-
The present invention relates generally to operations performed within
subterranean wells, and more particularly relates to apparatus and for controlling fluid
flow within a subterranean well. More specifically, the invention relates to a remotely
operable actuator for use in subterranean wells. In an aspect, the invention relates to
a downhole hydraulic power source.
-
In horizontal well open hole completions, fluid migration has typically been
controlled by positioning a production tubing string within the horizontal wellbore
intersecting a formation. An annulus formed between the wellbore and the tubing string
is then packed with gravel. A longitudinally spaced apart series of sliding sleeve valves
in the tubing string provides fluid communication with selected portions of the formation
in relatively close proximity to an open valve, while somewhat restricting fluid
communication with portions of the formation at greater distances from an open valve.
In this manner, water and gas coning may be reduced in some portions of the formation
by closing selected ones of the valves, while not affecting production from other
portions of the formation.
-
Unfortunately, the above method has proved unsatisfactory, inconvenient and
inefficient for a variety of reasons. First, the gravel pack in the annulus does not
provide sufficient fluid restriction to significantly prevent fluid migration longitudinally
through the wellbore. Thus, an open valve in the tubing string may produce a
significant volume of fluid from a portion of the formation longitudinally remote from the
valve. However, providing additional fluid restriction in the gravel pack in order to
prevent fluid migration longitudinally therethrough would also deleteriously affect
production of fluid from a portion of the formation opposite an open valve.
-
Second, it is difficult to achieve a uniform gravel pack in horizontal well
completions. In many cases the gravel pack will be less dense and/or contain voids in
the upper portion of the annulus. This situation results in a substantially unrestricted
longitudinal flow path for migration of fluids in the wellbore.
-
Third, in those methods which utilize the spaced apart series of sliding sleeve
valves, intervention into the well is typically required to open or close selected ones of
the valves. Such intervention usually requires commissioning a slickline rig, wireline
rig, coiled tubing rig, or other equipment, and is very time-consuming and expensive
to perform. Furthermore, well conditions may prevent or hinder these operations.
-
Therefore, it would be advantageous to provide a method of controlling fluid flow
within a subterranean well, which method does not rely on a gravel pack for restricting
fluid flow longitudinally through the wellbore. Additionally, it would be advantageous
to provide associated apparatus which permits an operator to produce or inject fluid
from or into a selected portion of a formation intersected by the well. These methods
and apparatus would be useful in open hole, as well as cased hole, completions.
-
It would also be advantageous to provide a method of controlling fluid flow within
a well, which does not require intervention into the well for its performance. Such
method would permit remote control of the operation, without the need to kill the well
or pass equipment through the wellbore.
-
In carrying out the principles of the present invention, in accordance with an
embodiment thereof, an actuator is provided which is operable to actuate a wide variety
of well tools. The actuator may be actuated remotely by transmitting a signal thereto,
by coupling an electrical power source thereto, and by other methods.
-
In one aspect of the present invention, the actuator includes multiple chambers
formed between first and second members. The members are biased to displace
relative to each other by a pressure differential between at least two of the chambers.
A releasing device releasably prevents such displacement. The releasing device may
be remotely operated.
-
In another aspect of the present invention, one of the chambers is substantially
filled with a fluid. The fluid prevents relative displacement between the first and second
members. A valve connected to the fluid-filled chamber selectively permits discharge
of the fluid from the chamber, thereby permitting relative displacement between the first
and second members. The valve may be remotely operable by transmitting a signal to
a receiver connected to the valve. The valve may include a choke or flow restrictor,
which may be variable in response to a signal received by the receiver, in order to
regulate flow of the fluid from the chamber.
-
In still another aspect of the present invention, the actuator may be configured
to elevate fluid pressure within the fluid-filled chamber. This may be accomplished by
providing multiple sets of chambers wherein pressure differentials are created between
the chambers, or different piston areas may be provided for different chambers. The
output of the valve may be connected to a well tool so that the well tool may be
operated by the elevated fluid pressure.
-
According to another aspect of the invention there is provided a remotely
operable actuator operatively positionable in a subterranean well, the actuator
comprising: first and second reciprocably disposed members; at least first and second
chambers disposed between the first and second members, a fluid pressure differential
between the first and second chambers biasing the first and second members to
displace relative to each other; and a remotely operable releasing device releasably
securing the first and second members against displacement relative to each other.
-
In an embodiment, the first chamber is exposed to fluid pressure external to the
first chamber.
-
In an embodiment, the second chamber contains a gas at a relatively low
pressure.
-
In an embodiment, the releasing device releases the first and second members
for displacement relative to each other when a signal is received by a receiver
connected to the releasing device.
-
In an embodiment, the releasing device includes a solenoid, the solenoid
displacing a component of the releasing device when the signal is received by the
receiver.
-
In an embodiment, the releasing device includes a valve, the valve operating in
response to the signal being received by the receiver.
-
In an embodiment, the releasing device includes a tumbler preventing relative
displacement between the first and second members, and a solenoid, the tumbler
displacing and permitting relative displacement between the first and second members
when the solenoid is activated, the solenoid being activated upon transmission of a
signal from a remote location.
-
In an embodiment, the releasing device includes a piston preventing relative
displacement between the first and second members, the piston displacing into a fluid
containing chamber and permitting relative displacement between the first and second
members when a valve connected to the chamber is activated, the valve being
activated upon transmission of a signal from a remote location.
-
According to another aspect of the invention there is provided a remotely
operable actuator operatively positionable in a subterranean well, the actuator
comprising: first and second reciprocably disposed members; at least a first chamber
formed between the first and second members, the first chamber having a fluid
contained therein, the fluid preventing relative displacement between the first and
second members; and a remotely operable valve connected to the first chamber, the
valve being operative to permit discharge of the fluid from the first chamber and thereby
permit relative displacement between the first and second members.
-
In an embodiment, the valve is remotely operable in response to reception of a
signal by a receiver connected to the valve.
-
In an embodiment, the actuator further comprises a flow restrictor, the flow
restrictor restricting discharge of the fluid from the first chamber when the valve is
operated.
-
In an embodiment, the flow restrictor has a restriction to flow therethrough which
is variable in response to reception of a signal by a receiver connected to the flow
restrictor.
-
In an embodiment, the actuator further comprises second and third chambers
formed between the first and second members, a pressure differential between the
second and third chambers biasing the first and second members to displace relative
to each other. The second chamber may be exposed to fluid pressure external to the
second chamber, and the third chamber may contain a gas at a relatively low pressure.
