U.S. patent application number 16/177695 was filed with the patent office on 2020-05-07 for method of producing hydrocarbon resources using an upper rf heating well and a lower producer/injection well and associated appa.
The applicant listed for this patent is EAGLE TECHNOLOGY, LLC. Invention is credited to MARK A. TRAUTMAN, Brian N. Wright.
Application Number | 20200141216 16/177695 |
Document ID | / |
Family ID | 70284990 |
Filed Date | 2020-05-07 |
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United States Patent
Application |
20200141216 |
Kind Code |
A1 |
TRAUTMAN; MARK A. ; et
al. |
May 7, 2020 |
METHOD OF PRODUCING HYDROCARBON RESOURCES USING AN UPPER RF HEATING
WELL AND A LOWER PRODUCER/INJECTION WELL AND ASSOCIATED
APPARATUS
Abstract
A method of producing hydrocarbon resources from a subterranean
formation may include heating the subterranean formation with at
least one radio frequency (RF) antenna located in an upper well
within the subterranean formation. The method may further include
producing hydrocarbon resources from a lower well within the heated
subterranean formation and vertically beneath the upper well to
create a void within the subterranean formation, and injecting a
solvent into the void within the heated subterranean formation from
the lower well.
Inventors: |
TRAUTMAN; MARK A.;
(Melbourne, FL) ; Wright; Brian N.; (Indialantic,
FL) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
EAGLE TECHNOLOGY, LLC |
Melbourne |
FL |
US |
|
|
Family ID: |
70284990 |
Appl. No.: |
16/177695 |
Filed: |
November 1, 2018 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 43/25 20130101;
E21B 47/07 20200501; E21B 43/2401 20130101; E21B 47/06
20130101 |
International
Class: |
E21B 43/24 20060101
E21B043/24 |
Claims
1. A method of producing hydrocarbon resources from a subterranean
formation comprising: heating the subterranean formation with at
least one radio frequency (RF) antenna located in an upper well
within the subterranean formation; producing hydrocarbon resources
from a lower well within the heated subterranean formation and
vertically beneath the upper well to create a void within the
subterranean formation; injecting a solvent upward into the void
within the heated subterranean formation from the lower well; and
the heating comprising continuously heating the subterranean
formation with the at least one RF antenna from the upper well
during producing and injecting to create solvent vapor for
refluxing the solvent.
2. The method of claim 1 wherein heating comprises pre-heating the
subterranean formation with the at least one RF antenna prior to
producing the hydrocarbon resources.
3. The method of claim 2 wherein pre-heating comprises pre-heating
the subterranean formation to a temperature in a range of
80-100.degree. C. prior to initiating producing.
4. The method of claim 1 wherein producing and injecting are cycled
over time.
5. The method of claim 1 wherein injecting comprises injecting the
solvent into the void from the lower well while simultaneously
producing the hydrocarbon resources from the lower well.
6. (canceled)
7. The method of claim 1 wherein the upper and lower wells are
parallel to one another.
8. The method of claim 1 wherein a pressure of the solvent injected
into the void is decreased over time.
9. The method of claim 1 wherein the lower well comprises a solvent
supply pipe and a producer pipe adjacent thereto.
10. A method of producing hydrocarbon resources from a subterranean
formation comprising: pre-heating the subterranean formation with
at least one radio frequency (RF) antenna located in an upper well
within the subterranean formation; producing hydrocarbon resources
from a lower well within the heated subterranean formation and
vertically beneath the upper well to create a void within the
subterranean formation; injecting a solvent upward into the void
within the heated subterranean formation from the lower well;
cycling producing and injecting over time; and continuously heating
the subterranean formation with the at least one RF antenna from
the upper well during the producing and injecting cycles to create
solvent vapor for refluxing the solvent, the refluxing comprising
when a solvent and hydrocarbon resources mixture approaches the
lower well, generating solvent vapor from the solvent and
hydrocarbon resources mixture, and causing the solvent vapor to
migrate to a vapor chamber boundary for additional diffusion into
the hydrocarbon resources in the subterranean formation.
11. The method of claim 10 wherein the upper and lower wells are
parallel to one another.
12. The method of claim 10 wherein a pressure of the solvent
injected into the void is decreased over time.
