U.S. patent application number 15/090963 was filed with the patent office on 2017-08-31 for degradable material time delay system and method.
This patent application is currently assigned to GEODynamics, Inc.. The applicant listed for this patent is GEODynamics, Inc.. Invention is credited to John T. Hardesty.
Application Number | 20170247996 15/090963 |
Document ID | / |
Family ID | 59679570 |
Filed Date | 2017-08-31 |
United States Patent
Application |
20170247996 |
Kind Code |
A1 |
Hardesty; John T. |
August 31, 2017 |
DEGRADABLE MATERIAL TIME DELAY SYSTEM AND METHOD
Abstract
A detonating restriction plug element and method in a wellbore
casing. The element includes a hollow passage in the restriction
plug element that receives a detonating assembly coupled to a
mechanical restraining element, and a space for containing a
reactive fluid. The mechanical restraining element undergoes a
change in shape for a pre-determined time delay due to a chemical
reaction when the reactive fluid in the space such as wellbore
fluids comes in contact with the restraining element. A firing pin
in the detonating assembly is released when the restraining
elements changes shape and releases the restraint on the firing
pin. The firing pin contacts a detonator in the detonating assembly
and causes a detonating event such that the restriction plug
element fragments.
Inventors: |
Hardesty; John T.;
(Weatherford, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
GEODynamics, Inc. |
Millsap |
TX |
US |
|
|
Assignee: |
GEODynamics, Inc.
Millsap
TX
|
Family ID: |
59679570 |
Appl. No.: |
15/090963 |
Filed: |
April 5, 2016 |
Related U.S. Patent Documents
|
|
|
|
|
|
Application
Number |
Filing Date |
Patent Number |
|
|
15053417 |
Feb 25, 2016 |
|
|
|
15090963 |
|
|
|
|
15053534 |
Feb 25, 2016 |
|
|
|
15053417 |
|
|
|
|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 41/00 20130101;
E21B 43/1185 20130101; E21B 34/063 20130101; E21B 33/1208 20130101;
E21B 33/13 20130101 |
International
Class: |
E21B 43/26 20060101
E21B043/26; E21B 43/14 20060101 E21B043/14; E21B 33/12 20060101
E21B033/12; E21B 43/116 20060101 E21B043/116; E21B 33/13 20060101
E21B033/13 |
Claims
1. A detonating restriction plug element for isolating stages in a
wellbore casing wherein said restriction plug element shaped as a
sphere and said restriction plug element configured to be pumped
into said wellbore casing without a wireline; said restriction plug
element configured with a hollow passage; said hollow passage
configured to receive a detonating assembly; said detonating
assembly comprising a detonating device coupled to a mechanical
restraining element; said mechanical restraining element configured
to react with a reactive fluid; said mechanical restraining element
configured to restrain a firing pin in said detonating device;
wherein, when said reactive fluid comes in contact with said
mechanical restraining element and initiates a chemical reaction;
said chemical reaction enables a physical property change in said
mechanical restraining element for a pre-determined time delay; and
said firing pin initiates a detonating event after elapse of said
pre-determined time delay.
2. The detonating restriction plug element of claim 1 wherein said
chemical reaction occurs at a pre-determined temperature expected
to be encountered in said wellbore casing.
3. The detonating restriction plug element of claim 2 wherein said
pre-determined temperature ranges from 25.degree. C.-250.degree.
C.
4. The detonating restriction plug element of claim 1 wherein said
reactive fluid is contained in a reservoir; said reservoir in
pressure communication with said mechanical restraining
element.
5. The detonating restriction plug element of claim 1 wherein said
reactive fluid is wellbore fluid expected in said wellbore
casing.
6. The detonating restriction plug element of claim 1 wherein said
reactive fluid is selected from a group comprising: fresh water,
salt water, KCL, NaCl, HCL, oil or hydrocarbon.
7. The detonating restriction plug element of claim 1 wherein said
detonating restriction plug element fragments after said detonating
event.
8. The detonating restriction plug element of claim 1 wherein said
detonating restriction plug element remains intact after said
detonating event and creates a flow channel.
9. The detonating restriction plug element of claim 1 wherein said
time delay is determined by a time greater than a fracturing time
of an isolated stage.
10. (canceled)
11. The detonating restriction plug element of claim 1 wherein said
time delay ranges from 1 hour to 48 hours.
12. The detonating restriction plug element of claim 1 wherein said
time delay ranges from 0.01 seconds to 1 hour.
13. The detonating restriction plug element of claim 1 wherein said
detonating restriction plug element further comprises a degradable
material.
14. The detonating restriction plug element of claim 1 wherein said
mechanical restraining element is a nut.
15. The detonating restriction plug element of claim 1 wherein said
mechanical restraining element is a tensile member.
16. The detonating restriction plug element of claim 1 wherein said
pre-determined time delay is determined by composition of said
reactive fluids.
17. The detonating restriction plug element of claim 1 wherein said
pre-determined time delay is determined by reaction rate of said
reactive fluids with said mechanical restraining element.
18. The detonating restriction plug element of claim 1 wherein said
pre-determined time delay is determined by reaction time of said
reactive fluids with said mechanical restraining element.
19. The detonating restriction plug element of claim 1 wherein said
pre-determined time delay is determined by masking a contact area
of said mechanical restraining element.
20. The detonating restriction plug element of claim 1 wherein said
pre-determined time delay is determined by masking a portion of
said mechanical restraining element in contact with said reactive
fluid.
21. The detonating restriction plug element of claim 1 wherein a
shape of said mechanical restraining element is selected from a
group comprising: square, circle, oval, and elongated.
22. The detonating restriction plug element of claim 1 wherein a
material of said mechanical restraining element is selected from a
group comprising: Magnesium, Aluminum, or Magnesium-Aluminum
alloy.
23. (canceled)
24. The detonating restriction plug element of claim 1 wherein said
detonating assembly further comprises a detonating cord coupled to
said detonating device.
25. The detonating restriction plug element of claim 1 wherein said
reactive fluid is pressure isolated from said mechanical
restraining element through a pressure actuating device.
26. The detonating restriction plug element of claim 25 wherein
said actuating device is a rupture disk; said rupture disk actuated
by pressure in said wellbore casing.
27. A detonating method, said method operating in conjunction with
a detonating restriction plug element for isolating stages in a
wellbore casing, wherein said restriction plug element shaped as a
sphere and configured to be pumped into said wellbore casing
without a wireline; said restriction plug element configured with a
hollow passage; said hollow passage configured to receive a
detonating assembly; said detonating assembly comprising a
detonating device coupled to a mechanical restraining element; said
mechanical restraining element configured to react with a reactive
fluid; said mechanical restraining element configured to restrain a
firing pin in said detonating device; wherein said method comprises
the steps of: (1) pumping said restriction plug element into said
wellbore casing and isolating a stage to block fluid communication;
(2) fracturing said stage; (3) initiating a chemical reaction
between said mechanical restraining element and said reactive
fluid; (4) progressing said chemical reaction for a pre-determined
time delay and changing a physical property of said mechanical
restraining element; (5) releasing said firing pin after elapse of
said time delay; and (6) initiating a detonating event.
28. The detonating method claim 27 wherein said detonating
restriction plug element fragments after said detonating event.
29. The detonating method claim 27 wherein said hollow passage
remains intact while said detonating restriction plug element
further degrades in said wellbore fluids.
30. The detonating method claim 27 wherein said initiating step [3]
is further delayed by a pressure actuating device.
Description
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application is a continuation-in-part of U.S.
application Ser. Nos. 15/053,417 and 15/053,534, both filed Feb.
25, 2016, the disclosures of which are fully incorporated herein by
reference.
FIELD OF THE INVENTION
[0002] The present invention generally relates to restriction plug
elements in a wellbore. Specifically, the invention attempts to
utilize a reactive fluid that reacts with a degradable mechanical
element for a known time delay and initiates a detonating event
inside a restriction plug element.
PRIOR ART AND BACKGROUND OF THE INVENTION
Prior Art Background
[0003] In oil and gas extraction applications, there is a need to
have a certain length of time delay between pressure triggered
events such that the system can be tested at a pressure before the
next event could proceed. This system cannot be controlled with any
other means besides the application of pressure. Prior art system
means of fluid restriction uses a complex system of microscopic
passages that meter fluid. Therefore, there is a need for
non-expensive simple and flexible component flow restriction
systems.
[0004] Inside a tandem in a gun string assembly, a transfer happens
between the detonating cords to detonate the next gun in the daisy
chained gun string. Detonation can be initiated from the wireline
used to deploy the gun string assembly either electrically, by
pressure activation or by electronic means. In tubing conveyed
perforating (TCP) as there is no electric conductor, pressure
activated percussion initiation is used to detonate. TCP is used to
pump up to a tubing pressure that reaches a certain pressure
enabling a firing head to launch a firing pin. Subsequently, the
firing pin starts the percussion initiator which starts the
detonation cord. There is a need to delay the launching of a firing
pin by a predetermined time in certain instances so that tests can
be conducted or a hang fire condition may be detected on a previous
gun.
