U.S. patent application number 12/722283 was filed with the patent office on 2010-07-01 for stimulation and recovery of heavy hydrocarbon fluids.
This patent application is currently assigned to HW ADVANCED TECHNOLOGIES, INC.. Invention is credited to Allan Provost, James Tranquilla.
Application Number | 20100163227 12/722283 |
Document ID | / |
Family ID | 39223689 |
Filed Date | 2010-07-01 |
United States Patent
Application |
20100163227 |
Kind Code |
A1 |
Tranquilla; James ; et
al. |
July 1, 2010 |
STIMULATION AND RECOVERY OF HEAVY HYDROCARBON FLUIDS
Abstract
The present invention is directed to the use of electromagnetic
radiation, acoustic energy, and surfactant injection to recover
hydrocarbon-containing materials from a hydrocarbon-bearing
formation.
Inventors: |
Tranquilla; James; (New
Brunswick, CA) ; Provost; Allan; (Lakewood,
CO) |
Correspondence
Address: |
SHERIDAN ROSS PC
1560 BROADWAY, SUITE 1200
DENVER
CO
80202
US
|
Assignee: |
HW ADVANCED TECHNOLOGIES,
INC.
Lakewood
CO
|
Family ID: |
39223689 |
Appl. No.: |
12/722283 |
Filed: |
March 11, 2010 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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11682171 |
Mar 5, 2007 |
7677673 |
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12722283 |
|
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60827012 |
Sep 26, 2006 |
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60867537 |
Nov 28, 2006 |
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Current U.S.
Class: |
166/270.1 ;
166/177.1 |
Current CPC
Class: |
E21B 43/003 20130101;
E21B 43/2401 20130101 |
Class at
Publication: |
166/270.1 ;
166/177.1 |
International
Class: |
E21B 43/22 20060101
E21B043/22; E21B 28/00 20060101 E21B028/00 |
Claims
1. A method for recovering a subterranean hydrocarbon-containing
material, comprising: (a) from a manned underground excavation
emitting, from an emitter, radiation in at least one of the
electromagnetic and acoustic energy ranges into a selected region
of a subterranean hydrocarbon-bearing formation, to lower a
viscosity of a hydrocarbon-containing material in the selected
region, the emitter positioned in the excavation being at least one
of (i) in direct physical contact with the formation, (ii) for
electromagnetic energy, in contact with an impedance transformer,
the transformer being, in direct physical contact with the
formation and (iii) for acoustic energy, a transducing medium, the
transducing medium being in direct physical contact with the
formation; and (b) recovering, by a production well in proximity to
the selected region, the irradiated hydrocarbon-containing
material.
2. The method of claim 1, wherein the radiation is microwave
radiation, wherein the microwave radiation is emitted by a
waveguide running a length of the excavation, and wherein at least
a portion of the production well is positioned below the selected
region.
3. The method of claim 1, wherein the at least one emitter is in
contact with an impedance transformer, the impedance transformer
being in direct physical contact with the formation.
4. The method of claim 1, wherein the radiation is acoustic energy,
and wherein the impedance transformer is a transducing medium,
through which the acoustic energy passes, and wherein the
transducing medium is in direct physical contact with the
formation.
5. The method of claim 4, further comprising: (c) introducing a
surfactant into the selected region before and/or during step
(a).
6. The method of claim 1, wherein the excavation follows generally
at least one of a strike and dip of the formation.
7. The method of claim 4, wherein the acoustic energy has a
frequency in the ultrasonic band.
8. A method for recovering a subterranean hydrocarbon-containing
material, comprising: (a) introducing a surfactant into a selected
region of a subterranean hydrocarbon-bearing formation; (b) from an
underground excavation, emitting acoustic energy into the selected
region to lower a viscosity of a hydrocarbon-containing material in
the selected region, wherein the underground excavation has a
dimension normal to a heading of the excavation of at least about
four feet; and (c) recovering, by a production well in proximity to
the selected region, the hydrocarbon-containing material.
9. The method of claim 8, wherein the acoustic energy has a
frequency in the ultrasonic spectrum, wherein the acoustic energy
is emitted by an emitter positioned in the underground excavation,
and wherein the emitter is one of in contact with and proximal to
the formation.
10. The method of claim 9, further comprising before step (c): (d)
from the underground excavation, emitting electromagnetic energy
into the selected region.
11. A method for recovering hydrocarbon-containing materials,
comprising: (a) introducing a surfactant into a selected region of
a hydrocarbon-bearing formation, the formation comprising at least
one hydrocarbon-containing material; (b) while the surfactant is in
the selected region, passing acoustic energy through the selected
region of the formation; (c) passing electromagnetic radiation
through the selected region of the formation; and (d) thereafter
recovering the at least one hydrocarbon-containing material.
12. The method of claim 11, wherein the acoustic energy has a
frequency in the ultrasonic spectrum and wherein the
electromagnetic radiation has a frequency in the microwave
band.
13. The method of claim 12, wherein the electromagnetic radiation
is emitted by a waveguide positioned in an underground excavation
positioned in or proximal to the formation and wherein the
underground excavation has a dimension normal to a heading of the
excavation of at least about four feet.
14. A system for recovering hydrocarbon-containing materials,
comprising: (a) a hydrocarbon-bearing formation comprising a
hydrocarbon-containing material; (b) an underground excavation; (c)
in the underground excavation, at least one electromagnetic
radiation emitter to direct radiation into the formation; and (d)
in the underground excavation, at least one acoustic energy emitter
to direct acoustic energy into the formation.
15. The system of claim 14, wherein the underground excavation is
lined by a liner, wherein the underground excavation has a
dimension normal to a heading of the excavation of at least about
four feet, and wherein the liner comprises a passage for the
electromagnetic emitter and/or an impedance transformer in contact
therewith to contact physically the formation.
16. The system of claim 14, wherein the underground excavation is
lined by a liner, wherein the underground excavation has a
dimension normal to a heading of the excavation of at least about
four feet, and wherein the liner comprises a passage for the
acoustic energy emitter and/or an transducing medium in contact
therewith to contact physically the formation.