13. A method of producing hydrocarbon resources from a subterranean
formation comprising: pre-heating the subterranean formation with
at least one radio frequency (RF) antenna located in an upper well
within the subterranean formation; producing hydrocarbon resources
from a lower well within the heated subterranean formation and
vertically beneath the upper well to create a void within the
subterranean formation; injecting a solvent upward into the void
within the heated subterranean formation from the lower well while
simultaneously producing hydrocarbon resources from the lower well;
and continuously heating the subterranean formation with the at
least one RF antenna from the upper well during producing and
injecting to create solvent vapor for refluxing the solvent.
14. The method of claim 13 wherein the upper and lower wells are
parallel to one another.
15. The method of claim 13 wherein a pressure of the solvent
injected into the void is decreased over time.
16. An apparatus for producing hydrocarbon resources from a
subterranean formation comprising: a radio frequency (RF) source;
at least one RF antenna located in an upper well within the
subterranean formation and configured to continuously heat the
subterranean formation based upon RF power from the RF source
during producing and injecting to create solvent vapor for
refluxing a solvent; a producer pipe and a solvent supply pipe
positioned within a lower well vertically beneath the upper well; a
recovery pump coupled to the producer pipe and configured to
recover hydrocarbon resources from the subterranean formation from
the lower well to create a void within the heated subterranean
formation; and a solvent source coupled to the solvent supply pipe
and configured to inject the solvent upward into the void in the
subterranean formation from the lower well.
17. The apparatus of claim 16 wherein the recovery pump and the
solvent source are configured to respectively recover hydrocarbon
resources and inject solvent into the subterranean formation in a
cyclical fashion over time.
18. The apparatus of claim 16 wherein the solvent supply pipe and
the producer pipe are configured to inject the solvent into the
void from the lower well while simultaneously producing hydrocarbon
resources from the lower well.
19. (canceled)
20. The apparatus of claim 16 wherein the upper and lower wells are
parallel to one another.
21. The apparatus of claim 16 wherein a pressure of the solvent
injected into the subterranean formation decreases over time.
Description
TECHNICAL FIELD
[0001] The present invention relates to the field of hydrocarbon
resource recovery, and, more particularly, to hydrocarbon resource
recovery methods using radio frequency heating devices.
BACKGROUND
[0002] Energy consumption worldwide is generally increasing, and
conventional hydrocarbon resources are being consumed. In an
attempt to meet demand, the exploitation of unconventional
resources may be desired. For example, highly viscous hydrocarbon
resources, such as heavy oils, may be trapped in sands where their
viscous nature does not permit conventional oil well production.
This category of hydrocarbon resource is generally referred to as
oil sands. Estimates are that trillions of barrels of oil reserves
may be found in such oil sand formations.
[0003] In some instances, these oil sand deposits are currently
extracted via open-pit mining. Another approach for in situ
extraction for deeper deposits is known as Steam-Assisted Gravity
Drainage (SAGD). The heavy oil is immobile at reservoir
temperatures, and therefore, the oil is typically heated to reduce
its viscosity and mobilize the oil flow. In SAGD, pairs of injector
and producer wells are formed to be laterally extending in the
ground. Each pair of injector/producer wells includes a lower
producer well and an upper injector well. The injector/production
wells are typically located in the payzone of the subterranean
formation between an underburden layer and an overburden layer.
[0004] The upper injector well is used to typically inject steam,
and the lower producer well collects the heated crude oil or
bitumen that flows out of the formation, along with any water from
the condensation of injected steam and some connate water in the
formation. The injected steam forms a steam chamber that expands
vertically and horizontally in the formation. The heat from the
steam reduces the viscosity of the heavy crude oil or bitumen,
which allows it to flow down into the lower producer well where it
is collected and recovered. The steam and gases rise due to their
lower density. Gases, such as methane, carbon dioxide, and hydrogen
sulfide, for example, may tend to rise in the steam chamber and
fill the void space left by the oil defining an insulating layer
above the steam. Oil and water flow is by gravity driven drainage
urged into the lower producer well.
[0005] Many countries in the world have large deposits of oil
sands, including the United States, Russia, and various countries
in the Middle East. Oil sands may represent as much as two-thirds
of the world's total petroleum resource, with at least 1.7 trillion
barrels in the Canadian Athabasca Oil Sands, for example. At the
present time, only Canada has a large-scale commercial oil sands
industry, though a small amount of oil from oil sands is also
produced in Venezuela. Because of increasing oil sands production,
Canada has become the largest single supplier of oil and products
to the United States. Oil sands now are the source of almost half
of Canada's oil production, while Venezuelan production has been
declining in recent years. Oil is not yet produced from oil sands
on a significant level in other countries.
