle
unit 19. The middle unit is treated as previously described, the
trailing portion of the treating fluid being provided with a
plurality of balls 38 which upon completion of the treatment seals
the middle unit perforated section. Again the pressure in the
column is gradually increased, actuating the perforating means of
the top unit 20 forming passages 39". This permits treatment of the
top interval. At the conclusion of the treatment, the invaded zone
of the formation will be of general cylindrical shape as depicted
in FIG. 3.
In order to ensure the sequential treatment of the vertically
spaced intervals, a plugging solution such as an oil base mud can
be used following each treatment so that the fluid passages 39,
39', and 39" are temporarily plugged. These plugs can be removed by
producing the well.
The well completion apparatus of this invention has particular
application in plastic, sand consolidation treatments. Each
vertically adjacent interval can be treated with a plurality of
chemicals comprising a preflush, a plastic resin, a hardener or
catalyst, and a plugging solution. In treating each interval the
various solutions can be separated by one or more of the sealing
balls 38 which can be collected in stacked relationship in the
tubes 26, 26', and 26". The apparatus can be used in the placement
of any the presently known sand-consolidating plastics, the most
important of which are the epoxy resins, the phenol-formaldehyde
resins, and the furan resins. It can be used in premixed system
(resin and catalyst mixed before placement) or the in situ mixed
system (resin and catalyst mixed in the formation).
* * * * *