-
In an embodiment, the actuator further comprises fourth and fifth chambers
formed between the first and second members, a pressure differential between the
fourth and fifth chambers biasing the first and second members to displace relative to
each other. The fourth chamber may be exposed to fluid pressure external to the fourth
chamber, and the fifth chamber may contain a gas at a relatively low pressure.
-
In an embodiment, the pressure differential between the second and third
chambers creates a pressure within the first chamber greater than fluid pressure in the
second chamber.
-
In an embodiment, the pressure differential between the second and third
chambers, and the pressure differential between the fourth and fifth chambers creates
a pressure within the first chamber greater than fluid pressure in the fourth chamber.
-
In an embodiment, the third chamber has a piston area larger than a piston area
of the second chamber, thereby creating a pressure within the first chamber greater
than fluid pressure in the second chamber.
-
According to another aspect of the invention there is provided a remotely
operable actuator operatively positionable in a subterranean well, the actuator
comprising: a generally tubular outer housing; a generally tubular inner mandrel
sealingly engaged within the outer housing and forming an annular space
therebetween; a plurality of chambers formed in the annular space, at least one of the
chambers containing a fluid, the fluid preventing relative displacement between the
housing and mandrel; and a remotely operable valve selectively permitting and
preventing discharge of the fluid from the chamber containing the fluid.
-
In an embodiment, the valve is remotely controllable via a receiver connected
thereto, the receiver causing the valve to operate in response to a signal transmitted
from a remote location.
-
In an embodiment, an output of the valve is connected to a well tool for actuation
thereof.
-
In an embodiment, the valve includes a flow restrictor which variably restricts
discharge of the fluid from the chamber containing the fluid.
-
In an embodiment, the flow restrictor is remotely controllable via a receiver
connected thereto, the receiver causing the flow restrictor to operate in response to a
signal transmitted from a remote location.
-
Reference is now made to the accompanying drawings, in which:
- FIG. 1 is a schematicized cross-sectional view of a subterranean well;
- FIG. 2 is a schematicized partially cross-sectional and partially elevational view
of the well of FIG. 1, in which steps of a first embodiment of a method according to the
present invention have been performed;
- FIG. 3 is a schematicized partially cross-sectional and partially elevational view
of the well of FIG. 1, in which steps of a second embodiment of a method according to
the present invention have been performed;
- FIG. 4 is a schematicized partially cross-sectional and partially elevational view
of the well of FIG. 1, in which steps of a third embodiment of a method according to the
present invention have been performed;
- FIG. 5 is a schematicized partially cross-sectional and partially elevational view
of the well of FIG. 1, in which steps of a fourth embodiment of a method according to
the present invention have been performed;
- FIG. 6 is a schematicized partially cross-sectional and partially elevational view
of the well of FIG. 1, in which steps of a fifth embodiment of a method according to the
present invention have been performed;
- FIG. 7 is a schematicized partially cross-sectional and partially elevational view
of the well of FIG. 1, in which steps of a sixth embodiment of a method according to the
present invention have been performed;
- FIG. 8 is a schematicized partially cross-sectional and partially elevational view
of the well of FIG. 1, in which steps of a seventh embodiment of a method according
to the present invention have been performed;
- FIG. 9 is a schematicized cross-sectional view of a first embodiment of an
apparatus according to the present invention;
- FIG. 10 is a schematicized quarter-sectional view of a first embodiment of a
release device according to the present invention which may be used with the first
apparatus;
- FIG. 11 is a schematicized quarter-sectional view of a second embodiment of a
release device according to the present invention which may be used with the first
apparatus;
- FIG. 12 is a schematicized quarter-sectional view of a second embodiment of an
apparatus according to the present invention;
- FIG. 13 is a schematicized quarter-sectional view of a third embodiment of an
apparatus according to the present invention;
- FIG. 14 is a schematicized quarter-sectional view of a fourth embodiment of an
apparatus according to the present invention;
- FIG. 15 is a cross-sectional view of an embodiment of an atmospheric chamber
according to the present invention;
- FIG. 16 is a schematicized view of a fifth embodiment of an apparatus according
to the present invention;
- FIG. 17 is a schematicized view of a sixth embodiment of an apparatus
according to the present invention;
- FIG. 18 is a schematicized elevational view of a seventh embodiment of an
apparatus according to the present invention; and
- FIG. 19 is a schematicized elevational view of an eighth embodiment of an
apparatus according to the present invention.
-
-
Representatively and schematically illustrated in FIG. 1 is a method 10 which
embodies principles of the present invention. In the following description of the method
10 and other apparatus and methods described herein, directional terms, such as
"above", "below", "upper", "lower", etc., are used for convenience in referring to the
accompanying drawings. Additionally, it is to be understood that the various
embodiments of the present invention described herein may be utilized in various
orientations, such as inclined, inverted, horizontal, vertical, etc., without departing from
the principles of the present invention.
-
The method 10 is described herein as it is practiced in an open hole completion
of a generally horizontal wellbore portion 12 intersecting a formation 14. However, it
is to be clearly understood that methods and apparatus embodying principles of the
present invention may be utilized in other environments, such as vertical wellbore
portions, cased wellbore portions, etc. Additionally, the method 10 may be performed
in wells including both cased and uncased portions, and vertical, inclined and
horizontal portions, for example, including the generally vertical portion of the well lined
with casing 16 and cement 18. Furthermore, the method 10 is described in terms of
producing fluid from the well, but the method may also be utilized in injection
operations. As used herein, the term "wellbore" is used to indicate an uncased
wellbore (such as wellbore 12 shown in FIG. 1), or the interior bore of the casing or
liner (such as the casing 16) if the wellbore has casing or liner installed therein.
-
It will be readily appreciated by a person of ordinary skill in the art that if the well
shown in FIG. 1 is completed in a conventional manner utilizing gravel surrounding a
production tubing string including longitudinally spaced apart screens and/or sliding
sleeve valves, fluid from various longitudinal portions 20, 22, 24, 26 of the formation 14
will be permitted to migrate longitudinally through the gravel pack in the annular space
between the tubing string and the wellbore 12. Of course, a sliding sleeve valve may
be closed in an attempt to restrict fluid production from one of the formation portions
20, 22, 24, 26 opposite the valve, but this may have little actual effect, since the fluid
may easily migrate longitudinally to another, open, valve in the production tubing string.
-
Referring additionally now to FIG. 2, steps of the method 10 have been
performed which include positioning a tubing string 28 within the wellbore 12. The
tubing string 28 includes a longitudinally spaced apart series of sealing devices 30, 32,
34 and a longitudinally spaced apart series of flow control devices 36, 38, 40. The
tubing string 28 extends to the earth's surface, or to another location remote from the
wellbore 12, and its distal end is closed by a bull plug 42.