[0006] U.S. Published Patent Application No. 2010/0078163 to
Banerjee et al. discloses a hydrocarbon recovery process whereby
three wells are provided: an uppermost well used to inject water, a
middle well used to introduce microwaves into the reservoir, and a
lowermost well for production. A microwave generator generates
microwaves which are directed into a zone above the middle well
through a series of waveguides. The frequency of the microwaves is
at a frequency substantially equivalent to the resonant frequency
of the water so that the water is heated.
[0007] Along these lines, U.S. Published Patent Application No.
2010/0294489 to Dreher, Jr. et al. discloses using microwaves to
provide heating. An activator is injected below the surface and is
heated by the microwaves, and the activator then heats the heavy
oil in the production well. U.S. Published Patent Application No.
2010/0294488 to Wheeler et al. discloses a similar approach.
[0008] U.S. Pat. No. 7,441,597 to Kasevich discloses using a radio
frequency generator to apply radio frequency (RF) energy to a
horizontal portion of an RF well positioned above a horizontal
portion of an oil/gas producing well. The viscosity of the oil is
reduced as a result of the RF energy, which causes the oil to drain
due to gravity. The oil is recovered through the oil/gas producing
well.
[0009] U.S. Pat. No. 7,891,421, also to Kasevich, discloses a choke
assembly coupled to an outer conductor of a coaxial cable in a
horizontal portion of a well. The inner conductor of the coaxial
cable is coupled to a contact ring. An insulator is between the
choke assembly and the contact ring. The coaxial cable is coupled
to an RF source to apply RF energy to the horizontal portion of the
well.
[0010] U.S. Patent Application Publication No. 2011/0309988 to
Parsche discloses a continuous dipole antenna. More particularly,
Parsche disclose a shielded coaxial feed coupled to an AC source
and a producer well pipe via feed lines. A non-conductive magnetic
bead is positioned around the well pipe between the connection from
the feed lines.
[0011] U.S. Patent Application Publication No. 2012/0085533 to
Madison et al. discloses combining cyclic steam stimulation with RF
heating to recover hydrocarbons from a well. Steam is injected into
a well followed by a soaking period wherein heat from the steam
transfers to the hydrocarbon resources. After the soaking period,
the hydrocarbon resources are collected, and when production levels
drop off, the condensed steam is revaporized with RF radiation to
thus upgrade the hydrocarbon resources.
[0012] Unfortunately, long production times, for example, due to a
failed start-up, to extract oil using SAGD may lead to significant
heat loss to the adjacent soil, excessive consumption of steam, and
a high cost for recovery. Significant water resources are also
typically used to recover oil using SAGD, which may impact the
environment. Limited water resources may also limit oil recovery.
SAGD is also not an available process in permafrost regions, for
example, or in areas that may lack sufficient cap rock, are
considered "thin" payzones, or payzones that have interstitial
layers of shale.
[0013] Additionally, production times and efficiency may be limited
by post extraction processing of the recovered oil. More
particularly, oil recovered may have a chemical composition or have
physical traits that may require additional or further post
extraction processing as compared to other types of oil
recovered.
SUMMARY
[0014] A method of producing hydrocarbon resources from a
subterranean formation may include heating the subterranean
formation with at least one radio frequency (RF) antenna located in
an upper well within the subterranean formation. The method may
further include producing hydrocarbons from a lower well within the
heated subterranean formation and vertically beneath the upper well
to create a void within the subterranean formation, and injecting a
solvent into the void within the heated subterranean formation from
the lower well.
[0015] More particularly, heating may include pre-heating the
subterranean formation with the at least one RF antenna prior to
producing the hydrocarbon resources. By way of example, pre-heating
may include pre-heating the subterranean formation to a temperature
in a range of 80-100.degree. C. prior to initiating producing.
[0016] In accordance with one example implementation, producing and
injecting may be cycled over time. Furthermore, in accordance with
another example implementation, injecting may comprise injecting
the solvent into the void from the lower well while simultaneously
producing hydrocarbons from the lower well. Furthermore, heating
may comprise continuously heating the subterranean formation with
the at least one RF antenna from the upper well during producing
and injecting.