[0005] In tandem systems there is a single detonating cord passing
through the guns. There are no pressure barriers. However, in
select fire systems (SFS) there is a pressure isolation switch
between each gun. Each gun is selectively fired though its own
detonation train. A detonator feeds off each switch. When the lower
most perforating gun is perforated, pressure enters the inside of
the gun. When the first gun is actuated, the second detonator gets
armed when the pressure in the first gun switch moves into the next
position actuating a firing pin to enable detonation in the next
gun. All guns downstream are isolated from the next gun by the
pressure barrier.
[0006] Spool valves are directional control valves that are used as
wellbore tools. They allow fluid flow into different paths from one
or more sources. They usually consist of a spool inside a cylinder
which is mechanically or electrically controlled. The movement of
the spool restricts or permits the flow, thus it controls the fluid
flow. There are two fundamental positions of directional control
valve namely normal position where valve returns on removal of
actuating force and other is working position which is position of
a valve when actuating force is applied. However, prior art spool
valves do not have a control mechanism with a pre-determined delay
to switch from normal position to a working position.
[0007] It is known that well fluids vary in the chemical nature and
are not always the same composition. However, the temperature of
the well is often defined or can be manipulated to achieve a
pre-determined temperature. Most time delay elements currently used
comprise complex mechanisms and are often expensive. Therefore,
there is a need for a time delay tool that can use a known fluid or
an unknown fluid inside a well at a known temperature such that a
known degradable element can react and degrade in the known fluid
at the known temperature for a known amount of time so that a
pre-determined time may be achieved to trigger a mechanism in a
device.
[0008] In many instances a single wellbore may traverse multiple
hydrocarbon formations that are otherwise isolated from one another
within the Earth. It is also frequently desired to treat such
hydrocarbon bearing formations with pressurized treatment fluids
prior to producing from those formations. In order to ensure that a
proper treatment is performed on a desired formation, that
formation is typically isolated during treatment from other
formations traversed by the wellbore. To achieve sequential
treatment of multiple formations, the casing adjacent to the toe of
a horizontal, vertical, or deviated wellbore is first perforated
while the other portions of the casing are left unperforated. The
perforated zone is then treated by pumping fluid under pressure
into that zone through perforations. Following treatment a plug is
placed adjacent to the perforated zone. The process is repeated
until all the zones are perforated. The plugs are particularly
useful in accomplishing operations such as isolating perforations
in one portion of a well from perforations in another portion or
for isolating the bottom of a well from a wellhead. The purpose of
the plug is to isolate some portion of the well from another
portion of the well.
[0009] Subsequently, production of hydrocarbons from these zones
requires that the sequentially set plugs be removed from the well.
In order to reestablish flow past the existing plugs an operator
must remove and/or destroy the plugs by milling, drilling, or
dissolving the plugs.
[0010] Additionally, frac plugs can be inadvertently set at
undesired locations in the wellbore casing creating unwanted
constrictions. The constrictions may latch wellbore tools that are
run for future operations and cause unwanted removal process.
Therefore, there is a need to prevent premature set conditions
caused by conventional frac plugs.
[0011] The steps comprised of setting up a plug, isolating a
hydraulic fracturing zone, perforating the hydraulic fracturing
zone and pumping hydraulic fracturing fluids into the perforations
are repeated until all hydraulic fracturing zones in the wellbore
casing are processed. When all hydraulic fracturing zones are
processed, the plugs are milled out with a milling tool and the
resulting debris is pumped out or removed from the wellbore casing.
Hydrocarbons are produced by pumping out from the hydraulic
fracturing stages.
[0012] The milling step requires that removal/milling equipment be
run into the well on a conveyance string which may typically be
wire line, coiled tubing or jointed pipe. The process of
perforating and plug setting steps represent a separate "trip" into
and out of the wellbore with the required equipment. Each trip is
time consuming and expensive. In addition, the process of drilling
and milling the plugs creates debris that needs to be removed in
another operation. Therefore, there is a need for isolating
multiple hydraulic fracturing zones without the need for a milling
operation. Furthermore, there is a need for positioning restrictive
plug elements that could be removed in a feasible, economic, and
timely manner before producing gas.
Deficiencies in the Prior Art
[0013] The prior art as detailed above suffers from the following
deficiencies: [0014] Prior art systems do not provide for a known
degradable element that can react and degrade in a known fluid at a
known temperature for a known amount of time so that a
pre-determined time may be achieved to trigger a mechanism in a
device. [0015] Prior art systems do not provide for a low cost
configurable time delay flow restriction element that is commonly
available. [0016] Prior art systems do not provide for a
predictable time delay. [0017] Prior art systems do not provide for
a cost effective time delay solution that are independent of the
wellbore fluids. [0018] Prior art systems require bulky and
expensive hydraulics. [0019] Prior art systems require expensive
electronics that have difficulty functioning at downhole
temperatures. [0020] Prior art systems do not provide for isolating
multiple hydraulic fracturing zones without the need for a milling
operation. [0021] Prior art systems do not provide for positioning
restrictive elements that could be removed in a feasible, economic,
and timely manner. [0022] Prior art systems cause undesired
premature preset conditions preventing further wellbore
operations.
[0023] While some of the prior art may teach some solutions to
several of these problems, the core issue of a predictable time
delay with known fluids at pre-determined temperatures has not been
addressed by prior art.
BRIEF SUMMARY OF THE INVENTION
System Overview
[0024] The present invention in various embodiments addresses one
or more of the above objectives in the following manner. A
detonating restriction plug element wellbore casing includes a
hollow passage in the restriction plug element that receives a
detonating assembly coupled to a mechanical restraining element,
and a space for containing a reactive fluid. The mechanical
restraining element undergoes a change in shape for a
pre-determined time delay due to a chemical reaction when the
reactive fluid in the space such as wellbore fluids comes in
contact with the restraining element. A firing pin in the
detonating assembly is released when the restraining elements
changes shape and releases the restraint on the firing pin. The
firing pin contacts a detonator in the detonating assembly and
causes a detonating event such that the restriction plug element
fragments. The amount of the pre-determined time delay is
determined by factors that include the reactive fluids,
concentration of the reactive fluids, geometry and size of the
mechanical restraining element.
Method Overview
[0025] The present invention system may be utilized in the context
of an overall detonating method, wherein the detonating restriction
plug element as previously described is controlled by a method
having the following steps: [0026] (1) deploying the restriction
plug element into the wellbore casing and isolating a stage to
block fluid communication; [0027] (2) fracturing the stage; [0028]
(3) initiating a chemical reaction between the mechanical
restraining element and the reactive fluid; [0029] (4) progressing
the chemical reaction for a pre-determined time delay and changing
a physical property of the mechanical restraining element; [0030]
(5) releasing the firing pin after elapse of the time delay; and
[0031] (6) initiating a detonating event.
[0032] Integration of this and other preferred exemplary embodiment
methods in conjunction with a variety of preferred exemplary
embodiment systems described herein in anticipation by the overall
scope of the present invention.
BRIEF DESCRIPTION OF THE DRAWINGS
[0033] For a fuller understanding of the advantages provided by the
invention, reference should be made to the following detailed
description together with the accompanying drawings wherein:
[0034] FIG. 1 illustrates a cross-section overview diagram of
downhole wellbore time delay tool according to an exemplary
embodiment of the present invention.
[0035] FIG. 2 illustrates a cross-section overview diagram of
downhole wellbore time delay tool with an energetic device and a
firing pin according to an exemplary embodiment of the present
invention.
[0036] FIG. 3A-3D illustrates a cross-section view of downhole
wellbore time delay tool with an energetic device and a firing pin
describing an initial set up, actuation position, a degradation
position, and a triggering position according to an exemplary
embodiment of the present invention.
[0037] FIG. 3E-3H illustrates a cross-section view of downhole
wellbore time delay tool with an energetic device and a firing pin
with a shear pin restraint describing an initial set up, actuation
position, a degradation position, and a triggering position
according to an exemplary embodiment of the present invention.
[0038] FIG. 4A illustrates a perspective view of a downhole
wellbore time delay tool with an energetic device and a firing pin
according to an exemplary embodiment of the present invention.
[0039] FIG. 4B illustrates a perspective view of a downhole
wellbore time delay tool with an energetic device and a firing pin
with a shear pin restraint according to an exemplary embodiment of
the present invention.
[0040] FIG. 5A-5D illustrates a cross-section view of downhole
wellbore time delay tool with an energetic device and a firing pin
and a spring loaded device describing an initial set up, actuation
position, a degradation position, and a triggering positions
according to an exemplary embodiment of the present invention.
[0041] FIG. 6 illustrates a perspective view of a downhole wellbore
time delay tool with an energetic device and a firing pin and a
spring loaded device according to an exemplary embodiment of the
present invention.