-
The sealing devices 30, 32, 34 are representatively and schematically illustrated
in FIG. 2 as inflatable packers, which are capable of radially outwardly extending to
sealingly engage the wellbore 12 upon application of fluid pressure to the packers. Of
course, other types of packers, such as production packers settable by pressure, may
be utilized for the packers 30, 32, 34, without departing from the principles of the
present invention. The packers 30, 32, 34 utilized in the method 10 have been
modified somewhat, however, using techniques well within the capabilities of a person
of ordinary skill in the art, so that each of the packers is independently inflatable. Thus,
as shown in FIG. 2, packers 30 and 32 have been inflated, while packer 34 remains
deflated.
-
In order to inflate a selected one of the packers 30, 32, 34, a fluid power source
is conveyed into the tubing string 28, and fluid is flowed into the packer. For example,
in FIG. 2 a coiled tubing string 44 has been inserted into the tubing string 28, the coiled
tubing string thereby forming a fluid conduit extending to the earth's surface.
-
At its distal end, the coiled tubing string 44 includes a latching device 46 and a
fluid coupling 48. The latching device 46 is of conventional design and is used to
positively position the fluid coupling 48 within the selected one of the packers 30, 32,
34. For this purpose, each of the packers 30, 32, 34 includes a conventional internal
latching profile (not shown in FIG. 2) formed therein.
-
The coupling 48 provides fluid communication between the interior of the coiled
tubing string 44 and the packer 30, 32, 34 in which it is engaged. Thus, when the
coupling 48 is engaged within the packer 30 as shown in FIG. 2, fluid pressure may be
applied to the coiled tubing string 44 and communicated to the packer via the coupling
48. Deflation of a previously inflated packer may be accomplished by relieving fluid
pressure from within a selected one of the packers 30, 32, 34 via the coupling 48 to the
coiled tubing string 44, or to the interior of the tubing string 28, etc. Therefore, it may
be clearly seen that each of the packers 30, 32, 34 may be individually and selectively
set and unset within the wellbore 12.
-
The flow control devices 36, 38, 40 are representatively illustrated as sliding
sleeve-type valves. However, it is to be understood that other types of flow control
devices may be used for the valves 36, 38, 40, without departing from the principles of
the present invention. For example, the valves 36, 38, 40 may instead be downhole
chokes, pressure operated valves, remotely controllable valves, etc.
-
Each of the valves 36, 38, 40 may be opened and closed independently and
selectively to thereby permit or prevent fluid flow between the wellbore 12 external to
the tubing string 28 and the interior of the tubing string. For example, the latching
device 46 may be engaged with an internal profile of a selected one of the valves 36,
38, 40 to shift its sleeve to its open or closed position in a conventional manner.
-
As representatively depicted in FIG. 2, packers 30 and 32 have been inflated
and the valve 36 has been closed, thereby preventing fluid migration through the
wellbore 12 between the formation portion 22 and the other portions 20, 24, 26 of the
formation 14. Note that fluid from the portion 22 may still migrate to the other portions
20, 24, 26 through the formation 14 itself, but such flow through the formation 14 will
typically be minimal compared to that which would otherwise be permitted through the
wellbore 12. Thus, flow of fluids from the portion 22 to the interior of the tubing string
28 is substantially restricted by the method 10. It will be readily appreciated that
production of fluid from selected ones of the other portions 20, 24, 26 may also be
substantially restricted by inflating other packers, such as packer 34, and closing other
valves, such as valves 38 or 40. Additionally, inflation of the packer 30 may be used
to substantially restrict production of fluid from the portion 20, without the need to close
a valve.
-
If, however, it is desired to produce fluid substantially only from the portion 22,
the valve 36 may be opened and the other valves 38, 40 may be closed. Thus, the
method 10 permits each of the packers 30, 32, 34 to be selectively set or unset, and
permits each of the valves 36, 38, 40 to be selectively opened or closed, which enables
an operator to tailor production from the formation 14 as conditions warrant. The use
of variable chokes in place of the valves 36, 38, 40 allows even further control over
production from each of the portions 20, 22, 24, 26.
-
As shown in FIG. 2, three packers 30, 32, 34 and three valves 36, 38, 40 are
used in the method 10 to control production from four portions 20, 22, 24, 26 of the
formation 14. It will be readily appreciated that any other number of packers and any
number of valves (the number of packers not necessarily being the same as the number
of valves) may be used to control production from any number of formation portions, as
long as a sufficient number of packers is utilized to prevent flow through the wellbore
between each adjacent pair of formation portions. Furthermore, production from
additional formations intersected by the wellbore could be controlled by extending the
tubing string 28 and providing additional sealing devices and flow control devices
therein.
-
Referring additionally now to FIG. 3, another method 50 is schematically and
representatively illustrated. Elements of the method 50 which are similar to those
previously described are indicated in FIG. 3 using the same reference numbers, with
an added suffix "a".
-
The method 50 is in many respects similar to the method 10. However, in the
method 50, the power source used to inflate the packers 30a, 32a, 34a is a fluid pump
52 conveyed into the tubing string 28a attached to a wireline or electric line 54
extending to the earth's surface. The electric line 54 supplies electricity to operate the
pump 52, as well as conveying the latching device 46a, pump, and coupling 48a within
the tubing string 28a. Other conveyances, such as slickline, coiled tubing, etc., may
be used in place of the electric line 54, and electricity may be otherwise supplied to the
pump 52, without departing from the principles of the present invention. For example,
the pump 52 may include a battery, such as the Downhole Power Unit available from
Halliburton Energy Services, Inc. of Duncan, Oklahoma.
-
As depicted in FIG. 3, the latching device 46a is engaged with the packer 30a,
and the coupling 48a is providing fluid communication between the packer and the
pump 52. Actuation of the pump 52 causes fluid to be pumped into the packer 30a,
thereby inflating the packer, so that it sealingly engages the wellbore 12a. The packer
34a has been previously inflated in a similar manner. Additionally, the valves 36a, 38a
have been closed to restrict fluid flow generally radially therethrough.
-
Note that the packers 30a, 34a longitudinally straddle two of the formation
portions 22a, 24a. Thus, it may be seen that fluid flow from multiple formation portions
may be restricted in keeping with the principles of the present invention. If desired,
another flow control device could be installed in the tubing string 28a above the packer
30a to selectively permit and prevent fluid flow into the tubing string directly from the
formation portion 20a while the packer 30a is set within the wellbore 12a.
-
Referring additionally now to FIG. 4, another method 60 embodying principles
of the present invention is representatively illustrated. Elements shown in FIG. 4 which
are similar to those previously described are indicated using the same reference
numbers, with an added suffix "b".