17. The system of claim 14, further comprising: (e) a production
well, at least a portion of which is positioned below the
formation.
18. The system of claim 17, wherein the at least a portion of the
production well is generally parallel to a heading of the
excavation.
19. The system of claim 18, wherein the at least a portion of the
production well is substantially horizontal.
20. The system of claim 14, further comprising: (e) a plurality of
sensors positioned at different locations in the formation; and (f)
a computer operable to receive signals from the sensors and, in
response thereto, control operation of the at least one of the
electromagnetic radiation emitter and acoustic energy emitter.
Description
CROSS REFERENCE TO RELATED APPLICATION
[0001] The present application claims the benefits of U.S.
Provisional Application Ser. No. 60/827,012, filed Sep. 26, 2006,
entitled "Means for the Stimulation and Recovery of Heavy
Hydrocarbon Fluids", and 60/867,537, filed Nov. 28, 2006, of the
same title, each of which are incorporated herein by this
reference.
FIELD OF THE INVENTION
[0002] The invention relates generally to recovery of hydrocarbon
fluids and particularly to the in situ thermal stimulation and
recovery of hydrocarbon fluids.
BACKGROUND OF THE INVENTION
[0003] Heavy and extra heavy oil and bitumen represent the largest
deposit types of recoverable hydrocarbons in the world. As an
example, the proven, recoverable heavy oil reserves (including oil
sands) in Alberta, Canada are greater that all of the light oil
reserves of the Middle East. As used herein, heavy and extra heavy
oil refers to a hydrocarbon-containing material having an American
Petroleum Institute ("API") gravity, or specific gravity, of no
more than about 22.5.degree. API, and bitumen to a
hydrocarbon-containing material having an API gravity of no more
than about 10.degree. API. By way of comparison, light crude oil is
defined as having an API gravity higher than about 31.1.degree.
API, and medium oil as having an API gravity between about
22.3.degree. API and 31.1.degree. API. Bitumen will not flow at
normal temperatures, or without dilution, and is "upgraded"
normally to an API gravity of 31.degree. API to 33.degree. API. The
upgraded oil is known as synthetic oil.
[0004] To recover heavy oil and bitumen, its viscosity is reduced.
In one common commercial method of recovering heavy oil and
bitumen, steam is injected under pressure into the oil-bearing
formation. The steam heats up the formation, including the oil
and/or bitumen, causing it to flow under the force of the steam
(and other fluid(s)) pressure to a recovery well where it is pumped
to the surface for refining. In one steam-assisted technique, known
as SAGD, or Steam Assisted Gravity Drainage, steam is used to heat
the oil which then flows downward (under the force of fluid
pressure and gravity) to horizontal recovery wells placed beneath
the oil formation. Another heavy oil recovery method ignites
injected gas to create a high temperature, high pressure firefront
which sweeps through the oil formation, pushing some of the oil
ahead of it. In other heavy oil recovery methods, various forms of
fluid injection (such as carbon dioxide, water, steam, surfactants
(which reduce the viscosity of the fluid layer between the oil and
the ground formation), alkaline chemicals, polymers, etc.) are
performed.
[0005] The use of electromagnetic energy (usually electrical or
Radio Frequency or RF) to heat the heavy oil formation has been
known for several years. This technology was introduced during the
1970s when there was widespread interest in exploiting oil shale
reserves. There have been several variations of this technology,
ranging from relatively low frequency through radio frequency and
microwaves. These have included multi-probe "closed" field heating
arrangements, single probe heating arrangements, and radiating
configurations.
[0006] By way of example, U.S. Pat. No. 2,799,641 to Bell discloses
a method for production enhancement through electrolytic means
whereby a direct electrical current causes oil flow through
electro-osmosis. Another electro-osmosis technique is disclosed in
U.S. Pat. No. 4,466,484 to Kermabon. Other disclosures (for example
U.S. Pat. No. 3,507,330 to Gill, U.S. Pat. No. 3,874,450 to Kern,
and U.S. Pat. No. 4,084,638 to Whitting) describe attempts to heat
the near-wellbore region as well as more distant parts of the
reservoir by electrical methods.
[0007] Kasevich in U.S. Pat. No. 4,301,865 disclosed the use of an
underground array of RF emitting rods, which enclose a defined
volume that is to be heated. The array is used specifically for the
recovery of oil shale kerogen.
[0008] Bridges, et al., in U.S. Pat. Nos. 4,140,180; 4,144,935;
4,790,375; 5,293,936; 5,621,844; 4,485,868; and 5,713,415, disclose
arrangements of underground RF heating elements and associated
transformer and cable equipment, all applicable to volumetric
heating of a closely defined space at or near the production
well.
[0009] Elligsen, in U.S. Pat. No. 6,499,536, suggests the injection
of RF absorbent materials in the well region as a means of
enhancing the local heating effect.
[0010] Yuan, in U.S. Pat. No. 6,631,761, suggests the use of
electrode configurations around the well as a means of further
controlling the heating effect in conjunction with RF probes, such
as those suggested by Bridges, et al.
[0011] Both Haagensen, in U.S. Pat. No. 4,620,593, and Jeambey, in
U.S. Pat. No. 4,912,971, propose true underground antennas for RF
(and microwave) heating. Haagensen further proposes a modified
waveguide to be placed within the well casing. The waveguide,
however, at the only available, relevant microwave frequency is
still far too large to fit within any standard well casing.
[0012] U.S. Pat. No. 5,109,927 to Supernaw describes the use of a
hypothetical directional antenna to direct energy selectively at
the bottom region of a production zone to improve steam
recovery.
[0013] In general, RF thermal stimulation techniques have
encountered several pitfalls. These pitfalls include localized
charring around the heating probes, limited field penetration,
electrical downhole component failure, and the like. These pitfalls
have led to improvements in electrical components as well as
attempts to create a more uniform energy distribution throughout
the heating zone.
[0014] The use of acoustic energy to stimulate heavy oil recovery
has been known for a considerably long time. U.S. Pat. No.