[0042] FIG. 7A-7D illustrates a cross-section view of downhole
wellbore time delay tool with a spool valve describing an initial
set up, actuation position, a degradation position, and a
triggering positions according to an exemplary embodiment of the
present invention.
[0043] FIG. 7E-7F illustrates a cross-section view of downhole
wellbore time delay tool with a spool valve and a tensile member
according to an exemplary embodiment of the present invention.
[0044] FIG. 8 illustrates a perspective view of a downhole wellbore
time delay tool with a spool valve according to an exemplary
embodiment of the present invention.
[0045] FIG. 9A-9D illustrates a cross-section view of downhole
wellbore time delay tool with a firing pin and a switch describing
an initial set up, actuation position, a degradation position, and
a triggering position according to an exemplary embodiment of the
present invention.
[0046] FIG. 10 illustrates a perspective view of a downhole
wellbore time delay tool with a firing pin and a switch according
to an exemplary embodiment of the present invention.
[0047] FIG. 11 illustrates a cross section view of a downhole
wellbore time delay tool with a dissolvable plug according to an
exemplary embodiment of the present invention.
[0048] FIG. 12 illustrates an exemplary flow chart for a time delay
method operating in conjunction with a downhole wellbore time delay
tool according to an embodiment of the present invention.
[0049] FIG. 13 illustrates a preferred exemplary flowchart
embodiment of a time delay firing method in conjunction with a
downhole wellbore time delay tool that is integrated into an
energetic device used in TCP operation according to an embodiment
of the present invention.
[0050] FIG. 14 illustrates an exemplary Time vs Temperature curve
for calculating a time delay based on a known fluid and known
restraining element according to an embodiment of the present
invention.
[0051] FIG. 15 illustrates an exemplary predictable time delay
flowchart operating in conjunction with a predictable downhole time
delay tool according to an embodiment of the present invention.
[0052] FIG. 16A illustrates a cross section view of a detonating
restriction plug element with a detonating assembly according to an
exemplary embodiment of the present invention.
[0053] FIG. 16B illustrates another cross section view of a
detonating restriction plug element with a detonating assembly
according to an exemplary embodiment of the present invention.
[0054] FIG. 16C illustrates a cross section view of a detonating
restriction plug element with a detonating assembly without a
reservoir and a pressure actuating device according to an exemplary
embodiment of the present invention.
[0055] FIG. 17 illustrates a flowchart embodiment of a detonating
method operating in conjunction with a detonating restriction plug
element according to an exemplary embodiment of the present
invention.
OBJECTIVES OF THE INVENTION
[0056] Accordingly, the objectives of the present invention are
(among others) to circumvent the deficiencies in the prior art and
affect the following objectives: [0057] Provide for a known
degradable element that can react and degrade in a known fluid at a
known temperature for a known amount of time so that a
pre-determined time may be achieved to trigger a mechanism in a
device. [0058] Provide for a low cost configurable time delay flow
restriction element that is commonly available. [0059] Provide for
a predictable time delay. [0060] Provide for a cost effective time
delay solution that is independent of the wellbore fluids. [0061]
Provide for a tubing conveyed perforating gun with a delay
mechanism which provides a known delay interval between pressuring
the tubing to a second predetermined level and the actual firing of
the perforating gun. [0062] Provide for a delay means to move a
firing pin holder out of locking engagement with a firing pin, to
release firing pin, after a predetermined time interval. [0063]
Provide for portable and inexpensive hydraulics for a time delay
tool. [0064] Provide for an inexpensive time delay tool that
functions reliably at downhole temperatures. [0065] Provide for a
time delay tool suitable for wireline conveyed, coil tubing
conveyed, casing conveyed or pump down. [0066] Provide for
isolating multiple hydraulic fracturing zones without the need for
a milling operation. [0067] Provide for positioning restrictive
elements that could be removed in a feasible, economic, and timely
manner. [0068] Provide for tools that prevent undesired premature
preset conditions that hinder further wellbore operations.
[0069] While these objectives should not be understood to limit the
teachings of the present invention, in general these objectives are
achieved in part or in whole by the disclosed invention that is
discussed in the following sections. One skilled in the art will no
doubt be able to select aspects of the present invention as
disclosed to affect any combination of the objectives described
above.
DESCRIPTION OF THE PRESENTLY PREFERRED EXEMPLARY EMBODIMENTS
[0070] While this invention is susceptible of embodiment in many
different forms, there is shown in the drawings and will herein be
described in detailed preferred embodiment of the invention with
the understanding that the present disclosure is to be considered
as an exemplification of the principles of the invention and is not
intended to limit the broad aspect of the invention to the
embodiment illustrated.
[0071] The numerous innovative teachings of the present application
will be described with particular reference to the presently
preferred embodiment, wherein these innovative teachings are
advantageously applied to the particular problems of a hydraulic
time delay system and method. However, it should be understood that
this embodiment is only one example of the many advantageous uses
of the innovative teachings herein. In general, statements made in
the specification of the present application do not necessarily
limit any of the various claimed inventions. Moreover, some
statements may apply to some inventive features but not to
others.
Preferred Exemplary Downhole Wellbore Time Delay Tool Integrated
into an Energetic Device (0200-0600)
[0072] As generally illustrated in FIG. 1 and FIG. 2 (0200), a
downhole wellbore time delay tool (0210) for use in a wellbore
casing comprises a reservoir (0211) for containing a reactive fluid
(0201), an actuating device (0202) such as a rupture disk, a
mechanical restraining element (0203) such as a nut and
mechanically connected to a wellbore device such as an energetic
device (0220) with firing pin (0204), a percussion initiator
(0205), a booster (0206) and a detonating cord (0207). A detailed
view of the wellbore tool (0210) is illustrated in FIG. 1. The
entire tool (0200) may be piped into the casing string as an
integral part of the string and positioned where functioning of the
tool is desired or the tool may be deployed to the desired location
with TCP, CT or a wire line. The wellbore may be cemented or not.
The fluid in the reservoir (0211) is held at an initial position by
the actuating device (0202), such as a rupture disk. The tool
mandrel is machined to accept the actuating device (0202) (such as
rupture discs) that ultimately controls the flow of reactive fluid
(0201). The fluid reservoir (0211) may be further installed in
within a fluid holding body (0208). The fluid holding body (0208)
may be operatively connected to a body (0209) of the energetic
device (0220). In one embodiment, the rated pressure of the
actuating device may range from 500 PSI to 15000 PSI.
[0073] The reservoir (0211) may be in fluid communication with the
mechanical restraining element via the actuation device (0202).
Alternatively, the reactive fluid may be directly in fluid
communication with the mechanical restraining element via the
actuation device (0202) without a reservoir. For example, the
mechanical restraining element may not be in fluid communication
initially with any fluid. When the pressure in the wellbore casing
increases to actuate the actuating device, wellbore fluids may
enter and react with the mechanical restraining element. It should
be noted that the reservoir to contain a reactive fluid may not be
construed as a limitation. A pressure port (0213) may be attached
to another end of the reservoir through another actuating device
(0212). The reservoir (0211) may be a holding tank that may be
positioned inside a fluid holding body (0208) of a well casing. The
volume of the reservoir may range from 25 ml to 5 liters. The
material of the reservoir may be chosen so that the reactive fluid
inside the reservoir does not react with the material of the
reservoir and therefore does not corrode or erode the reservoir
(0211). According to a preferred exemplary embodiment, the material
of the reservoir may be selected from a group comprising: metal,
ceramic, plastic, degradable, long term degradable, glass,
composite or combinations thereof. The reservoir may also be
pressurized so that there is sufficient flow of the reactive fluid
towards the restraining element. The actuation device (0202) may be
a reverse acting rupture disk that blocks fluids communication
between the reactive fluid and the restraining element. The
actuation device (0212) ruptures or actuates when a pressure in the
wellbore through the pressure port (0213) exceeds a rated pressure
of the actuating device (0212). After the actuating device (0212)
rupture, the pressure acting through the pressure port (0213) may
act on the fluid which further acts on the actuating device (0202).
When the pressure of the fluid acting on the actuation device
(0202) exceeds a rated pressure of the actuating device (0202), the
reactive fluid (0201) flows through and enters a chamber and comes
in contact with the restraining element (0203). According to
another preferred exemplary embodiment the actuating device is an
electronic switch that is actuated by a signal from a device
storing a stored energy.
[0074] The pressure on the actuation device (0202) may be ramped up
to the rated pressure with pressure from the reactive fluid. The
reactive fluid (0201) is configured to react with the mechanical
restraining element (0203) at a temperature expected to be
encountered in the wellbore. According to a preferred exemplary
embodiment a physical property change in the restraining element
may occur at a pre-determined temperature expected to be
encountered in the wellbore casing. According to a further
preferred exemplary embodiment the pre-determined temperature
ranges from 25.degree. C.-250.degree. C. The mechanical restraining
element (0203) may be a nut, a shear pin, or a holding device that
degrades as the reaction takes place. Upon further degradation, the
mechanical restraining element (0203) may release a restraint on
the energetic device (0220) and enable the entire pressure or
stored energy to act on an end of the energetic device (0220).