-
The method 60 is similar in many respects to the method 50, in that the power
source used to set selected ones of the packers 30b, 32b, 34b includes the electric line
54b and a fluid pump 62. However, in this case the pump 62 is interconnected as a
part of the tubing string 28b. Thus, the pump 62 is not separately conveyed into the
tubing string 28b, and is not separately engaged with the selected ones of the packers
30b, 32b, 34b by positioning it therein. Instead, fluid pressure developed by the pump
62 is delivered to selected ones of the packers 30b, 32b, 34b and valves 36b, 38b, 40b
via lines 64.
-
As used herein, the term "pump" includes any means for pressurizing a fluid.
For example, the pump 62 could be a motorized rotary or axial pump, a hydraulic
accumulator, a device which utilizes a pressure differential between hydrostatic
pressure and atmospheric pressure to produce hydraulic pressure, other types of fluid
pressurizing devices, etc.
-
Fluid pressure from the pump 62 is delivered to the lines 64 as directed by a
control module 66 interconnected between the pump and lines. Such control modules
are well known in the art and may include a plurality of solenoid valves (not shown) for
directing the pump fluid pressure to selected ones of the lines 64, in order to actuate
corresponding ones of the packers 30b, 32b, 34b and valves 36b, 38b, 40b. For
example, if it is desired to inflate the packer 34b, the pump 62 is operated to provide
fluid pressure to the control module 66, and the control module directs the fluid
pressure to an appropriate one of the lines 64 interconnecting the control module to the
packer 34b by opening a corresponding solenoid valve in the control module.
-
Electricity to operate the pump 62 is supplied by the electric line 54b extending
to the earth's surface. The electric line 54b is properly positioned by engaging the
latching device 46b within the pump 62 or control module 66. A wet connect head 68
of the type well known to those of ordinary skill in the art provides an electrical
connection between the electric line 54b and the pump 62 and control module 66.
Alternatively, the electric line 54b may be a slickline or coiled tubing, and electric power
may be supplied by a battery installed as a part of the tubing string or conveyed
separately therein. Of course, if the pump 62 is of a type which does not require
electricity for its operation, an electric power source is not needed.
-
The control module 66 directs the fluid pressure from the pump 62 to selected
ones of the lines 64 in response to a signal transmitted thereto via the electric line 54b
from a remote location, such as the earth's surface. Thus, the electric line 54b
performs several functions in the method 60: conveying the latching device 46b and wet
connect head 68 within the tubing string 28b, supplying electric power to operate the
pump 62, and transmitting signals to the control module 66. Of course, it is not
necessary for the electric line 54b to perform all of these functions, and these functions
may be performed by separate elements, without departing from the principles of the
present invention.
-
Note that the valves 36b, 38b, 40b utilized in the method 60 differ from the
valves in the previously described methods 10, 50 in that they are pressure actuated.
Pressure actuated valves are well known in the art. They may be of the type that is
actuated to a closed or open position upon application of fluid pressure thereto and
return to the alternate position upon release of the fluid pressure by a biasing member,
such as a spring, they may be of the type that is actuated to a closed or open position
only upon application of fluid pressure thereto, or they may be of any other type.
Additionally, the valves 36b, 38b, 40b may be chokes in which a resistance to fluid flow
generally radially therethrough is varied by varying fluid pressure applied thereto, or
by balancing fluid pressures applied thereto. Thus, any type of flow control device may
be used for the valves 36b, 38b, 40b, without departing from the principles of the
present invention.
-
In FIG. 4, the packer 34b has been set within the wellbore 12b, and the valve
40b has been closed. The remainder of the valves 36b, 38b are open. Therefore, fluid
flow from the formation portion 26b to the interior of the tubing string 28b is restricted.
It may now be clearly seen that it is not necessary to set more than one of the packers
36b, 38b, 40b in order to restrict fluid flow from a formation portion.
-
Referring additionally now to FIG. 5, another method 70 embodying principles
of the present invention is schematically and representatively illustrated. In FIG. 5,
elements which are similar to those previously described are indicated using the same
reference numbers, with an added suffix "c".
-
The method 70 is substantially similar to the method 60 described above, except
that no intervention into the well is used to selectively set or unset the packers 30c,
32c, 34c or to operate the valves 36c, 38c, 40c. Instead, the pump 62c and control
module 66c are operated by a receiver 72 interconnected in the tubing string 28c.
Power for operation of the receiver 72, pump 62c and control module 66c is supplied
by a battery 74 also interconnected in the tubing string 28c. Of course, other types of
power sources may be utilized in place of the battery 74. For example, the power
source may be an electro-hydraulic generator, wherein fluid flow is utilized to generate
electrical power, etc.
-
The receiver 72 may be any of a variety of receivers capable of operatively
receiving signals transmitted from a remote location. The signals may be in the form
of acoustic telemetry, radio waves, mud pulses, electromagnetic waves, or any other
form of data transmission.
-
The receiver 72 is connected to the pump 62c, so that when an appropriate
signal is received by the receiver, the pump is operated to provide fluid pressure to the
control module 66c. The receiver 72 is also connected to the control module 66c, so
that when another appropriate signal is received by the receiver, the control module is
operated to direct the fluid pressure via the lines 64c to a selected one of the packers
30c, 32c, 34c or valves 36c, 38c, 40c. As such, the combined receiver 72, battery 74,
pump 62c and control module 66c may be referred to as a common actuator 76 for the
sealing devices and flow control devices of the tubing string 28c.
-
As shown in FIG. 5, the receiver 72 has received a signal to operate the pump
62c, and has received a signal for the control module 66c to direct the fluid pressure
to the packer 30c. The packer 30c has, thus, been inflated and is preventing fluid flow
longitudinally through the wellbore 12c between the formation portions 20c and 22c.
-
Referring additionally now to FIG. 6, another method 80 embodying principles
of the present invention is schematically and representatively illustrated. Elements of
the method 80 which are similar to those previously described are indicated in FIG. 6
with the same reference numbers, with an added suffix "d".
-
The method 80 is similar to the previously described method 70. However,
instead of a common actuator 76 utilized for selectively actuating the sealing devices
and flow control devices, the method 80 utilizes a separate actuator 82, 84, 86 directly
connected to a corresponding pair of the packers 30d, 32d, 34d and valves 36d, 38d,
40d. In other words, each of the actuators 82, 84, 86 is interconnected to one of the
packers 30d, 32d, 34d, and to one of the valves 36d, 38d, 40d.