3,378,075 to Bodine and U.S. Pat. No. 4,437,518 to Williams
describe the use of sonic transmitters as a means of stimulating
oil well production. U.S. Pat. No. 2,670,801 to Sherborne is one of
the earliest disclosures of the use of sonic energy for this
purpose. Wesley, in U.S. Pat. No. 4,345,650, further discloses the
use of an explosive, ablative, electric spark as a means of
generating a high-intensity acoustic wave at or near a subsurface
oil formation to stimulate oil production.
[0015] More recently, U.S. Pat. Nos. 6,186,228 and 6,279,653 to
Wegener, et al., disclose the use of electro-acoustic transmitters
inside a wellbore to improve oil production from an oil-bearing
formation. U.S. Pat. Nos. 6,227,293 and 6,427,774 to Huffman, et
al., and Thomas, et al., respectively, describe a means of
generating coupled electromagnetic and acoustic pulses to stimulate
oil production at much greater distances from the wellbore than was
previously possible using direct acoustic generation within the
wellbore. It is speculative if the electromagnetic pulse so
generated could retain appreciable power density at the extended
distances exceeding 6,000 feet. Meyer, et al., in U.S. Pat. No.
6,405,796, teaches the use of acoustic stimulation near the
acoustic slow wave frequency in conjunction with fluid injection
displacement as a means of stimulating oil flow. Abramov, et al.,
in U.S. Pat. No. 7,059,413, describe the use of a high intensity
ultrasonic field near the bottom of the wellbore to generate heat
and directly reduce the oil viscosity. This technique uses high
frequency electrical heating of the well casing to maintain the oil
at a relatively low viscosity.
[0016] Prior art techniques can have drawbacks.
[0017] The prior art techniques commonly use one or more
stimulation techniques in conjunction with one or more wellbores
drilled from the ground surface to intersect at least one
oil-bearing stratum in a subterranean oil-bearing formation. The
vertical string introduces several natural barriers which prevent
the techniques from being commercially practical or at least
introduces a large measure of additional cost or engineering
difficulty related to energy loss and the necessity to locate the
electrical equipment on the surface of the ground above the oil
formation from where the energy must then be transmitted down a
drill hole to access the oil formation. The barriers include
inaccessibility of the stimulation device(s) after being placed,
well completion at the surface and downhole end, operational
unreliability of the stimulation device(s) and repair difficulties
from location of the device(s) in the well casing, difficulty in
keeping potentially harmful and/or flammable liquids from the
device(s), well casing incompatibility with the stimulation
actuators, creation of a means at the bottom of the drill casing
whereby the energy can be transferred into the formation, and
inability to recover the installed hardware. In particular, the
limited size of standard drill casings, as well as the prohibitive
cost of oversize casings, greatly restrict the size and complexity
of components which can be reliably placed therein.
[0018] Prior art techniques seek to thermally stimulate the entire
reservoir at one time followed by production from the entire
reservoir over a period of up to five or ten years. To accomplish
this, the entire reservoir must be thermally stimulated
periodically over the production life of the reservoir. The unit of
thermal energy required to produce a barrel of
hydrocarbon-containing material can be relatively high. Moreover,
heat can be lost heating up country rock and groundwater in
proximity to the reservoir.
[0019] Many prior art techniques use vertical, rather than
horizontal, hydrocarbon removal from the reservoir, along a
typically long wellbore. Vertical hydrocarbon removal can raise
recovery costs and lower recovery of hydrocarbons due to the
pumping pressure and/or drive pressure (such as from steam
introduced into the reservoir) required to overcome the effect of
gravity.
[0020] Prior art techniques are generally unable to recover more
than approximately 20% of the heavy oil in place, resulting in an
overall inefficiency and loss of resource potential.
SUMMARY OF THE INVENTION
[0021] These and other needs are addressed by the various
embodiments and configurations of the present invention. The
present invention is directed to methods and systems for recovering
hydrocarbon-containing materials, particularly heavy oil, bitumen,
and kerogen, from subterranean formations. As used herein, a
"hydrocarbon" is formed exclusively of the elements carbon and
hydrogen. Hydrocarbons are derived principally from
hydrocarbon-containing materials, such as oil. Hydrocarbons are of
two primary types, namely aliphatic (straight-chain) and cyclic
(closed ring). Hydrocarbon-containing materials include any
material containing hydrocarbons, such as heavy oil, bitumen, and
kerogen.
[0022] In one embodiment, a method for recovering a subterranean
hydrocarbon-containing material is provided. The method includes
the steps of:
[0023] (a) from a manned underground excavation in spatial
proximity to a subterranean hydrocarbon-bearing formation, emitting
radiation into a selected region of the formation to lower a
viscosity of a hydrocarbon-containing material in the selected
region; and
[0024] (b) recovering, by a production well in proximity to the
selected region, the irradiated hydrocarbon-containing
material.
[0025] A "manned excavation" refers to an excavation that is
accessible directly by personnel. In other words, the radiation
emitters can be installed, accessed after installation, and removed
by workers without the need of downhole devices, such as wireline
devices. A typical manned excavation has at least one dimension
normal to the excavation heading that is at least about 4 feet.
[0026] In one embodiment, the radiation has multiple, disparate
wavelengths to provide synergistic viscosity effects. For example,
one or more wavelengths are in the electromagnetic wavelength
range, with microwave wavelengths being preferred, and one or more
other wavelengths are in the acoustic energy range, with ultrasonic
and supersonic wavelengths being preferred. Surfactants can be
introduced into the hydrocarbon-bearing formation, in temporal
proximity to radiation emission, to further decrease the viscosity
of the hydrocarbon-containing material. As will be appreciated, a
"surfactant" is a surface-active agent. The amount of surfactant
needed to realize a desired degree of viscosity reduction is
reduced synergistically by the application of acoustic energy to
the formation.
[0027] The electromagnetic energy can heat the portion of the
hydrocarbon-bearing formation beneath the waveguide assembly. The
use of two parallel waveguide assemblies, for example, can make it
possible to "sweep" the electromagnetic beam laterally so as to
include a wider portion of the formation within the heated zone.
The intent is not to heat the entire oil formation, as in other
stimulation techniques, but to rapidly heat only a limited region
within the formation.