[0075] According to a preferred exemplary embodiment the reactive
fluid is selected from a group comprising: fresh water, salt water,
KCL, NaCl, HCL, or hydrocarbons.
[0076] The energetic device (0220) may be operatively connected to
the mechanical restraining element via threads, seals or a
connecting element. The tool mandrel may be machined to accept the
wellbore reservoir, the actuating device and the wellbore device
such as a firing pin assembly. In some instances, the mechanical
restraining element may be a nut that may be screwed or attached to
a counterpart in the wellbore device. In other instances the
restraining element may be a tensile member. The wellbore device
may be an energetic device (0220) with a firing pin (0204) as
illustrated in FIG. 2 (0200).
[0077] According to a preferred exemplary embodiment, when a stored
energy, such as a pressure from a fluid, is applied on the firing
pin assembly, the actuating device (0202) is actuated and the
reactive fluid (0201) from the reservoir (0211) comes into contact
with the mechanical restraining element (0203) and enables a
physical property change in the mechanical restraining element such
that the stored energy applied on the wellbore device is delayed by
a pre-determined time delay while the mechanical restraining
element undergoes the physical property change. The physical
property change may enable the restraining element to change shape
for a pre-determined period of time. The physical property may be
strength, ductility or elasticity. In tubing conveyed perforating
gun with a delay mechanism, a known delay interval between
pressuring the tubing to a second pre-determined level and the
actual firing of the perforating gun may be achieved by the
pre-determined time delay. In a select fire system, a delay means,
to move a firing pin holder out of locking engagement with a firing
pin to release the firing pin, may be achieved by the predetermined
time interval 5. The firing pin (0204) may contact a percussion
detonator/initiator (0205) that connects to a bidirectional booster
(0206). The bidirectional booster (0206) may accept a detonation
input from the detonator. The detonating cord (0207) may be
initiated in turn by the booster (0206). When the firing pin is
actuated after the mechanical restraint (0203) is released, the
firing pin (0204) may contact a percussion detonator (0205) and in
turn initiate a detonator through a booster (0206) and a detonating
cord (0207).
[0078] According to a preferred exemplary embodiment, the stored
energy is applied from a spring. According to another preferred
exemplary embodiment, the stored energy is applied from a pressure
from a fluid and a seal. According to a further preferred exemplary
embodiment, the stored energy is applied from a magnetic field.
According to yet another preferred exemplary embodiment, the stored
energy is applied from a weight.
[0079] According to a preferred exemplary embodiment, the
pre-determined time delay ranges from 1 hour to 48 hours. According
to a more preferred exemplary embodiment, the pre-determined time
delay ranges from 2 days to 14 days. According to a most preferred
exemplary embodiment, the pre-determined time delay ranges from
0.01 seconds to 1 hour.
[0080] According to a preferred exemplary embodiment, the chemical
reaction may be an exothermic reaction that gives off heat. The
energy needed to initiate the chemical reaction may be less than
the energy that is subsequently released by the chemical reaction.
According to another preferred exemplary embodiment, the chemical
reaction may be an endothermic reaction that absorbs heat. The
energy needed to initiate the chemical reaction may be greater than
the energy that is subsequently released by the chemical
reaction.
[0081] The rate of the chemical reaction may be accelerated or
retarded based on factors such as nature of the reactants, particle
size of the reactants, concentration of the reactants, pressure of
the reactants, temperature and catalysts. According to a preferred
exemplary embodiment, a catalyst may be added to alter the rate of
the reaction. According to a preferred exemplary embodiment, the
material of the restraining element may be selected from a group
comprising: mixture of aluminum, copper sulfate, potassium
chlorate, and calcium sulfate, iron, magnesium, steel, plastic,
degradable, magnesium-iron alloy, particulate oxide of an alkali or
alkaline earth metal and a solid, particulate acid or strongly acid
salt, or mixtures thereof. The catalyst may be selected from a
group comprising salts. According to a preferred exemplary
embodiment, the material of the restraining element may be selected
from a group comprising: metal, non-metal or alloy.
[0082] According to a preferred exemplary embodiment the mechanical
restraining element is a restrictive plug element. For example, the
restriction plug element may be a ball or a plug that is used to
isolate pressure communication between zones or stages in a well
casing.
[0083] According to a preferred exemplary embodiment the
pre-determined time delay is determined by concentration of the
reactive fluids. According to another preferred exemplary
embodiment the pre-determined time delay is determined by reaction
rate of the reactive fluids with the mechanical restraining
element. According to yet another preferred exemplary embodiment
the pre-determined time delay is determined by reaction time of the
reactive fluids with the mechanical restraining element. According
to a further preferred exemplary embodiment the pre-determined time
delay is determined by masking a contact area of the mechanical
restraining element. According to a further preferred exemplary
embodiment the pre-determined time delay is determined by masking a
total area of the mechanical restraining element in contact with
the mechanical restraining element.
[0084] According to a preferred exemplary embodiment the shape of
the mechanical restraining element is selected from a group
comprising: square, circle, oval, and elongated.
[0085] A sealed cap may seal the exposed end of the reservoir to
physically protect the reservoir from undesired wellbore
conditions.
[0086] According to an alternate preferred embodiment, a multi
stage restraining element comprising a blocking member and a
restraining member may further increase a time delay. For example,
mechanical restraining element (0203) may be coupled with a
blocking member that may have a different composition and reaction
time with the fluid in the reservoir. The blocking member may react
with the fluid for a period of time and may restrict fluid access
to the mechanical restraining element for a pre-determined period
of time. It should be noted that the multi stage restraining
element may not limited to a blocking member and a restraining
element. Any number of blocking members and restraining elements
may be used in combination to achieve a desired time delay. The
reaction times and therefore the time delays of each of the bonding
members with the fluid may be characterized at various temperatures
expected in the wellbore.
[0087] In another preferred exemplary embodiment, the reservoir may
be filled with wellbore fluids. For example, the reservoir may be
empty when deployed into the wellbore and later filled with
wellbore fluids. A time vs temperature chart for the restraining
element may be characterized with different compositions of
wellbore fluids expected in the wellbore at temperatures expected
in the wellbore casing. Alternatively, the fluid reservoir may be
partially filled with the known fluid and wellbore fluids may fill
the remaining portion of the reservoir. The reservoir may be filled
with the known fluid, wellbore fluids or a combination thereof. The
mechanical restraining element may comprise one or more material
types that react and have different degradation rates in one or
more fluid types. The desired time delay may be achieved with a
combination of fluid types and restraining element material
types.
[0088] The present exemplary embodiment is generally illustrated in
more detail in FIG. 3A (0300), FIG. 3B (0310), FIG. 3C (0320), FIG.
3D (0330), wherein the downhole wellbore delay tool is deployed
inside a wellbore casing. FIG. 3A-3D generally illustrates
different positions of a firing pin assembly (0304). The positions
include an initial set up position (0300), an actuation position
(0310), a degradation position (0320) and a triggering position
(0330). The entire tool may be piped into the casing string as an
integral part of the string and positioned where functioning of the
tool is desired. In one exemplary embodiment, the tool may be a
firing pin assembly that is positioned where detonation,
perforation of a formation and fluid injection into a formation is
desired. The tool may be installed in either direction with no
change in its function. A detailed view of the tool in the initial
set up position is shown in FIG. 3 (0300) where in the fluid in the
reservoir is held by the actuating device (0302). When ready to
operate, the pressure is increased for example with TCP. The tool
then moves to the actuation position (0310), when pressure acting
on the actuating device (0302) exceeds its rated pressure, the
actuation device ruptures and enables reactive fluid in the fluid
reservoir (0301) to enter the adjacent chamber and contacts the
restraining element. Subsequently, after elapse of a pre-determined
time delay, the restraining element degrades or changes shape due
to the chemical reaction as illustrated in the degradation position
in FIG. 3C (0320). In the triggering position (0330), the firing
pin (0304) in the energetic device is triggered as the restraining
element (0303) no longer holds or restrains the firing pin (0304)
due to change of shape or strength. The entire stored energy may be
applied to move the firing pin and contact a bidirectional booster,
after the pre-determined time delay in the degradation position.
The stored energy may be applied by pressure and seal, magnetic
field, a weight, a spring or combination thereof.
[0089] FIG. 4A (0400) generally illustrates a perspective view of
the downhole delay tool with a firing pin as the wellbore
device.
[0090] Similar to FIGS. 3A-3D, a downhole delay tool with a firing
pin and a shear pin restraint is generally illustrated in FIGS.
3E-3H. As generally illustrated in more detail in FIG. 3E (0350),
FIG. 3F (0360), FIG. 3G (0370), FIG. 3H (0380), wherein the
downhole wellbore delay tool is deployed inside a wellbore casing.