-
Each of the actuators 82, 84, 86 is a combination of a receiver 72d, battery 74d,
pump 62d and control module 66d. Since each actuator 82, 84, 86 is directly
connected to its corresponding pair of the packers 30d, 32d, 34d and valves 36d, 38d,
40d, no lines (such as lines 64c, see FIG. 6) are used to interconnect the control
modules 66d to their respective packers and valves. However, lines could be provided
if it were desired to space one or more of the actuators 82, 84, 86 apart from its
corresponding pair of the packers and valves. Additionally, it is not necessary for each
actuator 82, 84, 86 to be connected to a pair of the packers and valves, for example,
a separate actuator could be utilized for each packer and for each valve, or for any
combination thereof, in keeping with the principles of the present invention.
-
In FIG. 6, the receiver 72d of the actuator 84 has received a signal to operate
its pump 62d, and a signal for its control module 66d to direct the fluid pressure
developed by the pump to the packer 32d, and then to direct the fluid pressure to the
valve 38d. The packer 32d is, thus sealingly engaging the wellbore 12d between the
formation portions 22d and 24d. Additionally, the receiver 72d of the actuator 86 has
received a signal to operate its pump 62d, and a signal for its control module 66d to
direct the fluid pressure to the packer 34d. Therefore, the packer 34d is sealingly
engaging the wellbore 12d between the formation portions 24d and 26d, and fluid flow
is substantially restricted from the formation portion 24d to the interior of the tubing
string 28d.
-
Referring additionally now to FIG. 7, another method 90 embodying principles
of the present invention is schematically and representatively illustrated. Elements
shown in FIG. 7 which are similar to those previously described are indicated using the
same reference numbers, with an added suffix "e".
-
The method 90 is similar to the method 70 shown in FIG. 5, in that a single
actuator 92 is utilized to selectively actuate the packers 30e, 32e, 34e and valves 36e,
38e, 40e. However, the actuator 92 relies only indirectly on a battery 94 for operation
of its fluid pump 96, thus greatly extending the useful life of the battery. A receiver 98
and control module 100 of the actuator 92 are connected to the battery 94 for operation
thereof.
-
The pump 96 is connected via a shaft 102 to an impeller 104 disposed within a
fluid passage 106 formed internally in the actuator 92. A solenoid valve 108 is
interconnected to the fluid passage 106 and serves to selectively permit and prevent
fluid flow from the wellbore 12e into an atmospheric gas chamber 110 of the actuator
through the fluid passage. Thus, when the valve 108 is opened, fluid flowing from the
wellbore 12e through the fluid passage 106 into the chamber 110 causes the impeller
104 and shaft 102 to rotate, thereby operating the pump 96. When the valve 108 is
closed, the pump 96 ceases to operate.
-
The valve 108 and control module 100 are operated in response to signals
received by the receiver 98. As shown in FIG. 7, the receiver 98 has received a signal
to operate the pump 96, and the valve 108 has been opened accordingly. The receiver
98 has also received a signal to operate the control module 100 to direct fluid pressure
developed by the pump 96 via the lines 64e to the packer 32e and then to the valve
36e. In this manner, the packer 32e has been inflated to sealingly engage the wellbore
12e and the valve 36e has been closed. Thus, it may be readily appreciated that fluid
flow from multiple formation portions 20e and 22e into the tubing string 28e has been
substantially restricted, even though only one of the packers 30e, 32e, 34e has been
inflated.
-
Of course, many other types of actuators may be used in place of the actuator
92 shown in FIG. 7. The actuator 92 has been described only as an example of the
variety of actuators that may be utilized for operation of the packers 30e, 32e, 34e and
valves 36e, 38e, 40e. For example, an actuator of the type disclosed in U.S. Patent
No. 5,127,477 may be used in place of the actuator 92. Additionally, the actuator 92
may be modified extensively without departing from the principles of the present
invention. For example, the battery 94 and receiver 98 may be eliminated by running
a control line 112 from a remote location, such as the earth's surface or another
location in the well, to the actuator 92. The control line 112 may be connected to the
valve 108 and control module 100 for transmitting signals thereto, supplying electrical
power, etc. Furthermore, the chamber 110, impeller 104 and valve 108 may be
eliminated by delivering power directly from the control line 112 to the pump 100 for
operation thereof.
-
Referring additionally now to FIG. 8, another method 120 embodying principles
of the present invention is schematically and representatively illustrated. In FIG. 8,
elements which are similar to those previously described are indicated using the same
reference numbers, with an added suffix "f".
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In the method 120, each packer 30f, 32f, 34f and each valve 36f, 38f, 40f has a
corresponding control module 122 connected thereto. The control modules 122 are of
the type utilized to direct fluid pressure from lines 124 extending to a remote location
to actuate equipment to which the control modules are connected. For example, the
control modules 122 may be SCRAMS modules available from Petroleum Engineering
Services of The Woodlands, Texas, and/or as described in U.S. Patent No. 5,547,029.
Accordingly, the lines 124 also carry electrical power and transmit signals to the control
modules 122 for selective operation thereof. For example, the lines 124 may transmit
a signal to the control module 122 connected to the packer 30f, causing the control
module to direct fluid pressure from the lines to the packer 30f, thereby inflating the
packer 30f. Alternatively, one control module may be connected to more than one of
the packers 30f, 32f, 34f and valves 36f, 38f, 40f in a manner similar to that described
in U.S. Patent No. 4,636,934.
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Referring additionally now to FIG. 9, an actuator 126 embodying principles of the
present invention is representatively illustrated. The actuator 126 may be used to
actuate any of the tools described above, such as packers 30, 32, 34, valves 36, 38,
40, flow chokes, etc. In particular, the actuator 126 may be utilized where it is desired
to have an individual actuator actuate a corresponding individual tool, such as in the
method 80 described above.
-
The actuator 126 includes a generally tubular outer housing 128, a generally
tubular inner mandrel 130 and circumferential seals 132. The seals 132 sealingly
engage both the outer housing 128 and the inner mandrel, and divide the annular
space therebetween into three annular chambers 134, 136, 138. Each of chambers
134 and 138 initially has a gas, such as air or nitrogen, contained therein at
atmospheric pressure or another relatively low pressure. Hydrostatic pressure within
a well is permitted to enter the chamber 136 via openings 140 formed through the
housing 128.