[0028] The injected surfactant can provide a chemical accelerant
which can reduce the surface bonding between the
hydrocarbon-bearing material and the formation matrix material,
which normally consists of sand and clay.
[0029] The ultrasonic transmitter can introduce high energy
acoustic waves into the heated zone, which includes oil mixed with
connate water and the injected surfactant within the formation
matrix. The ultrasonic waves act to rapidly disperse the liquid
surfactant and connate water and greatly reduce the viscosity of
the heated oil directly at the interface between the oil and sand
particles, thus causing the oil to flow more quickly through the
formation matrix.
[0030] The overall result of the combination of these stimulation
techniques is to cause a large fraction of the hydrocarbon-bearing
material within the heated zone to migrate downward under the force
of gravity for collection by a horizontal production well located
immediately beneath the oil formation.
[0031] Through the techniques of the invention, substantial
reductions in viscosity can be realized. Typically, the viscosity
of the hydrocarbon-containing material, particularly heavy oil,
bitumen, and kerogen, is reduced by at least about 200%, more
typically by at least about 300%, and even more typically by at
least about 350%. By way of example, the viscosity of the heavy
oil, bitumen, and kerogen is reduced typically from a first
viscosity of at least about 20,000 Cp to a second viscosity of no
more than about 10 Cp.
[0032] Other advantages can also be realized by the present
invention depending on the particular configuration. The invention
can provide direct human access to the hydrocarbon-bearing
formation, thereby removing the obstacles related to the downhole
drill string. These obstacles include inaccessibility of the
stimulation device(s) after being placed, well completion at the
surface and downhole end, operational unreliability of the
stimulation device(s) and repair difficulties from location of the
device(s) in the well casing, difficulty in keeping potentially
harmful and/or flammable liquids from the device(s), well casing
incompatibility with the stimulation actuators, creation of a means
at the bottom of the drill casing whereby the energy can be
transferred into the formation, and inability to recover the
installed hardware. This is made possible by using economical,
modern tunneling technology, which, in turn, allows the
introduction of much more reliable and efficient electromagnetic
and acoustic stimulation techniques directly into the oil
formation. The ability to access directly the formation can permit
the various radiation emitters to be positioned manually and
operated to provide a substantially uniform energy distribution
throughout the selected region of the formation to be heated. The
use of manned excavations, can remove limitations in conventional
methods imposed on component size and complexity by the limited
size of standard drill casings and the prohibitive cost of oversize
casings. The invention normally does not seek to stimulate
thermally the entire reservoir at one time. Rather, it stimulates
preferentially only selected portions of the formation at one time,
followed by production from that portion of the formation. Such
selective stimulation can reduce, relative to conventional
stimulation techniques, the energy required to produce a barrel of
hydrocarbon-containing material. Unlike prior art techniques which
use vertical, rather than horizontal, hydrocarbon removal from the
reservoir, along a typically long wellbore, the invention can use,
for hydrocarbon collection, a horizontal wellbore positioned in or
below the hydrocarbon-bearing formation. Relative to conventional
techniques, such horizontal removal can lower recovery costs and
increase recovery of hydrocarbons. Finally, the invention can
recover substantially, and normally several times, more than the
approximately 20% of the heavy oil in place being recovered by
conventional techniques.
[0033] These and other advantages will be apparent from the
disclosure of the invention(s) contained herein.
[0034] As used herein, "at least one", "one or more", and "and/or"
are open-ended expressions that are both conjunctive and
disjunctive in operation. For example, each of the expressions "at
least one of A, B and C", "at least one of A, B, or C", "one or
more of A, B, and C", "one or more of A, B, or C" and "A, B, and/or
C" means A alone, B alone, C alone, A and B together, A and C
together, B and C together, or A, B and C together.
[0035] It is to be noted that the term "a" or "an" entity refers to
one or more of that entity. As such, the terms "a" (or "an"), "one
or more" and "at least one" can be used interchangeably herein. It
is also to be noted that the terms "comprising", "including", and
"having" can be used interchangeably.
[0036] The above-described embodiments and configurations are
neither complete nor exhaustive. As will be appreciated, other
embodiments of the invention are possible utilizing, alone or in
combination, one or more of the features set forth above or
described in detail below.
BRIEF DESCRIPTION OF THE DRAWINGS
[0037] FIG. 1 is a cross-sectional side view taken along line 2-2
of FIG. 2 of an in situ hydrocarbon stimulation and production
system according to an embodiment of the present invention;
[0038] FIG. 2 is a cross-sectional front view taken along line 1-1
of FIG. 1 of the an in situ hydrocarbon stimulation and production
system of FIG. 1;
[0039] FIG. 3 is a cross-sectional front view of multiple
underground excavations according to an embodiment of the present
invention;
[0040] FIG. 4 shows the simulated production performance of a
microwave stimulated Cold Lake reservoir, single 100 kW injector
with vertical production
[0041] FIGS. 5A and 5B show the simulated production performance of
a microwave stimulated Cold Lake reservoir, single 100 kW injector
with horizontal production; and
[0042] FIG. 6 shows the simulated production performance of a
microwave stimulated Cold Lake reservoir, with four 25 kW injectors
with horizontal production.
DETAILED DESCRIPTION
[0043] In a preferred embodiment, in situ stimulation of a
hydrocarbon-containing material, particularly heavy oil (otherwise
known as low-API oil), is provided that includes the following
operations: [0044] 1. Excavating a subterranean tunnel in or in
proximity to the upper boundary of a hydrocarbon-bearing stratum or
formation; [0045] 2. Placing one or more microwave waveguides
disposed longitudinally along the bottom, side(s), and or top of
said tunnel such that a face of the waveguide is in contact, either
directly or indirectly, with the hydrocarbon-bearing formation;
[0046] 3. Incorporating radiating slots or fixtures into the lower
face of the waveguide; [0047] 4. Incorporating a medium material,
or impedance transformer, between the waveguide and
hydrocarbon-bearing formation to transfer efficiently microwave
energy from the waveguide into the formation; [0048] 5. Energizing
the waveguide using microwave energy in the frequency band from
about 100 MHz to about 3000 MHz to heat locally a selected portion
of the hydrocarbon-bearing formation in proximity to the said
waveguide arrangement; [0049] 6. Inserting ultrasonic transmitters
into the hydrocarbon-bearing formation along the bottom of the
tunnel in proximity to the waveguide, the ultrasonic transmitters
operating in the frequency band of from about 10 kHz to about 40
kHz; [0050] 7. Injecting, under high pressure, a surfactant (or
similar surface tension adjusting) fluid into the
hydrocarbon-bearing formation along the bottom of the tunnel;
[0051] 8. Placing one or more recovery wells disposed substantially
horizontally along the bottom boundary of the hydrocarbon-bearing
formation and disposed substantially parallel to the tunnel; [0052]
9. Extracting the produced fluid(s), including the stimulated
hydrocarbon-containing materials, connate water and surfactant
fluids, using the recovery well; and [0053] 10. Making the
extracted fluids available at the surface of the ground for
treatment to separate at least most, and more preferably
substantially all, of the extracted hydrocarbon-containing
materials and to produce water suitable for subsequent treatment or
use.