FIG. 3E-3H generally illustrates different positions of a firing
pin assembly (0324) restrained by a shear pin (0325) in addition to
a mechanical restraining element (0323). The positions include an
initial set up position (0350), an actuation position (0360), a
degradation position (0370) and a triggering position (0380). A
detailed view of the tool in the initial set up position is shown
in FIG. 3E (0350) wherein the fluid in the reservoir is held by the
actuating device (0322). When ready to operate, the pressure is
increased for example with TCP. The tool then moves to the
actuation position (0360), when pressure acting on the actuating
device (0322) exceeds its rated pressure, the actuation device
ruptures and enables reactive fluid in the fluid reservoir (0321)
or well fluids from the wellbore casing to enter the adjacent
chamber and contacts the restraining element. Subsequently, after
elapse of a pre-determined time delay, the restraining element
degrades or changes shape due to the chemical reaction as
illustrated in the degradation position in FIG. 3G (0370). In the
triggering position (0380), the firing pin (0324) in the energetic
device is triggered as the restraining element (0323) no longer
holds or restrains the firing pin (0324) and the shear pin (0325)
due to change of shape or a physical property. According to a
preferred exemplary embodiment, the shear pins provide additional
control, when the time delay enables, but it would need an active
input to finally fire. FIG. 4B (0410) generally illustrates a
perspective view of the downhole delay tool with an energetic
device and a firing pin and a shear pin restraint mechanism as the
wellbore device. The mechanical restraining element (0323) could be
degraded, releasing the shear pin (0325), and then the tool would
have to be pumped to a pressure sufficient to shear the shear pins
(0325), which would allow the firing pin (0324) to strike a
percussion initiator (not shown).
[0091] Similar to FIGS. 3A-3D, a downhole delay tool with a firing
pin and a spring is generally illustrated in FIGS. 5A-5D. As
generally illustrated in more detail in FIG. 5A (0500), FIG. 5B
(0510), FIG. 5C (0520), FIG. 5D (0530), wherein the downhole
wellbore delay tool is deployed inside a wellbore casing. FIG.
5A-5D generally illustrates different positions of a firing pin
assembly (0504) restrained by a spring (0505). The positions
include an initial set up position (0500), an actuation position
(0510), a degradation position (0520) and a triggering position
(0530). A detailed view of the tool in the initial set up position
is shown in FIG. 5A (0500) wherein the fluid in the reservoir is
held by the actuating device (0502). When ready to operate, the
pressure is increased for example with TCP. The tool then moves to
the actuation position (0510), when pressure acting on the
actuating device (0502) exceeds its rated pressure, the actuation
device ruptures and enables reactive fluid in the fluid reservoir
(0501) to enter the adjacent chamber and contacts the restraining
element. Subsequently, after elapse of a pre-determined time delay,
the restraining element degrades or changes shape due to the
chemical reaction as illustrated in the degradation position in
FIG. 5C (0520). In the triggering position (0530), the firing pin
(0504) in the energetic device is triggered as the restraining
element (0503) no longer holds or restrains the firing pin (0504)
and the spring (0505) due to change of shape or a physical
property. FIG. 6 (0600) generally illustrates a perspective view of
the downhole delay tool with an energetic device and a firing pin
and a spring loading mechanism as the wellbore device.
Preferred Exemplary Downhole Wellbore Time Delay Tool Integrated
with a Spool Valve (0700-0800)
[0092] Similar to FIGS. 3A-3D, a downhole delay tool with a spool
valve is generally illustrated in FIGS. 7A-7D. A detailed view of
the tool in the initial set up position is shown in FIG. 7A (0700)
wherein the fluid in the reservoir is held by the actuating device
(0702) and a sleeve (0704) may block ports (0705, 0706) and disable
pressure or fluid communication to a hydrocarbon formation. When
ready to operate, the pressure is increased for example with TCP.
The tool then moves to the actuation position (0710), when pressure
acting on the actuating device (0702) exceeds its rated pressure,
the actuation device ruptures and enables reactive fluid in the
fluid reservoir (0701 to enter the adjacent chamber and contacts
the restraining element (0703). Subsequently, after elapse of a
pre-determined time delay, the restraining element degrades or
changes shape due to the chemical reaction as illustrated in the
degradation position in FIG. 7C (0720). In the triggering position
(0730), a movement in a sleeve (0704) in the spool valve is
triggered as the restraining element (0703) no longer holds or
restrains the sleeve (0704) due to change of shape. After being
released from the restraining element, the sleeve (0704) may slide
and unblock one or more ports (0705, 0706) and enable pressure or
fluid communication to a hydrocarbon formation. Similar to the
mechanical restraining element (0703) in FIG. 7A (0700), a tensile
member (0713) is generally illustrated in FIG. 7E (0740). The
tensile member (0713) may react with a reactive fluid from a
reservoir (0711) and provide a time delay for the tensile member
(0713) to break and enable a sleeve in the spool valve to slide and
open ports (0714, 0715). FIG. 7F (0750) generally illustrates a
sleeve position after the ports (0714, 0715) are opened to the
hydrocarbon formation. FIG. 8 (0800) generally illustrates a
perspective view of the downhole delay tool with a spool valve and
a sliding sleeve as a wellbore device.
Preferred Exemplary Downhole Wellbore Time Delay Tool Integrated
with a Pin and a Switch (0900-1000)
[0093] Similar to FIGS. 3A-3D, a downhole delay tool with a pin and
a switch is generally illustrated in FIGS. 9A-9D. As generally
illustrated in more detail in FIG. 9A (0900), FIG. 9B (0910), FIG.
9C (0920), FIG. 9D (0930), wherein the downhole wellbore delay tool
is deployed inside a wellbore casing. FIG. 9A-9D generally
illustrate different positions of a firing pin assembly (0904) and
a switch (0906) with a contact (0905). The positions include an
initial set up position (0900), an actuation position (0910), a
degradation position (0920) and a triggering position (0930). A
detailed view of the tool in the initial set up position is shown
in FIG. 9A (0900) where in the fluid in the reservoir is held by
the actuating device (0902). In the initial set up position (0900),
the electrical contact may not be connected to the pin (0904). When
ready to operate, the pressure is increased for example with TCP.
The tool then moves to the actuation position (0910), when pressure
acting on the actuating device (0902) exceeds its rated pressure,
the actuation device ruptures and enables reactive fluid in the
fluid reservoir (0901) to enter the adjacent chamber and contacts
the restraining element (0903). Subsequently, after elapse of a
pre-determined time delay, the restraining element degrades or
changes shape due to the chemical reaction as illustrated in the
degradation position in FIG. 9C (0920). In the triggering position
(0930), the pin (0904) in the wellbore device is triggered as the
restraining element (0903) no longer holds or restrains the pin
(0904) due to change of shape or a physical property. The movement
of the pin enables the pin to complete an electrical connection
that may be used to trigger an electrical event for purposes of
perforating or determining a status. FIG. 10 (1000) generally
illustrates a perspective view of the downhole delay tool with a
pin and a switch as the wellbore device.
Preferred Exemplary Downhole Wellbore Time Delay Tool Integrated
with a Degradable Restriction Element (1100)
[0094] FIG. 11 (1100) generally illustrates a degradable
restriction element (1103) blocking a flow channel (1104) in a
wellbore casing. A known reactive fluid may be provided to react
with the degradable restriction element (1103). After an elapse of
a predictable time period, the degradable restriction element
(1103) may degrade or change physical shape to enable fluid
communication through the channel (1104).
Preferred Exemplary Flowchart Embodiment of a Time Delay Method
(1200)
[0095] As generally seen in the flow chart of FIG. 12 (1200), a
preferred exemplary flowchart embodiment of a time delay method may
be generally described in terms of the following steps: [0096] (1)
positioning a wellbore tool at a desired wellbore location (1201);
[0097] The entire tool may be piped into the casing string as an
integral part of the string and positioned where functioning of the
tool is desired or the tool may be deployed to the desired location
using TCP, Coiled tubing (CT) or a wire line. The wellbore may be
cemented or not. The wellbore tool and the wellbore device may be
deployed separately or together. [0098] (2) applying stored energy
on the wellbore device (1202); [0099] The stored energy may be
applied by pressure and seal, magnetic field, a weight, a spring or
combination thereof. The energy may be transferred via TCP or
wireline. The stored energy may be directly applied via the
restraining element. The stored energy may be applied indirectly
via an actuating device and pressure. [0100] (3) actuating the
actuating device and enabling contact between the mechanical
restraining element and the reactive fluid (1203); [0101] If the
differential pressure acting on the piston is greater than a rated
pressure of a pressure activated opening device, the device
ruptures and allows the piston to move. The rating of the pressure
activated device could range from 5000 PSI to 15000 PSI. [0102] (4)
initiating a chemical reaction between the mechanical restraining
element and the reactive fluid (1204); [0103] According to a
preferred exemplary embodiment the pre-determined time delay is
determined by composition of the reactive fluids. According to
another preferred exemplary embodiment the pre-determined time
delay is determined by reaction rate of the reactive fluids with
the mechanical restraining element. According to yet another
preferred exemplary embodiment the pre-determined time delay is
determined by reaction time of the reactive fluids with the
mechanical restraining element. According to a further preferred
exemplary embodiment the pre-determined time delay is determined by
masking a contact area of the mechanical restraining element.