-
It will be readily appreciated by one skilled in the art that, with hydrostatic
pressure greater than atmospheric pressure in chamber 136 and surrounding the
exterior of the actuator 126, the outer housing 128 will be biased downwardly relative
to the mandrel 130. Such biasing force may be utilized to actuate a tool, for example,
a packer, valve or choke, connected to the actuator 126. For example, a mandrel of a
conventional packer which is set by applying a downwardly directed force to the packer
mandrel may be connected to the housing 128 so that, when the housing is downwardly
displaced relative to the inner mandrel 130 by the downwardly biasing force, the packer
will be set. Similarly, the actuator 126 may be connected to a valve, for example, to
displace a sleeve or other closure element of the valve, and thereby open or close the
valve. Note that either the housing 128 or the mandrel 130, or both of them, may be
interconnected in a tubular string for conveying the actuator 126 in the well, and either
the housing or the mandrel, or both of them, may be attached to the tool for actuation
thereof. Of course, the actuator 126 may be otherwise conveyed, for example, by
slickline, etc., without departing from the principles of the present invention.
-
Referring additionally now to FIGS. 10 and 11, devices 142, 144 for releasing
the housing 128 and mandrel 130 for relative displacement therebetween are
representatively illustrated. Each of the devices 142, 144 permits the actuator 126 to
be lowered into a well with increasing hydrostatic pressure, without the housing 128
displacing relative to the mandrel 130, until the device is triggered, at which time the
housing and mandrel are released for displacement relative to one another.
-
In FIG. 10, it may be seen that an annular recess 146 is formed internally on the
housing 128. A tumbler or stop member 148 extends outward through an opening 150
formed in the mandrel 130 and into the recess 146. In this position, the tumbler 148
prevents downward displacement of the housing 128 relative to the mandrel 130. The
tumbler 148 is maintained in this position by a retainer member 152.
-
A detent pin or lug 154 engages an external shoulder 156 formed on the mandrel
130 and prevents displacement of the retainer 152 relative to the tumbler 148. An outer
release sleeve or blocking member 158 prevents disengagement of the detent pin 154
from the shoulder 156. A solenoid 160 permits the release sleeve 158 to be displaced,
so that the detent pin 154 is released, the retainer is permitted to displace relative to
the tumbler 148, and the tumbler is permitted to disengage from the recess 146,
thereby releasing the housing 128 for displacement relative to the mandrel 130.
-
The solenoid 160 is activated to displace the release sleeve 158 in response to
a signal received by a receiver, such as receivers 72, 98 described above. For this
purpose, lines 162 may be interconnected to a receiver and battery as described above
for the actuator 76 in the methods 70, 80, or for the actuator 92 in the method 90.
Alternatively, electrical power may be supplied to the lines 162 via a wet connect head,
such as the wet connect head 68 in the method 60.
-
In FIG. 11, it may be seen that the recess 146 is engaged by a piston 164
extending outwardly from a fluid-filled chamber 166 formed in the mandrel 130. Fluid
in the chamber 166 prevents the piston 164 from displacing inwardly out of engagement
with the recess 146. A valve 168 selectively permits fluid to be vented from the
chamber 166, thereby permitting the piston 164 to disengage from the recess, and
permitting the housing 128 to displace relative to the mandrel 130.
-
The valve 168 may be a solenoid valve or other type of valve which permits fluid
to flow therethrough in response to an electrical signal on lines 170. Thus, the valve
168 may be interconnected to a receiver and/or battery in a manner similar to the
solenoid 160 described above. The valve 168 may be remotely actuated by
transmission of a signal to a receiver connected thereto, or the valve may be directly
actuated by coupling an electrical power source to the lines 170. Of course, other
manners of venting fluid from the chamber 166 may be utilized without departing from
the principles of the present invention.
-
Referring additionally now to FIG. 12, another actuator 172 embodying principles
of the present invention is representatively illustrated. The actuator 172 includes a
generally tubular outer housing 174 and a generally tubular inner mandrel 176.
Circumferential seals 178 sealingly engage the housing 174 and mandrel 176, isolating
annular chambers 180, 182, 184 formed between the housing and mandrel.
-
Chamber 180 is substantially filled with a fluid, such as oil. A valve 186, similar
to valve 168 described above, permits the fluid to be selectively vented from the
chamber 180 to the exterior of the actuator 172. When the valve 186 is closed, the
housing 174 is prevented from displacing downward relative to the mandrel 176.
However, when the valve 186 is opened, such as by using any of the methods
described above for opening the valve 168, the fluid is permitted to flow out of the
chamber 180 and the housing 174 is permitted to displace downwardly relative to the
mandrel 176.
-
The housing 174 is biased downwardly due to a difference in pressure between
the chambers 182, 184. The chamber 182 is exposed to hydrostatic pressure via an
opening 188 formed through the housing 174. The chamber 184 contains a gas, such
as air or nitrogen at atmospheric or another relatively low pressure. Thus, when the
valve 186 is opened, hydrostatic pressure in the chamber 182 displaces the housing
174 downward relative to the mandrel 176, with the fluid in the chamber 180 being
vented to the exterior of the actuator 172.
-
Referring additionally now to FIG. 13, another actuator190 embodying principles
of the present invention is representatively illustrated. The actuator 190 is similar in
many respects to the previously described actuator 172. However, the actuator 190
has additional chambers for increasing its force output, and includes a combined valve
and choke 196 for regulating the rate at which its housing 192 displaces relative to its
mandrel 194.
-
The valve and choke 196 may be a combination of a solenoid valve, such as
valves 168, 186 described above, and an orifice or other choke member, or it may be
a variable choke having the capability of preventing fluid flow therethrough or of
metering such fluid flow. If the valve and choke 196 includes a variable choke, the rate
at which fluid is metered therethrough may be adjusted by correspondingly adjusting
an electrical signal applied to lines 198 connected thereto.
-
Annular chambers 200, 202, 204, 206, 208 are formed between the housing 192
and the mandrel 194. The chambers 200, 202, 204, 206, 208 are isolated from each
other by circumferential seals 210. The chambers 202, 206 are exposed to hydrostatic
pressure via openings 212 formed through the housing 192. The chambers 200, 204
contain a gas, such as air or nitrogen at atmospheric or another relatively low pressure.
The use of multiple sets of chambers permits a larger force to be generated by the
actuator 190 in a given annular space.
-
A fluid, such as oil, is contained in the chamber 208. The valve/choke 196
regulates venting of the fluid from the chamber 208 to the exterior of the actuator 190.
When the valve/choke 196 is opened, the fluid in the chamber 208 is permitted to
escape therefrom, thereby permitting the housing 192 to displace relative to the
mandrel 194. A larger or smaller orifice may be selected to correspondingly increase
or decrease the rate at which the housing 192 displaces relative to the mandrel 194
when the fluid is vented from the chamber 208, or the electrical signal on the lines 198
may be adjusted to correspondingly vary the rate of fluid flow through the valve/choke
196 if it includes a variable choke.