[0054] Many of the world's heavy oil deposits are located at
relatively shallow depths (less than 2,000 feet) while others are
much deeper. Shallow formations are problematic for conventional
water flooding and steam injection stimulation production owing to
poor ground competence and fracturing and channeling, all of which
result in a very low net oil recovery. At greater depths, hot fluid
injection techniques must suffer high energy losses on the downhole
passage and other stimulation techniques, such as electrical and
acoustic stimulation, are disadvantaged by power losses in
connecting cables, breakage of cables, and actuator units,
including electrical components, difficulty in precise placement
and frequent inability to recover hardware.
[0055] In both the shallow and deep formation scenarios, nearly all
of the attendant engineering and production difficulties can be
eliminated if direct access can be gained to the
hydrocarbon-bearing formation. Accordingly, the present invention
creates an underground excavation, such as a tunnel, to provide
access to the hydrocarbon-bearing formation from the ground
surface. The excavation enables formation stimulation to
substantially the entire hydrocarbon-bearing formation region of
interest and, in doing so, enables a high net recovery of
hydrocarbon-containing materials from the region, thereby depleting
substantially the formation region. The excavation, in conjunction
with the stimulation techniques disclosed herein, enables the
sequential and systematic drainage of the hydrocarbon-bearing
formation, section-by-section, without the need to stimulate
simultaneously the entire formation region as is the case with
other stimulation methods. Because of the relative inability of the
natural high-viscosity hydrocarbon-containing materials to flow
freely throughout the formation, there is little opportunity for
the untapped hydrocarbon-containing materials in one region to
backflow into an adjacent depleted region. Hydrocarbon recovery is,
in one configuration, by means of a directionally drilled
horizontal well placed at or near the bottom of the
hydrocarbon-bearing formation "pay zone" and which essentially
follows the tunnel direction.
[0056] As can be appreciated, the present invention is entirely
compatible with conventional, surface-mounted, enhanced drive
processes, such as gas injection, for the purpose of driving the
liberated oil downward toward the producing well.
[0057] Referring now to FIGS. 1-2, a stimulation and recovery
system according to the preferred embodiment will now be described.
The system is described in the context of a subterranean
hydrocarbon-bearing formation 100, overlain by country or native
rock 104. the formation 100 is normally relatively thin, being only
a few feet thick, and may comprise several closely spaced
zones.
[0058] The system 108 includes a lined access excavation 112, a
lined stimulation excavation 116, an electromagnetic radiation
generation, transmission, and irradiation assembly 120 extending a
length of the stimulation excavation 116, surfactant injection
wells 124a-c positioned at intervals along the length of the
excavation 116, and acoustic energy emitters 128a-c also positioned
at intervals along the length of the excavation 116.
[0059] The lined access excavation 112 may be any suitable
excavation providing access from the surface 132. Examples include
shafts, declines, and inclines.
[0060] The lined stimulation excavation 116 extends from the lined
access excavation 112, is substantially sealed from fluids in the
surrounding formations, and can be any suitable excavation that
generally follows the strike and/or dip of the hydrocarbon-bearing
formation 100. Examples of suitable excavations 116 include
tunnels, stopes, adits, and winzes. The excavation 116 may be
positioned above (as shown), in, or below the hydrocarbon-bearing
formation 100. Preferably, the excavation 116 is placed along the
top of the formation 100 so that the formation 100 is directly
accessible at the excavation floor. The excavation is typically
relatively small (e.g., from about 4 to about 15 feet and more
typically from about 6 to about 8 feet in diameter), is lined with
a liner such as concrete or cement, and is suitably reinforced and
fitted with apertures in the liner to expose the formation 100 to
radiation emitters.
[0061] The electromagnetic radiation generation, transmission, and
irradiation assembly 120 imparts one or more selected wavelength
bands of electromagnetic radiation to a selected portion or region
of the hydrocarbon-bearing formation 100. As will be appreciated,
the higher the frequency of the electromagnetic radiation the
higher the attenuation and lower the penetration depth in the
formation, and the lower the frequency the lower the attenuation
and higher the penetration depth in the formation. The frequency of
the radiation preferably ranges from about Direct Current (DC) to
about 10 GHz, more preferably in a power frequency band of from
about DC to about 60 Hz Alternating Current (AC), in the short wave
band of from about 100 kHz to about 100 MHz, and/or in the
microwave band of from about 100 MHz to about 10 GHz, with the
microwave band in the range of from about 100 MHz to about 3 GHz
being particularly preferred.
[0062] When the radiation is in the microwave band, the assembly
120 includes a waveguide 136 having multiple, regularly spaced
antenna or radiating elements 140a-k, a generator 144, and tuner
148. The waveguide 136 can have any suitable configuration for the
set of radiation frequencies to be transported by the waveguide
136. For example, an exemplary waveguide could include a metal
cylinder having any desired cross sectional shape, which is
commonly rectangular. Likewise, the particular configuration of the
antenna elements depends on the particular set of radiation
frequencies to be emitted. For example, each element can be
configured as a resonant slot. In one configuration, the emitted
electromagnetic radiation (shown as arcs emanating from each
element 140) is a set of different frequencies having differing
penetration depths into the formation to heat the formation to
differing degrees. As will be appreciated, lower frequencies travel
with less attenuation than higher frequencies in the formation. The
generator 144 can be any suitable generating device, such as a
magnetron or klystron. Finally, the tuner 148 can be any suitable
tuning device to provide propagation characteristics in the
waveguide that reduce substantially, or minimize, reflected
electromagnetic radiation. The tuner 148, for example, may be a
tunable dielectric material, such as a thin or thick film or bulk
ferrite, ferromagnetic, or non-ferrous metallic material.