[0104] (5) progressing the chemical reaction for a pre-determined
time delay and altering size of the mechanical restraining element
(1205); [0105] According to a preferred exemplary embodiment, the
pre-determined time delay ranges from 1 hour to 48 hours. According
to a more preferred exemplary embodiment, the pre-determined time
delay ranges from 2 days to 14 days. According to a most preferred
exemplary embodiment, the pre-determined time delay ranges from
0.01 seconds to 1 hour. [0106] (6) releasing restraint on the
wellbore device by the mechanical restraining element (1206); and
[0107] the mechanical restraint may be a nut that decreases in size
or loses threads and grip, thereby releasing the wellbore device.
[0108] (7) triggering the wellbore device (1207). [0109] The
triggering step (7) may move a piston in the wellbore device. The
triggering step (7) may open a port in the wellbore device. The
triggering step (7) may unplug a wellbore device. The triggering
step (7) may enable a rotational movement in the wellbore
device.
Preferred Exemplary Flowchart Embodiment of a Time Delay Firing
Method (1300)
[0110] As generally seen in the flow chart of FIG. 13 (1300), a
preferred exemplary flowchart embodiment of a time delay firing
method in conjunction with a downhole wellbore time delay tool; the
downhole wellbore time delay tool integrated into an energetic
device used in TCP operation may be generally described in terms of
the following steps: [0111] (1) positioning a downhole wellbore
time delay tool at a desired wellbore location (1301); [0112] The
entire tool may be piped into the casing string as an integral part
of the string and positioned where functioning of the tool is
desired or the tool may be deployed to the desired location using
TCP or a wire line. The wellbore may be cemented or not. The
downhole wellbore time delay tool may be a tool (0210) as
aforementioned in FIG. 2 (0200). [0113] (2) increasing pressure to
actuate an actuating device (1302); [0114] The pressure may be
applied through TCP or the wellbore pressure may be pumped out
until the actuating device such as a rupture disk ruptures. [0115]
(3) initiating a chemical reaction between a mechanical restraining
element and a reactive fluid in the wellbore time delay tool
(1303); [0116] (4) progressing the chemical reaction for a
pre-determined time delay and altering physical property of the
mechanical restraining element (1304); [0117] According to a
preferred exemplary embodiment, the pre-determined time delay
ranges from 1 hour to 48 hours. According to a more preferred
exemplary embodiment, the pre-determined time delay ranges from 2
days to 14 days. According to a most preferred exemplary
embodiment, the pre-determined time delay ranges from 0.01 seconds
to 1 hour. [0118] (5) bleeding pressure until optimal conditions
for perforation is reached (1305); and [0119] bleeding pressure
creates a balanced or an underbalanced condition for perforation.
[0120] (6) firing the wellbore device when the change in the
physical property in the mechanical restraining element releases a
firing pin in the energetic device (1306). [0121] the mechanical
restraining element may be a nut that decreases in size or loses
threads and grip, thereby releasing the wellbore device.
Alternatively, the mechanical restraining element may be a shear
pin, a tensile member or a seal.
Preferred Exemplary Time Vs Temperature Reaction Curve Embodiment
(1400)
[0122] A time (1401) vs temperature (1402) reaction curve is
generally illustrated in FIG. 14 (1400). The nature of the curve
depends on the known fluid type reacting with a material of a
mechanical restraining element. For example, curve (1410) may
represent a fluid type "A" reacting with a material "A" of a
mechanical restraining element, curve (1420) may represent a fluid
type B reacting with a material "B", and curve (1430) may represent
a fluid type "C" reacting with a material "C". The reactive fluid
may be a known fluid such as fresh water, salt water, KCL, NaCl,
HCL, oil, hydrocarbon or combination thereof. The fluid may be
contained in a reservoir (0211) as illustrated in FIG. 2. The
mechanical restraining element may be a nut (0203) as illustrated
in FIG. 2. The material of the mechanical restraining element may
be a metal, a non-metal or an alloy. For example the material of
the mechanical restraining element may be Aluminum, Magnesium or an
aluminum-Magnesium alloy. A curve may be drawn for each combination
of a known fluid and a known material. A model may be developed
from the curve in order to calculate a time delay when a
temperature is determined in a wellbore. For example, at a
temperature of 180.degree. F. the time delay for curve (1410) may
be 4 minutes (1411). Similarly, the time delay for curve (1420) may
be 20 minutes (1412) and time delay for curve (1430) may be 74
minutes (1413). A model may be developed for each combination of a
known fluid and material. The model may be stored and used to
determine a time delay when a temperature is determined in a
wellbore casing. The predictability of time delay based on a
measured temperature enables a triggering event to be delayed
reliably with a greater accuracy. Any time delay may be achieved by
changing the combination of the reactive fluid and material of the
restraining element. The reservoir may be filled with the known
fluid, wellbore fluids or a combination thereof. The mechanical
restraining element may comprise one or more material types that
react and have different degradation rates in one or more fluid
types. The desired time delay may be achieved with a combination of
fluid types and restraining element material types. The mechanical
restraining element may be used in combination with a shear pin
mechanism as illustrated in FIG. 3E-3H so that additional control
may be provided before a detonator can finally fire. According to a
preferred exemplary embodiment, a predictable downhole time delay
tool for determining time delay may comprise a known fluid and a
known mechanical restraining element wherein the known fluid is
configured to react with the mechanical restraining element; and
the time delay is determined based upon a condition encountered in
the wellbore when the known fluid reacts with the mechanical
restraining element. According to another preferred exemplary
embodiment, the time delay is further based on a pre-determined
reaction curve between the known fluid and the mechanical
restraining element. According to yet another preferred exemplary
embodiment, the wellbore condition is wellbore temperature.
According to yet another preferred exemplary embodiment, the
wellbore temperature is determined by distributed temperature
sensing. The known fluid may be wellbore fluids that are sampled
and characterized for time delay and temperature. The known fluid
may be contained in a reservoir or an open chamber configured to
permit fluid to interact with a restraining element.
Preferred Exemplary Flowchart Embodiment of a Time Delay Firing
Method (1500)
[0123] As generally seen in the flow chart of FIG. 15 (1500), a
preferred exemplary flowchart embodiment of a predictable time
delay method, the method operating in conjunction with a
predictable downhole time delay tool comprising a known fluid and a
known mechanical restraining element may be generally described in
terms of the following steps: [0124] (1) positioning the wellbore
time delay tool at a desired wellbore location (1501); [0125] The
wellbore time delay tool may be deployed with TCP, CT, a slick
line, a wire line or pumped from the surface. [0126] (2)
determining a wellbore condition at the wellbore location (1502);
and [0127] A wellbore condition such as a temperature may be
determined with known methods. For example, a fiber optic cable run
with the wellbore casing may be used to determine the temperature.
Other wellbore conditions such as wellbore pressure, composition of
the wellbore fluids may also be determined using know methods and
tools. [0128] (3) calculating a time delay based on the wellbore
condition (1503). [0129] A time delay may be calculated with a Time
vs Temperature curve as illustrated in FIG. 14 (1400). A triggering
event may be initiated in a wellbore device in the wellbore after
elapse of the time delay. The triggering event may be the release
of a firing pin to initiate a percussion primer to a detonation
train. Another trigger event may be unplugging a restriction in a
wellbore casing. Yet another triggering event may be sliding a
piston to open a port to establish a connection to a hydrocarbon
formation.
Preferred Exemplary Detonating Restriction Plug Element (1600)
[0130] It is frequently desired to treat hydrocarbon bearing
formations with pressurized treatment fluids prior to producing
from those formations. In order to ensure that a proper treatment
is performed on a desired formation, that formation is typically
isolated during treatment from other formations traversed by the
wellbore. To achieve sequential treatment of multiple formations,
the casing adjacent to the toe of a horizontal, vertical, or
deviated wellbore is first perforated while the other portions of
the casing are left unperforated. The perforated zone is then
treated by pumping fluid under pressure into that zone through
perforations. Following treatment a restriction plug element such
as element (1600) is placed adjacent to the perforated zone. The
process is repeated until all the zones are perforated. The
plugs/elements are particularly useful in accomplishing operations
such as isolating perforations in one portion of a well from
perforations in another portion or for isolating the bottom of a
well from a wellhead. The purpose of the plug is to isolate some
portion of the well from another portion of the well. In order to
reestablish flow past the existing plugs, in present systems an
operator must remove and/or destroy the plugs by milling, drilling,
or dissolving the plugs. According to a preferred exemplary
embodiment the restriction plug element comprising a detonating
assembly may detonate after the treatment step. Therefore, the
milling or plug removal step may be completely eliminated.