-
Referring additionally now to FIG. 14, another actuator 214 embodying principles
of the present invention is representatively illustrated. The actuator 214 is similar in
many respects to the actuator 172 described above. However, the actuator 214 utilizes
an increased piston area associated with its annular gas chamber 216 in order to
increase the force output by the actuator.
-
The actuator 214 includes the chamber 216 and annular chambers 218, 220
formed between an outer generally tubular housing 222 and an inner generally tubular
mandrel 224. Circumferential seals 226 sealingly engage the mandrel 224 and the
housing 222. The chamber 216 contains gas, such as air or nitrogen, at atmospheric
or another relatively low pressure, the chamber 218 is exposed to hydrostatic pressure
via an opening 228 formed through the housing 222, and the chamber 220 contains a
fluid, such as oil.
-
A valve 230 selectively permits venting of the fluid in the chamber 220 to the
exterior of the actuator 214. The housing 222 is prevented by the fluid in the chamber
220 from displacing relative to the mandrel 224. When the valve 230 is opened, for
example, by applying an appropriate electrical signal to lines 231, the fluid in the
chamber 220 is vented, thereby permitting the housing 222 to displace relative to the
mandrel 224.
-
Note that each of the actuators 126, 172, 190, 214 has been described above
as if the housing and/or mandrel thereof is connected to the packer, valve, choke, tool,
item of equipment, flow control device, etc. which is desired to be actuated. However,
it is to be clearly understood that each of the actuators 126, 172, 190, 214 may be
otherwise connected or attached to the tool(s) or item(s) of equipment, without
departing from the principles of the present invention. For example, the output of each
of valves 168, 186, 196, 230 may be connected to any hydraulically actuated tool(s) or
item(s) of equipment for actuation thereof. In this manner, each of the actuators 126,
172, 190, 214 may serve as the actuator or fluid power source in the methods 50, 60,
70, 80,120.
-
Referring additionally now to FIG. 15, a container 232 embodying principles of
the present invention is representatively illustrated. The container 232 may be utilized
to store a gas at atmospheric or another relatively low pressure downhole. In an
embodiment described below, the container 232 is utilized in the actuation of one or
more tools or items of equipment downhole.
-
The container 232 includes a generally tubular inner housing 234 and a
generally tubular outer housing 236. An annular chamber 238 is formed between the
inner and outer housings 234, 236. In use, the annular chamber 238 contains a gas,
such as air or nitrogen, at atmospheric or another relatively low pressure.
-
It will be readily appreciated by one skilled in the art that, in a well, hydrostatic
pressure will tend to collapse the outer housing 236 and burst the inner housing 234,
due to the differential between the pressure in the annular chamber 238 and the
pressure external to the container 232 (within the inner housing 234 and outside the
outer housing 236). For this reason, the container 232 includes a series of
circumferentially spaced apart and longitudinally extending ribs or rods 240.
Preferably, the ribs 240 are spaced equidistant from each other, but that is not
necessary, as shown in FIG. 15.
-
The ribs 240 significantly increase the ability of the outer housing 236 to resist
collapse due to pressure applied externally thereto. The ribs 240 contact both the outer
housing 236 and the inner housing 234, so that radially inwardly directed displacement
of the outer housing 236 is resisted by the inner housing 234. Thus, the container 232
is well suited for use in high pressure downhole environments.
-
Referring additionally now to FIG. 16, an apparatus 242 embodying principles
of the present invention is representatively illustrated. The apparatus 242
demonstrates use of the container 232 along with a fluid power source 244, such as
any of the pumps and/or actuators described above which are capable of producing an
elevated fluid pressure, to control actuation of a tool 246.
-
The tool 246 is representatively illustrated as including a generally tubular outer
housing 248 sealingly engaged and reciprocably disposed relative to a generally
tubular inner mandrel 250. Annular chambers 252, 254 are formed between the
housing 248 and mandrel 250. Fluid pressure in the chamber 252 greater than fluid
pressure in the chamber 254 will displace the housing 248 to the left relative to the
mandrel 250 as viewed in FIG. 16, and fluid pressure in the chamber 254 greater than
fluid pressure in the chamber 252 will displace the housing 248 to the right relative to
the mandrel 250 as viewed in FIG. 16. Of course, either or both of the housing 248 and
mandrel 250 may displace in actual practice. It is to be clearly understood that the tool
246 is merely representative of tools, such as packers, valves, chokes, etc., which may
be operated by fluid pressure applied thereto.
-
When it is desired to displace the housing 248 and/or mandrel 250, one of the
chambers 252, 254 is vented to the container 232, and the other chamber is opened
to the fluid power source 244. For example, to displace the housing 248 to the right
relative to the mandrel 250 as viewed in FIG. 16, a valve 256 between the fluid power
source 244 and the chamber 254 is opened, and a valve 258 between the container
232 and the chamber 252 is opened. The resulting pressure differential between the
chambers 252, 254 causes the housing 248 to displace to the right relative to the
mandrel 250. To displace the housing 248 to the left relative to the mandrel 250 as
viewed in FIG. 16, a valve 260 between the fluid power source 244 and the chamber
252 is opened, and a valve 262 between the container 232 and the chamber 254 is
opened. The valves 260, 262 are closed when the housing 248 is displaced to the right
relative to the mandrel, and the valves 256, 258 are closed when the housing is
displaced to the left relative to the mandrel. The tool 246 may, thus, be repeatedly
actuated by alternately connecting each of the chambers 252, 254 to the fluid power
source 244 and the container 232.
-
The valves 256, 258, 260, 262 are representatively illustrated in FIG. 16 as
being separate electrically actuated valves, but it is to be understood that any type of
valves may be utilized without departing from the principles of the present invention.
For example, the valves 256, 258, 260, 262 may be replaced by two appropriately
configured conventional two-way valves, etc.
-
The tool 246 may be used to actuate another tool, without departing from the
principles of the present invention. For example, the mandrel 250 may be attached to
a packer mandrel, so that when the mandrel 250 is displaced in one direction relative
to the housing 248, the packer is set, and when the mandrel 250 is displaced in the
other direction relative to the housing 248, the packer is unset. For this purpose, the
housing 248 or mandrel 250 may be interconnected in a tubular string for conveyance
within a well.