[0063] Each of the antenna elements 140a-k has a corresponding
impedance transformer 152a-k positioned in the excavation liner to
match the waveguide field impedance to the impedance of the
formation 100 and couple the electromagnetic radiation to the
adjacent formation. Because the formation 100 is directly
accessible through the liner of the excavation, there is no need to
drill holes for placement of the antenna elements within the
formation, as is the case with all other RF or microwave
stimulation methods. Furthermore, the assembly 120 is completely
removable at the completion of the stimulation process.
[0064] Although any suitable impedance matching material or
materials may be used, a preferred impedance transformer 152a-k is
a "pillow" block of a special material, such as a ceramic material,
that interfaces between the waveguide and the formation 100. The
principal property of the impedance transformer is its intrinsic
impedance, which must be designed to fall at approximately the
average value of the two impedances being "matched", in this case
the typically air-filled waveguide (having an intrinsic impedance
of about 377 ohms) and the formation 100 whose intrinsic impedance
is given by:
.eta.= (j.omega..mu.)/(.sigma.+j.omega..di-elect cons.)=
where [0065] .omega.=2.pi.f is the radian frequency [0066] f=915
MHz [0067] .mu.=permeability of free space [0068] .sigma.=0.001 is
the medium conductivity [0069] .di-elect
cons.=(20-j0.45).times.8.854.times.10.sup.-12 is the medium
permittivity
[0070] The permittivity value is dependent on temperature,
frequency, and the relative soil/water ratio, which, for a typical
heavy oil formation, yields an impedance of approximately 80 ohms.
A preferable transformer therefore has a stepped or graded
impedance from about 377 ohms to about 80 ohms. Alternatively, the
impedance transformation may be incorporated into the antenna
element by designing the radiating slots in the waveguide to have a
low near-field impedance, i.e., a ratio of electric to magnetic
field magnitudes of the order of about 80. In this manner, the
electromagnetic energy may be coupled efficiently to the formation
100.
[0071] The antenna elements 140a-k preferably intermittently emit
radiation into the hydrocarbon-bearing formation. Beam steering or
scanning techniques may be employed to direct the radiation into
selected areas but not in others and/or to direct differing amounts
of radiation into differing areas. By way of example, rather than
irradiating in a 180 degree arc as shown beam steering may be used
to irradiate in a 90 degree arc. In another example, the radiation
may be beam steered so that it emanates from the antenna element in
the same manner as a windshield wiper moving across a car's
windshield.
[0072] As will be appreciated, a system of sensors (not shown)
embedded in the hydrocarbon-bearing formation 100 and computer (not
shown) can be used to control generation and emission of
electromagnetic radiation from the assembly 120. The computer
receives control feedback signals from an interface that is
connected to telemetering lines (not shown). The telemetering lines
are in turn connected to the sensors. Each sensor monitors the
amount of radiation reaching the underground location where that
sensor is located and/or the formation temperature at that
location. Preferably, the formation temperature in the selected
formation region is maintained from about 200 to about 350 degrees
Celsius and even more preferably from about 250 to about 300
degrees Celsius. At these temperatures, the heavy oil and bitumen
normally has a viscosity of no more than about 10 Cp and even more
normally of from about 1 to about 5 Cp.
[0073] In one operational configuration, the generator 144 is
turned on and off to emit radiation into the formation 100 only
during selected, discrete time periods. The time periods may of
uniform length or differing lengths depending on the application.
It is believed that intermittent irradiation of the selected region
of the formation 100 can produce a flow of hydrocarbon-containing
material that is greater than that produced by continuous
irradiation of the region. Intermittent irradiation of the deposit
further represents a lower consumption of thermal energy to recover
a selected volume of hydrocarbon-containing material and prevents
overheating near the antenna elements, thereby allowing the
deposited heat energy to dissipate through the selected formation
region and making maximum use of the available microwave power.
[0074] In one operational configuration, the radiation is emitted,
at least initially, at incrementally increasing radiation power. As
in the prior embodiment, the radiation may be emitted
intermittently.
[0075] In one operational configuration, alternate sets of antenna
elements are energized at different times. In other words, a first
set of antenna elements are energized at a first time while a
second set of antenna elements are energized at a second, normally
nonoverlapping, time. This permits the emitted microwave energy to
affect a larger portion of the formation and allows the heat to
dissipate into the formation between alternating cycles.
[0076] The action of the radiated electromagnetic radiation heats
the fluids within the formation 100 (water and asphaltenes are good
receptors), thereby substantially reducing fluid viscosity. For a
single waveguide, the affected heated region will be the angular
bandwidth directly beneath the waveguide, being approximately +/-60
degrees from the vertical (normal) direction. Given the relatively
small thickness of the typical formation "pay zone", the use of
microwave frequencies is beneficial since there is no need to
transmit high power densities over long distances as is the case
with all other RF and microwave heating techniques. This makes it
possible to take advantage of the high absorption of receptive oil
and water molecules at these frequencies.
[0077] The surfactant injection wells 124a-c introduce, under
pressure (via pump 200), an aqueous solution including one or more
surfactants into the formation 100. The primary purpose of the
aqueous fluid is not to effect a bulk fluid displacement of the
hydrocarbon-containing material but rather, in synergistic
combination with the acoustic and microwave stimulation, to reduce
effectively the hydrocarbon-containing material viscosity and
enhance its release from the formation matrix. This may, for
example, result from the creation of fluid flow channels through
the thickness of the pay zone, which are known to enhance the
effectiveness of acoustic stimulation. Unlike most other fluid
transport enhancement techniques, the occurrence of "channeling" is
not detrimental in the present invention and the fluid flow
direction is downward under the force of gravity instead of
laterally between vertical wells. In this respect, the invention is
somewhat similar to gravity drainage.