[0131] As generally illustrated in FIG. 16A and FIG. 16B, a
detonating restriction plug element (1600) for isolating stages in
a wellbore casing may comprise a body (1620) of degradable
material. The restriction plug element may be configured with a
hollow passage by drilling a cavity into the degradable element
body (1620). The hollow passage may be configured to receive a
detonating assembly (1630) that may comprise a detonating device
coupled to a mechanical restraining element (1603). The mechanical
restraining element (1603) is chosen such that it reacts with a
reactive fluid (1601) and the mechanical restraining element (1603)
also restrains a firing pin (1604) in the detonating device. The
reactive fluid (1601) may come into contact with the mechanical
restraining element (1603) and initiate a chemical reaction and
that reaction enables a physical property change in the mechanical
restraining element (1603) for a pre-determined time delay. The
firing pin (1604) initiates a detonating event after elapse of the
pre-determined time delay. In other cases the firing pin may
initiate a detonating event just before the elapse of the
pre-determined time delay. The reactive fluid (1601) may be
contained in a reservoir (1611) or a space confined within the
detonating assembly (1630). The reactive fluid may be pre-filled in
the reservoir (1611) or wellbore fluids may enter the space after
the restriction plug element (1600) is deployed into the wellbore
casing. The hollow passage may be machined in the body (1620) to
receive the detonating assembly (1630) and capped with a seal
(1610).
[0132] The restriction plug element (1600) may be dropped or pumped
into the casing string to a desired location where isolation is
required. The wellbore may be cemented or not. The fluid in the
reservoir (1611) may be held at an initial position by the
actuating device (1602) such as a rupture disk. The tool mandrel is
machined to accept the actuating device (1602) (such as rupture
discs) that ultimately controls the flow of reactive fluid (1601).
The fluid reservoir (1611) may be further installed within a fluid
holding body. In one embodiment, the rated pressure of the
actuating device may range from 500 PSI to 15000 PSI.
[0133] The reservoir (1611) may be in fluid communication with the
mechanical restraining element via the actuation device (1602).
Alternatively, the reactive fluid may be directly in fluid
communication with the mechanical restraining element via the
actuation device (1602) without a reservoir. For example, the
mechanical restraining element may not be in fluid communication
initially with any fluid. Instead, the reactive fluid may be
directly in fluid communication with the mechanical restraining
element without an actuation device. When the pressure in the
wellbore casing increases to actuate the actuating device, wellbore
fluids may enter and react with the mechanical restraining element.
It should be noted that the reservoir to contain a reactive fluid
may not be construed as a limitation. The volume of the reservoir
may range from 25 ml to 100 ml. According to a preferred exemplary
embodiment, the material of the reservoir may be selected from a
group comprising: metal, ceramic, plastic, degradable, long term
degradable, glass, composite or combinations thereof. The reservoir
may also be pressurized so that there is sufficient flow of the
reactive fluid towards the restraining element. The actuation
device (1602) may be a reverse acting rupture disk that blocks
fluid communication between the reactive fluid and the restraining
element. When the pressure of the fluid acting on the actuation
device (1602) exceeds a rated pressure of the actuating device
(1602), the reactive fluid (1601) may flow through and comes in
contact with the restraining element (1603).
[0134] The pressure on the actuation device (1602) may be ramped up
to the rated pressure with pressure from the reactive fluid. The
reactive fluid (1601) is configured to react with the mechanical
restraining element (1603) at a temperature expected to be
encountered in the wellbore. According to a preferred exemplary
embodiment a physical property change in the restraining element
may occur at a pre-determined temperature expected to be
encountered in the wellbore casing. According to a further
preferred exemplary embodiment the pre-determined temperature
ranges from 25.degree. C.-250.degree. C. The mechanical restraining
element (1603) may be a nut, a shear pin, a tensile member, or a
holding device that degrades as the reaction takes place. Upon
further degradation, the mechanical restraining element (1603) may
release a restraint on the firing pin (1604) and initiate a
detonating event in the detonator (1609).
[0135] According to a preferred exemplary embodiment the reactive
fluid is selected from a group comprising: fresh water, salt water,
KCL, NaCl, HCL, or hydrocarbons.
[0136] The detonator (1609) and the firing pin (1604) may be
operatively connected to the mechanical restraining element (1603)
via threads, seals (1613) or a connecting element. In some
instances, the mechanical restraining element may be a nut that may
be screwed or attached to a counterpart in the detonating assembly.
In other instances the restraining element may be a tensile
member.
[0137] According to a preferred exemplary embodiment, a physical
property change due to a chemical reaction may enable the
restraining element to change shape for a pre-determined period of
time. The physical property may be strength, ductility or
elasticity. A delay means, to move a firing pin holder out of
locking engagement with a firing pin to release the firing pin and
may be achieved by the predetermined time interval. The firing pin
(1604) may contact a percussion detonator/initiator that may
connect to a bidirectional booster. The bidirectional booster may
accept a detonation input from the detonator (1609). The detonating
cord may be initiated in turn by the booster. When the firing pin
(1604) is actuated after the mechanical restraint (1603) is
released, the firing pin (1604) may contact a percussion detonator
and in turn initiate a detonator (1609) through a booster and a
detonating cord.
[0138] According to a preferred exemplary embodiment, the
pre-determined time delay ranges from 1 hour to 48 hours. According
to a more preferred exemplary embodiment, the pre-determined time
delay ranges from 2 days to 14 days. According to a most preferred
exemplary embodiment, the pre-determined time delay ranges from
0.01 seconds to 1 hour.
[0139] According to a preferred exemplary embodiment, the chemical
reaction may be an exothermic reaction that gives off heat. The
energy needed to initiate the chemical reaction may be less than
the energy that is subsequently released by the chemical reaction.
According to another preferred exemplary embodiment, the chemical
reaction may be an endothermic reaction that absorbs heat. The
energy needed to initiate the chemical reaction may be greater than
the energy that is subsequently released by the chemical
reaction.
[0140] The rate of the chemical reaction may be accelerated or
retarded based on factors such as nature of the reactants, particle
size of the reactants, concentration of the reactants, pressure of
the reactants, temperature and catalysts. According to a preferred
exemplary embodiment, a catalyst may be added to alter the rate of
the reaction. According to a preferred exemplary embodiment, the
material of the restraining element may be selected from a group
comprising: mixture of aluminum, copper sulfate, potassium
chlorate, and calcium sulfate, iron, magnesium, steel, plastic,
degradable, magnesium-iron alloy, particulate oxide of an alkali or
alkaline earth metal and a solid, particulate acid or strongly acid
salt, or mixtures thereof. The catalyst may be selected from a
group comprising salts. According to a preferred exemplary
embodiment, the material of the restraining element may be selected
from a group comprising: metal, non-metal or alloy.
[0141] According to a preferred exemplary embodiment the
pre-determined time delay is determined by concentration of the
reactive fluids. According to another preferred exemplary
embodiment the pre-determined time delay is determined by reaction
rate of the reactive fluids with the mechanical restraining
element. According to yet another preferred exemplary embodiment
the pre-determined time delay is determined by reaction time of the
reactive fluids with the mechanical restraining element. According
to a further preferred exemplary embodiment the pre-determined time
delay is determined by masking a contact area of the mechanical
restraining element. According to a further preferred exemplary
embodiment the pre-determined time delay is determined by masking a
total area of the mechanical restraining element in contact with
the mechanical restraining element.
[0142] According to a preferred exemplary embodiment the shape of
the mechanical restraining element is selected from a group
comprising: square, circle, oval, and elongated.
[0143] A sealed cap (1610) may seal the exposed end of the
detonating assembly (1630) to keep the detonating assembly in the
restriction element. The sealed cap may be shaped to fit the
detonating restriction plug element such that the cap and the
element form a complete sphere or a cylindrical shape.
[0144] According to an alternate preferred embodiment, a multi
stage restraining element comprising a blocking member and a
restraining member may further increase a time delay. For example,
mechanical restraining element (1603) may be coupled with a
blocking member that may have a different composition and reaction
time with the fluid in the reservoir. The blocking member may react
with the fluid for a period of time and may restrict fluid access
to the mechanical restraining element for a pre-determined period
of time. It should be noted that the multi stage restraining
element may not limited to a blocking member and a restraining
element. Any number of blocking members and restraining elements
may be used in combination to achieve a desired time delay. The
reaction times and therefore the time delays of each of the bonding
members with the fluid may be characterized at various temperatures
expected in the wellbore.
[0145] In another preferred exemplary embodiment, the reservoir may
be filled with wellbore fluids. For example, the reservoir may be
empty when deployed into the wellbore and later filled with
wellbore fluids. A time vs temperature chart for the restraining
element may be characterized with different compositions of
wellbore fluids expected in the wellbore at temperatures expected
in the wellbore casing. Alternatively, the fluid reservoir may be
partially filled with the known fluid and wellbore fluids may fill
the remaining portion of the reservoir. The reservoir may be filled
with the known fluid, wellbore fluids or a combination thereof. The
mechanical restraining element may comprise one or more material
types that react and have different degradation rates in one or
more fluid types. The desired time delay may be achieved with a
combination of fluid types and restraining element material
types.