[0017] By way of example, the upper and lower wells may be parallel
to one another. Furthermore, a pressure of the solvent injected
into the void may be decreased over time. In addition, the lower
well may include a solvent supply pipe and a producer pipe adjacent
thereto.
[0018] A related apparatus for producing hydrocarbon resources from
a subterranean formation may include a radio frequency (RF) source
and at least one radio frequency (RF) antenna located in an upper
well within the subterranean formation and configured to heat the
subterranean formation based upon RF power from the RF source. The
apparatus may further include a producer pipe and a solvent supply
pipe positioned within a lower well vertically beneath the upper
well, a recovery pump coupled to the producer pipe and configured
to recover hydrocarbon resources from the subterranean formation
from the lower well, and a solvent source coupled to the solvent
supply pipe and configured to inject a solvent into the
subterranean formation from the lower well.
BRIEF DESCRIPTION OF THE DRAWINGS
[0019] FIG. 1 is a schematic block diagram of an apparatus for
hydrocarbon resource recovery including an upper RF heating well
and a lower producer/solvent injection well in accordance with an
example embodiment.
[0020] FIG. 2 is a flow diagram illustrating example method aspects
associated with the apparatus of FIG. 1.
[0021] FIGS. 3A and 3B are parts of a flow diagram illustrating an
example cyclical production/injection hydrocarbon resource recovery
approach for the apparatus of FIG. 1 in accordance with an example
embodiment.
[0022] FIG. 4 is a graph of oil produced vs. time comparing the
hydrocarbon resource recovery approach of FIGS. 3A and 3B with a
prior hydrocarbon resource recovery approach.
[0023] FIG. 5 is a flow diagram illustrating an example continuous
production/injection hydrocarbon resource recovery approach for the
apparatus of FIG. 1 in accordance with an example embodiment.
DETAILED DESCRIPTION
[0024] The present invention will now be described more fully
hereinafter with reference to the accompanying drawings, in which
preferred embodiments of the invention are shown. This invention
may, however, be embodied in many different forms and should not be
construed as limited to the embodiments set forth herein. Rather,
these embodiments are provided so that this disclosure will be
thorough and complete, and will fully convey the scope of the
invention to those skilled in the art. Like numbers refer to like
elements throughout.
[0025] By way of background, some RF hydrocarbon recovery systems
include an upper solvent injector well, and a producer well below
the injector well. Solvents (e.g., propane, light alkanes or other
relatively light hydrocarbons) are injected into a deposit to
dilute the heavy oil or bitumen. The solvent advantageously reduces
the native viscosity of or thins the hydrocarbon resources.
Furthermore, an RF antenna is positioned within the injector well
to apply RF heating to the formation, which also reduces the
viscosity of the heavy oil and allows it to flow more easily into
the producer well below for recovery. One such example well
configuration is set forth in U.S. Pat. No. 9,739,126 to Trautman
et al., which is assigned to the present Assignee and hereby
incorporated herein in its entirety by reference. While this
configuration is highly effective, the flow cross sectional area
required to deliver the solvent through the antenna may, in some
instances, increase the well casing to non-conventional, and
therefore more expensive, sizes.
[0026] Generally speaking, the present approach advantageously
allows installation of an RE antenna within smaller conventional
casing sizes, as it provides RF heating from an upper antenna well,
but moves the solvent injection function to the lower well. That
is, the upper (antenna) well provides RF energy to the formation,
and there is no solvent injection from the upper well. Rather,
solvent injection and hydrocarbon production are both provided
through the lower well.
[0027] Referring initially to FIG. 1 and the flowchart 60 of FIG.
2, an apparatus 30 and associated method of recovering hydrocarbon
resources in a subterranean formation 31 is now described. The
subterranean formation 31 illustratively includes an upper well 32
and a lower well 33 therein, with the lower well being vertically
below the upper well. The upper and lower wells 32, 33
illustratively initially extend diagonally from the surface of the
subterranean formation to a desired depth, and then laterally
within the subterranean formation along a payzone 34 where
hydrocarbon (e.g., bitumen or heavy oil) recovery is to occur. The
payzone 34 will be located at various depths depending on the
location of the subterranean formation 31, and the length of the
payzone may also vary between different implementations. By way of
example, a relatively thin payzone may be in a range of ten meters
or less, while a larger payzone may be between thirty and forty
meters, though again other ranges of payzones may be accommodated
by the apparatus 30 and recovery techniques discussed herein.