[0078] The surfactant can be any substance that reduces surface
tension in the hydrocarbon-containing material or water containing
the material, or reduces interfacial tension between the two
liquids or one of the liquids and the surrounding formation. For
example, the surfactant can be a detergent, wetting agent or
emulsifier. Preferred surfactants include aqueous alkaline
solutions (formed from hydroxides, silicates, and/or carbonates),
oxygen-containing organic products of the oxidation of organic
compounds (e.g., oxygen-containing functional groups, such as
aldehydes, ketones, alcohols, and carboxylic acids, that are more
soluble and polar than the original organic compound), demulsifiers
(such as pine oil and other terpene hydrocarbon derivatives), and
mixtures thereof.
[0079] The concentration of surfactant required is lowered due to
the synergistic combination of surfactant with acoustic energy.
[0080] The acoustic energy emitters 128a-c introduce acoustic
energy (shown by arcs emanating from emitters) into the formation
100 to disperse the surfactant and effect viscosity reduction of
the hydrocarbon-containing material. While not wishing to be bound
by any theory, it is believed that a sound wave passing through a
viscous liquid, such as water, causes a vibration pattern that sets
the liquid in motion. Acoustic vibration patterns form water
molecule layers that stretch, compress, bend, and relax.
Interacting layers generate tiny vacuum spaces called cavitations
within the liquid. Imploding cavitations scrub surfaces and pull
away foreign matter.
[0081] It is postulated that when acoustic energy is applied to a
hydrocarbon-bearing formation one or more of the following changes
in formation properties is realized: alteration of reduction in
adherence of wetting films to the rock matrix due to nonlinear
acoustic effects (such as in-pore turbulence, acoustic streaming,
cavitation, and perturbation in local pressures), reduction in
surface tension, density, and viscosity from heating by acoustic
energy, increased solubility of surfactants and reduction of
adsorption of surface-acting components, deposition of paraffin wax
and asphaltenes, permeability and porosity increase due to
deformation of pores and removal of fine particles or increase in
the flow by reduced boundary layer of immobile phase, reduction of
capillary forces due to the destruction of surface films,
coalescence of hydrocarbon-containing material drops due to the
Bjerknes forces that cause a continuous stream of water,
oscillation and excitation of capillary trapped
hydrocarbon-containing material drops due to forces generated by
cavitating bubbles and acoustic/mechanical vibration in the rock
and fluids, emulsification generated by intense sound vibration and
the presence of natural or introduced surfactants, sonocapillary
effects, and/or peristaltic transport caused by the deformation of
the pore walls.
[0082] Which effect(s) predominates depends on the frequency and
intensity of the acoustic energy. At higher intensity, mechanical
stresses increase markedly and therefore temperature increases.
Frequency can play an important role in wave dispersion,
attenuation, and heat dissipation.
[0083] Although acoustic energy frequencies in the subsonic and
lower and upper sonic bands may be employed, the preferred
frequency of acoustic energy is in the ultrasonic or supersonic
frequency spectrum and the intensity of the energy is at least
about 10 watts per square inch and more preferably ranges from
about 50 to about 100 watts per square inch in the immediate
vicinity of the acoustic transducer. The acoustic energy can be in
analog (sinusoidal) or digital (pulsed) form. Digital acoustic
energy permits adjustment of the cavitation response for the
specific application.
[0084] In one configuration, multiple acoustic energy frequencies
are intermixed to use multiple of the effects noted above. In this
configuration, complex or modulated vibrational waves are derived
from the combination of multiple sinusoidal waves of dissimilar
frequencies. The wave components of the complex wave may bear a
harmonic relationship to one another, i.e., the frequency of all
but one (the fundamental wave) of the component waves may be an
integral multiple of the frequency of the one fundamental wave.
Such complex waves may be formed by the use of multiple wave
generators.
[0085] Each emitter 128 includes a power source 204, a wave
generator 208, a transducing medium 216, and a coupler 212 between
the power source 204 and generator 208. Although the emitters 128
are depicted as being positioned in a drilled hole, it is to be
understood that the emitters 128 can be in the form of flat plate
transducers that are bolted or otherwise secured to the formation.
The use of flat plates is permitted because the formation 100 is
accessible through the liner. Upon completion of the stimulation
procedure, the emitters are dismounted and reused elsewhere.
[0086] The power source 204 can be mechanical (e.g., an engine or
motor) or electrical (e.g., a generator, battery, capacitor bank,
etc.).
[0087] The generator 208 can be mechanically or electrically driven
and capable of introducing large amounts of acoustic energy into
the formation 100.
[0088] Suitable mechanical generators 208 include, for example,
sonic pump and motor assembly. In one example of a mechanical wave
generator, a motor and generator assembly is located at in the
stimulation excavation. The motor (or power source 204) rotates a
cam (not shown) to effect vertical movement of a roller bearing
resting on the cam. The roller bearing is fastened to a rod that is
pivoted about a point and is counterbalanced by an adjustable
weight. A further coupling rod is attached to the rod by a pivot.
The rotation of the cam produces a reciprocating motion of the rod
through the bearing. The motion is transmitted by the coupling rod
to the transducing medium in the drilled hole, which releases
acoustic energy into the formation 100. The preceding exemplary
generator, and other possible mechanical generator designs, are
discussed in U.S. Pat. No. 2,670,801, which is incorporated herein
by this reference.
[0089] Suitable electrical generators 208 include sonic and
supersonic horns, piezo-electric crystals coupled with low or high
frequency oscillating electrical currents, magneto-restrictive
devices positioned in an alternating magnetic field, and the
like.
[0090] The transducer or transducing medium 216 is preferably a
solid or liquid medium. Under certain conditions, such as those
prevailing in high pressure formations, gaseous media may be used.
The transducing medium 216 may be, for example, water and other
liquids, cement or concrete, plastic, melted or solidified alloys,
or some other material lodged within or in the vicinity of the
formation 100.