[0146] As generally illustrated in FIG. 16C a detonating
restriction plug element for isolating stages in a wellbore casing
may comprise a body of degradable material. The restriction plug
element may be configured with a hollow passage by drilling a
cavity into the degradable element body. The hollow passage may be
configured to receive a detonating assembly that may comprise a
detonating device coupled to a mechanical restraining element
(1603). The mechanical restraining element (1603) is chosen such
that it reacts with a reactive fluid and the mechanical restraining
element (1603) also restrains a firing pin (1604) in the detonating
device. The reactive fluid may come into contact with the
mechanical restraining element (1603) and initiate a chemical
reaction and that reaction enables a physical property change in
the mechanical restraining element (1603) for a pre-determined time
delay. The firing pin (1604) initiates a detonating event after
elapse of the pre-determined time delay. In other cases the firing
pin may initiate a detonating event just before the elapse of the
pre-determined time delay. The reactive fluid may not be held in a
reservoir or a chamber as shown in FIG. 16A and FIG. 16B. In a
preferred exemplary embodiment, the reactive fluid reacts with the
mechanical retaining element without a pressure actuation device.
It should be noted that the reactive fluid may be wellbore fluids
that come in contact with the mechanical restraining element.
Preferred Exemplary Flowchart Embodiment of a Detonating Method
(1700)
[0147] As generally seen in the flow chart of FIG. 17 (1700), a
preferred exemplary flowchart embodiment of a detonating method
operating in conjunction with a detonating restriction plug element
(1600) for isolating stages in a wellbore casing may be generally
described in terms of the following steps: [0148] (1) Deploying the
detonating restriction plug element into the wellbore casing and
isolating a stage to block fluid communication (1701); [0149] The
detonating restriction plug element may be pumped or dropped into
the wellbore casing to a desired location. The element may seat in
a sleeve member or open a sliding sleeve. [0150] (2) Fracturing the
stage that was isolated in step (1) (1702); [0151] (3) Initiating a
chemical reaction between a mechanical restraining element and a
reactive fluid (1703); [0152] (4) Progressing the chemical reaction
for a pre-determined time delay and altering physical property of
the mechanical restraining element (1704); [0153] According to a
preferred exemplary embodiment, the pre-determined time delay
ranges from 1 hour to 48 hours. According to a more preferred
exemplary embodiment, the pre-determined time delay ranges from 2
days to 14 days. According to a most preferred exemplary
embodiment, the pre-determined time delay ranges from 0.01 seconds
to 1 hour. [0154] (5) Releasing the firing pin in the detonating
assembly after elapse of the pre-determined time delay (1705).
[0155] the mechanical restraining element may be a nut that
decreases in size or loses threads and grip, thereby releasing the
firing pin. Alternatively, the mechanical restraining element may
be a shear pin, a tensile member or a seal. [0156] (6) Initiating a
detonating event (1706). [0157] According to a preferred exemplary
embodiment the element fragments after the detonating event. [0158]
According to another preferred exemplary embodiment the hollow
passage remains intact while the element further degrades in the
wellbore fluids. [0159] According to yet another preferred
exemplary embodiment the initiating step is further delayed by a
pressure actuating device.
System Summary
[0160] The present invention system anticipates a wide variety of
variations in the basic theme of time delay, but can be generalized
as a downhole wellbore time delay tool for use with a wellbore
device in a wellbore casing, comprising: [0161] (a) a mechanical
restraining element; [0162] (b) a reactive fluid, the reactive
fluid configured to react with the mechanical restraining element;
[0163] (c) an actuating device configured to enable fluid
communication between the reactive fluid and the mechanical
restraining element;
[0164] whereby,
[0165] when a stored energy is applied on the wellbore device, the
actuating device actuates and the reactive fluid comes in contact
with the mechanical restraining element and initiates a chemical
reaction; the chemical reaction enables a physical property change
in the mechanical restraining element such that the stored energy
applied on the wellbore device is delayed by a pre-determined time
delay while the mechanical restraining element undergoes the
physical property change.
[0166] This general system summary may be augmented by the various
elements described herein to produce a wide variety of invention
embodiments consistent with this overall design description.
Method Summary
[0167] The present invention method anticipates a wide variety of
variations in the basic theme of implementation, but can be
generalized as a detonating restriction plug element for use with a
wellbore device in a wellbore casing [0168] wherein [0169] the
restriction plug element configured with a hollow passage; [0170]
the hollow passage configured to receive a detonating assembly;
[0171] the detonating assembly comprising a detonating device
coupled to a mechanical restraining element; [0172] the mechanical
restraining element configured to react with a reactive fluid; the
mechanical restraining element configured to restrain a firing pin
in the detonating device [0173] (1) deploying the restriction plug
element into the wellbore casing and isolating a stage to block
fluid communication; [0174] (2) fracturing the stage; [0175] (3)
initiating a chemical reaction between the mechanical restraining
element and the reactive fluid; [0176] (4) progressing the chemical
reaction for a pre-determined time delay and changing a physical
property of the mechanical restraining element; [0177] (5)
releasing the firing pin after elapse of the time delay; and [0178]
(6) initiating a detonating event.
[0179] This general method summary may be augmented by the various
elements described herein to produce a wide variety of invention
embodiments consistent with this overall design description.
System/Method Variations
[0180] The present invention anticipates a wide variety of
variations in the basic theme of oil and gas extraction. The
examples presented previously do not represent the entire scope of
possible usages. They are meant to cite a few of the almost
limitless possibilities.
[0181] This basic system and method may be augmented with a variety
of ancillary embodiments, including but not limited to: [0182] An
embodiment wherein the chemical reaction occurs at a pre-determined
temperature expected to be encountered in the wellbore casing.
[0183] An embodiment wherein the pre-determined temperature ranges
from 25.degree. C.-250.degree. C. [0184] An embodiment wherein the
reactive fluid is contained in a reservoir; the reservoir in
pressure communication with the mechanical restraining element.
[0185] An embodiment wherein the reactive fluid is wellbore fluid
expected in the wellbore casing. [0186] An embodiment wherein the
reactive fluid is selected from a group comprising: fresh water,
salt water, KCL, NaCl, HCL, oil or hydrocarbon. [0187] An
embodiment wherein the element fragments after the detonating
event. [0188] An embodiment wherein the element remains intact
after the detonating event and creates a flow channel. [0189] An
embodiment wherein the time delay is determined by a time greater
than a fracturing time of an isolated stage. [0190] An embodiment
wherein the element is pumped down into the wellbore casing. [0191]
An embodiment wherein the time delay ranges from 1 hour to 48
hours. [0192] An embodiment wherein the time delay ranges from 0.01
seconds to 1 hour. [0193] An embodiment wherein the element further
comprises a degradable material. [0194] An embodiment wherein the
mechanical restraining element is a nut. [0195] An embodiment
wherein the mechanical restraining element is a tensile member.
[0196] An embodiment wherein the pre-determined time delay is
determined by composition of the reactive fluids. [0197] An
embodiment wherein the pre-determined time delay is determined by
reaction rate of the reactive fluids with the mechanical
restraining element. [0198] An embodiment wherein the
pre-determined time delay is determined by reaction time of the
reactive fluids with the mechanical restraining element. [0199] An
embodiment wherein the pre-determined time delay is determined by
masking a contact area of the mechanical restraining element.
[0200] An embodiment wherein the pre-determined time delay is
determined by masking a total area of the mechanical restraining
element in contact with the mechanical restraining element. [0201]
An embodiment wherein a shape of the mechanical restraining element
is selected from a group comprising: square, circle, oval, and
elongated. [0202] An embodiment wherein a material of the
mechanical restraining element is selected from a group comprising:
Magnesium, Aluminum, or Magnesium-Aluminum alloy. [0203] An
embodiment wherein the detonating device is a slim detonator.
[0204] An embodiment wherein the detonating assembly further
comprises a detonating cord coupled to the detonating device.
[0205] An embodiment wherein the reactive fluid is pressure
isolated from the mechanical restraining element through a pressure
actuating device. [0206] An embodiment wherein the actuating device
is a rupture disk; the rupture disk actuated by pressure in the
wellbore casing.
[0207] One skilled in the art will recognize that other embodiments
are possible based on combinations of elements taught within the
above invention description.
CONCLUSION
[0208] A detonating restriction plug element and method in a
wellbore casing has been disclosed. The element includes a hollow
passage in the restriction plug element that receives a detonating
assembly coupled to a mechanical restraining element, and a space
for containing a reactive fluid. The mechanical restraining element
undergoes a change in shape for a pre-determined time delay due to
a chemical reaction when the reactive fluid in the space such as
wellbore fluids comes in contact with the restraining element. A
firing pin in the detonating assembly is released when the
restraining elements changes shape and releases the restraint on
the firing pin. The firing pin contacts a detonator in the
detonating assembly and causes a detonating event such that the
restriction plug element fragments.
* * * * *