[0028] In the illustrated example, the apparatus includes a radio
frequency (RF) source 35 at the wellhead, and one or more RF
antennas located in the upper well 32 and configured to heat the
subterranean formation 31 based upon RF power from the RF source,
at Block 62. More particularly, the RF power is supplied from the
RF source 35 to an RF transmission line 39 having an RF feed
section 36, which is within and coupled to an electrically
conductive well pipe 43. The RF transmission line 39 may be a
coaxial transmission line, for example. The electrically conductive
well pipe 43 may be a wellbore liner, for example, and defines an
RE antenna (e.g., a dipole antenna) with the RE feed portion 36. Of
course, other antenna configurations may be used in different
embodiments.
[0029] The electrically conductive well pipe 43 may have a tubular
shape, for example, to allow for equipment, sensors, etc. to be
passed therethrough. More particularly, a temperature sensor and/or
a pressure sensor may be positioned on or within the RF
transmission line 39 and/or RF feed section 36. A temperature
and/or a pressure sensor may alternatively or additionally be
positioned on or within the electrically conductive well pipe 43 to
read temperatures and pressures of the subterranean formation 31,
as will be discussed further below.
[0030] The apparatus 30 further illustratively includes a producer
pipe 37 and a solvent supply pipe 38 positioned within the lower
well 33. A recovery pump 40 is coupled to the producer pipe 37 and
configured to recover hydrocarbon resources from the subterranean
formation 31 from the lower well 33, at Block 63. In the
illustrated example the recovery pump 40 is a submersible pump
positioned within the electrically conductive well pipe of the
second well 33, although in some embodiments the recovery pump may
be positioned above the subterranean formation 31 at the wellhead.
The recovery pump 40 may be an artificial gas lift (AGL), or other
type of pump, for example, using hydraulic or pneumatic lifting
techniques.
[0031] The initial production begins to create a void 42 within the
payzone 34 as oil is drawn from the subterranean formation 31, as
will be discussed further below. Furthermore, a solvent source 41
is coupled to the solvent supply pipe 38 and configured to inject a
solvent into the subterranean formation 31 from the lower well 33,
at Block 64, which illustratively concludes the method of FIG. 2
(Block 65). The solvent supply pipe 38 illustratively includes
openings 44 spaced along a length thereof within the payzone 34.
However, the number of injection points shown is just an example,
and different numbers and spacings of the openings 44 may be used
in different configurations, depending on the length of the payzone
34, type of solvent being used, etc. In the illustrated
configuration, the openings 44 may be spaced apart from an inlet 45
of the producer pipe 37 to help avoid extraction of solvent before
it has a chance to enter the formation 31.
[0032] Referring additionally to the flow diagram 70 of FIGS.
3A-3B, an example implementation of the above-described hydrocarbon
production method is now described which utilizes a cyclical
production/injection approach, alternating between hydrocarbon
production and solvent injection from the lower well 33. Beginning
at Block 71, RF heating is initiated from the RF source 35 to begin
pre-heating the formation 31 to a desired starting temperature, at
Blocks 72-73. In one example embodiment, the target production
starting temperature may be in a range of 50 to 200.degree. C., and
more particularly 80 to 100.degree. C., measured from a temperature
sensor(s) within the lower well 33 (and/or upper well 32 in some
embodiments). However, other target temperatures may be used in
different embodiments as well. The pre-heating phase may take two
to three months in a typical implementation, although slower or
faster pre-heating may occur with different geological formations
and implementations.
[0033] Once the desired temperature is reached, oil may then be
produced from the lower well 44 to create the void 42 within the
formation 31, through which the solvent will enter the formation,
at Block 74. Production may continue until the desired operational
target is reached, at Block 75. By way of example, the target may
be production for a certain period of time, for a certain initial
quantity of oil, while above a target oil rate, etc., to create the
desired initial void size within the formation 31. Once production
ceases (e.g., the recovery pump 40 is turned off), then solvent
injection from the lower well 33 commences (e.g., by turning on the
solvent source 41), at Block 76, until an injection operational
target is reached, at Block 77. Here again, this may be based upon
an amount of time solvent is injected, a quantity of solvent
injected, etc. Once the target is reached, then solvent injection
may be stopped (e.g., by shutting off the solvent source 41) and
oil production resumed (e.g., by turning back on the recovery pump
40), at Blocks 78-79. Here again, production continues until the
desired operational target is reached for the current cycle, at
Block 80.