-
Note that the fluid power source 244 may alternatively be another source of fluid
at a pressure greater than that of the gas or other fluid in the container 232, without the
pressure of the delivered fluid being elevated substantially above hydrostatic pressure
in the well. For example, element 244 shown in FIG. 16 may be a source of fluid at
hydrostatic pressure. The fluid source 244 may be the well annulus surrounding the
apparatus 242 when it is disposed in the well; it may be the interior of a tubular string
to which the apparatus is attached; it may originate in a chamber conveyed into the well
with, or separate from, the apparatus; if conveyed into the well in a chamber, the
chamber may be a collapsible or elastic bag, or the chamber may include an equalizing
piston separating clean fluid for delivery to the tool 246 from fluid in the well; the fluid
source may include fluid processing features, such as a fluid filter, etc. Thus, it will be
readily appreciated that it is not necessary for the fluid source 244 to deliver fluid to the
tool 246 at a pressure having any particular relationship to hydrostatic pressure in the
well, although the fluid source may deliver fluid at greater than, less than and/or equal
to hydrostatic pressure.
-
Referring additionally to FIG. 17, another apparatus 264 utilizing the container
232 and embodying principles of the present invention is representatively illustrated.
The apparatus 264 includes multiple tools 266, 268, 270 having generally tubular outer
housings 272, 274, 276 sealingly engaged with generally tubular inner mandrels 278,
280, 282, thereby forming annular chambers 284, 286, 288 therebetween, respectively.
The tools 266, 268, 270 are merely representative of the wide variety of packers,
valves, chokes, and other flow control devices, items of equipment and tools which may
be actuated using the apparatus 264. Alternatively, displacement of each of the
housings 272, 274, 276 relative to corresponding ones of the mandrels 278, 280, 282
may be utilized to actuate associated flow control devices, items of equipment and tools
attached thereto. For example, the apparatus 264 including the container 232 and the
tool 266 may be interconnected in a tubular string, with the tool 266 attached to a
packer mandrel, such that when the housing 272 is displaced relative to the mandrel
278, the packer is set.
-
Valves 290, 292, 294 initially isolate each of the chambers 284, 286, 288,
respectively, from communication with the chamber 238 of the container 232. Each of
the chambers 284, 286, 288 is initially substantially filled with a fluid, such as oil. Thus,
as the apparatus 264 is lowered within a well, hydrostatic pressure in the well acts to
pressurize the fluid in the chambers 284, 286, 288. However, the fluid prevents each
of the housings 272, 274, 276 from displacing substantially relative to its corresponding
mandrel 278, 280, 282.
-
To actuate one of the tools 266, 268, 270, its associated valve 290, 292, 294 is
opened, thereby permitting the fluid in the corresponding chamber 284, 286, 288 to flow
into the chamber 238 of the container 232. As described above, the chamber 238 is
substantially filled with a gas, such as air or nitrogen at atmospheric or another
relatively low pressure. Hydrostatic pressure in the well will displace the corresponding
housing 272, 274, 276 relative to the corresponding mandrel 278, 280, 282, forcing the
fluid in the corresponding chamber 284, 286, 288 to flow through the corresponding
valve 290, 292, 294 and into the container 232. Such displacement may be readily
stopped by closing the corresponding valve 290, 292, 294.
-
Operation of the valves 290, 292, 294 may be controlled by any of the methods
described above. For example, the valves 290, 292, 294 may be connected to an
electrical power source conveyed into the well on slickline, wireline or coiled tubing, a
receiver may be utilized to receive a remotely transmitted signal whereupon the valves
are connected to an electrical power source, such as a battery, downhole, etc.
However, it is to be clearly understood that other methods of operating the valves 290,
292, 294 may be utilized without departing from the principles of the present invention.
-
The valve 290 may be a solenoid valve. The valve 292 may be a fusible plug-type
valve (a valve openable by dissipation of a plug blocking fluid flow through a
passage therein), such as that available from BEI. The valve 294 may be a
valve/choke, such as the valve/choke 196 described above. Thus, it may be clearly
seen that any type of valve may be used for each of the valves 290, 292, 294.
-
Referring additionally now to FIG. 18, another apparatus 296 embodying
principles of the present invention is representatively illustrated. The apparatus 296
includes the receiver 72, battery 74 and pump 62 described above, combined in an
individual actuator or hydraulic power source 298 connected via a line 300 to a tool or
item of equipment 302, such as a packer, valve, choke, or other flow control device.
The line 300 may be internally or externally provided, and the actuator 298 may be
constructed with the tool 302, with no separation therebetween.
-
In FIG. 18, the apparatus 296 is depicted interconnected as a part of a tubular
string 304 installed in a well. To operate the tool 302, a signal is transmitted from a
remote location, such as the earth's surface or another location within the well, to the
receiver 72. In response, the pump 62 is supplied electrical power from the battery 74,
so that fluid at an elevated pressure is transmitted via the line 300 to the tool 302, for
example, to set or unset a hydraulic packer, open or close a valve, vary a choke flow
restriction, etc. Note that the representatively illustrated tool 302 is of the type which
is responsive to fluid pressure applied thereto.
-
Referring additionally now to FIG. 19, an apparatus 306 embodying principles
of the present invention is representatively illustrated. The apparatus 306 is similar in
many respects to the apparatus 296 described above, however, a tool 308 of the
apparatus 306 is of the type responsive to force applied thereto, such as a packer set
by applying an axial force to a mandrel thereof, or a valve opened or closed by
displacing a sleeve or other blocking member therein.
-
To operate the tool 308, a signal is transmitted from a remote location, such as
the earth's surface or another location within the well, to the receiver 72. In response,
the pump 62 is supplied electrical power from the battery 74, so that fluid at an elevated
pressure is transmitted via the line 300 to a hydraulic cylinder 310 interconnected
between the tool 308 and the actuator 298. The cylinder 310 includes a piston 312
therein which displaces in response to fluid pressure in the line 300. Such
displacement of the piston 312 operates the tool 308, for example, displacing a mandrel
of a packer, opening or closing a valve, varying a choke flow restriction, etc.
-
Thus have been described the methods 10, 50, 60, 70, 80, 90, 120, and
apparatus and actuators 126, 172, 190, 214, 242, 264, 296, 306, which permit
convenient and efficient control of fluid flow within a well, and operation of tools and
items of equipment within the well. Of course, many modifications, additions,
substitutions, deletions, and other changes may be made to the methods described
above and their associated apparatus, which changes would be obvious to one of
ordinary skill in the art, and these are contemplated by the principles of the present
invention. For example, any of the methods may be utilized to control fluid injection,
rather than production, within a well, each of the valves 168, 186, 196, 230, 256, 258,
260, 262, 290, 292, 294 may be other than a solenoid valve, such as a pilot-operated
valve, and any of the actuators, pumps, control modules, receivers, packers, valves,
etc. may be differently configured or interconnected, without departing from the
principles of the present invention.