[0034] Numerous injection/production cycles may then be run (i.e.,
Blocks 76-79) until an overall recovery target is reached for the
formation 31, at Block 81. Different operational considerations may
be applicable depending upon the geographical region of operation,
the geological formation, etc., as will be appreciated by those
skilled in the art. By way of example, 20-100 cycles may be
appropriate depending upon the particular geological area where
production occurs, although different numbers of cycles may be used
in different embodiments. Solvent injection and/or RF heating may
be suspended, at Block 82, and a final production phase performed
(Block 83) until the oil rate falls below a minimum recovery rate,
at Block 84. At this point oil production is discontinued, and the
solvent may be recovered from the formation 31, if desired, at
Block 85. This concludes the method illustrated in FIGS. 3A-3B, at
Block 86.
[0035] In some embodiments, it may be advantageous to continuously
apply RF heating throughout the cyclical process. The RF heating
extends the production period and thereby increases the aggregate
oil rate by refluxing a portion of the solvent in the bitumen
draining to the lower well 33. As the mixture approaches the
producer it is heated from the RF heating, which causes some of the
solvent to flash off. The liberated solvent vapor is available to
support the vapor chamber pressure, and it migrates to the vapor
chamber boundary where it is once again diffused into raw bitumen,
diluting it and reducing the viscosity so that it drains to the
lower well 33 by gravity. This reflux reduces the amount of makeup
solvent required, which permits longer production and shorter
injection cycles, respectively. This is unlike traditional
processes like cyclic steam (e.g., SAGD) where the injected fluid
also supplies the heat and pressure support to the reservoir. Once
the steam injection phase is complete the chamber pressure
immediately begins to decrease as the steam cools and condenses to
liquid, resulting in relatively shorter production cycles. In some
embodiments, further pressure control may also be achieved by
introducing additional gas (e.g., an inert gas such as nitrogen)
into the void 42 along with the solvent in some embodiments.
[0036] Referring additionally to the graph 50 of FIG. 4, a
comparison of cumulative oil production over time for a simulated
example using the apparatus 30 and the cyclic recovery approach
described above is represented by the dashed plot line 51. By way
of comparison, a plot line 52 represents simulated oil production
using the above-noted approach set forth in U.S. Pat. No.
9,739,126, i.e., where solvent injection occurs from the same upper
well where the antenna is located. While the simulated results from
the '126 patent approach provide slightly higher output over the
same time period, the output from the present approach is
comparable, yet the present approach advantageously allows for
smaller (i.e., standard) size well casings and a potential for
reduced solvent injection, and, accordingly, lower operating
costs.
[0037] Turning now to the flow diagram 90 of FIG. 5, another
example operating method for the apparatus 30 is described.
Beginning at Block 91, the method illustratively includes
pre-heating the formation 31 from the upper well 32 to a target
temperature, and then oil production begins to create the void 42
within the formation, as described above (Blocks 92-94). However,
rather than ceasing production at this point as described above,
production (and optionally RF heating) continues and solvent
injection commences from the lower well, at Block 95. This process
may then continue until the overall recovery target for the well is
reached, at Block 96. At this point, solvent injection and/or RF
heating are suspended (Block 97) while an optional final production
occurs until the oil recovery rate falls below a minimum level, at
which point production is discontinued and the solvent optionally
recovered, at Blocks 98-100, as discussed above. The method of FIG.
5 illustratively concludes at Block 101. It should be noted that in
some embodiments, a combination of sequential operation and
continuous operation may be performed, if desired.
[0038] Further details of recovering or producing hydrocarbon
resources may be found in U.S. Pat. Nos. 9,044,731; 9,057,237;
9,200,506; 9,103,205; and U.S. Pub. Nos. 2014/0014324 and
2014/0014326, which are all assigned the Assignee of the present
application, and the entire contents of which are herein
incorporated by reference. Many modifications and other embodiments
of the invention will come to the mind of one skilled in the art
having the benefit of the teachings presented in the foregoing
descriptions and the associated drawings. Therefore, it is
understood that the invention is not to be limited to the specific
embodiments disclosed, and that modifications and embodiments are
intended to be included within the scope of the appended
claims.
* * * * *