[0091] The relative timing of surfactant injection and acoustic
energy emission depends on the application. The surfactant may be
injected before and/or during acoustic energy emission. In one
configuration, the surfactant is injected at a point called the
acoustic slow wave point at which the motion of the solid and pore
liquid is 180 degrees out of phase. At this point, the pore liquid
and solid have the maximum amount of relative motion. When excited
at the slow wave frequency, on alternate sound wave half cycles,
the maximum amount possible of pore fluid is moved from previously
inaccessible pores adjacent to the percolation flow path into the
flow path for removal and collection. On intervening acoustic wave
half cycles, fluid containing surfactants from the percolation flow
path is injected into the surrounding pores in the rock, thus
increasing the size of the percolation flow domain. Accordingly,
both ultrasound half cycles perform useful functions for secondary
oil recovery; that is, removing previously inaccessible oil from
rock surrounding the percolation flow path and enlarging the area
of the oil reservoir accessible to surfactants and percolation
flow. Regardless of the particular timing of surfactant injection
and acoustic energy emission, viscosity reduction can be
substantial, with a reduction of at least four orders of magnitude
being possible.
[0092] The hydrocarbon material, after exposure to the
electromagnetic radiation and acoustic energy and contact with the
surfactant, flows to a production well 170 positioned in proximity
to the excavation 116 and generally having a bearing parallel to
the bearing of the excavation 116. The production well 170 is
preferably formed by directional drilling techniques and located
within the stimulated region, or irradiated region, of the
formation 100. When the formation 100 comprises multiple zones, the
well 170 is placed beneath the lowermost zone. The production well
170 is cased with a well casing (not shown) which extends from the
surface to a position proximal to the formation 100, and a
perforated liner 51 containing perforations (not shown) through
which the hydrocarbon-containing material flows and is collected by
the well 170. Pump tubing (not shown) extends into the well 170 and
is fitted with a standing valve (not shown) that permits an upward
liquid flow and prevents reverse flow. The upward flow is
maintained by a traveling valve (not shown) which is actuated by a
sucker rod (not shown). The sucker rod is in turn actuated by a
motor (not shown) at the surface 132. The well casing is sealed
with a casing head (not shown). The casing head is fitted with a
packing gland (not shown) through which the pump tubing passes. The
collected hydrocarbon-bearing material is stored at the surface 132
in a storage tank (not shown).
[0093] With reference to FIG. 3, multiple stimulation excavations
116 (which typically originate from a common access excavation) are
generally needed to exploit the full width of the formation 100. In
this situation, adjacent excavations 116 are situated such that the
stimulated regions 300a and b overlap, leaving only a very small
portion of the pay zone as unrecovered. Typically adjacent
excavations 116 are substantially parallel and separated by
distances of approximately 300 to approximately 500 feet.
[0094] To facilitate a more efficient electromagnetic heating
effect and substantially minimize the unrecovered portion of the
pay zone, the electromagnetic beam is steered laterally (in a
cross-excavation direction) by incorporating a second waveguide
(not shown) along the excavation floor alongside the first
waveguide and separated from the first by a distance of at least
about 4 inches (or about one-quarter wavelength at the microwave
frequency of 915 MHz). By adjusting the relative phase of the
microwave signals in the adjacent waveguides, one may effectively
steer the radiation beam so as to increase the lateral coverage and
enable a wider tunnel separation, with only a substantially minimal
amount of unrecoverable pay zone. As will be more fully disclosed
below, net hydrocarbon-containing material recoveries approaching
80% may be realized, and in much shorter time periods, than is
possible with other stimulation methods.
[0095] As will be understood by one familiar with the prior art,
there is considerable advantage to the simultaneous combination of
electromagnetic, acoustic, and fluid stimulation techniques as
disclosed herein.
EXPERIMENTAL
Example 1
[0096] Extensive computer reservoir modeling analyses were
conducted for several heavy oil scenarios in Cold Lake, Alberta,
Canada to evaluate the expected performance of microwave
stimulation. The reservoir parameters are as follows:
TABLE-US-00001 Pay zone thickness 20 m Porosity 0.35 Permeability
2,200 md Res. Temperature 13 degrees Celsius Viscosity (live oil)
22,000 cp @ 20 degrees Celsius 950 cp @ 50 degrees Celsius 43 cp @
100 degrees Celsius BHP 500 kPa Water Saturation 0.26 Oil
Saturation 0.327 Pore Volume 0.446
[0097] A single vertical microwave (915 MHz) emitter was located in
the center of a cylindrical test area with diameter 150 meters. Oil
"recovery" was modeled as oil which reached the bottom of the test
cylinder. The cylinder bottom coincided with the bottom of the pay
zone. The simulation was run with 100 kW of microwave power for the
first 150 days and 70 kW thereafter. Microwave power was switched
on and off according to a set thermostat temperature of 300 degrees
(max) to 280 degrees Celsius (minimum). The simulation run time was
three years (FIG. 4). Cumulative oil production was 3,404 cubic
meters in 1095 days, average rate 3.10 cubic meters/day, and a
cumulative recovery of 11.65%.
Example 2
[0098] For the same Cold Lake reservoir parameters as in Example 1,
a single microwave emitter (100 kW at 915 MHz) was located at the
center of a 150 m by 150 m area directly above a horizontal
recovery well, which was located at the bottom of the pay zone. The
microwave power supply was thermostatically controlled as in
Example 1. The simulation time was 10 years (FIGS. 5A and 5B).
Average oil production was 3.28 cubic meters/day, and the
cumulative recovery was 35.3%.
Example 3
[0099] For the same Cold Lake reservoir arrangement as in Example
2, an arrangement of four vertical microwave emitters were
positioned 25 m apart and along a horizontal recovery well. Each
injector antenna provided 25 kW of microwave power at 915 MHz and
the sources were thermostatically controlled as in Example 1. The
simulation time was 10 years (FIG. 6). Average oil production rate
was 4.80 cubic meters/day, and the cumulative recovery was
59.7%.
[0100] A number of variations and modifications of the invention
can be used. It would be possible to provide for some features of
the invention without providing others.
[0101] For example in one alternative embodiment, the surfactant is
not injected into the formation 100 but is generated in situ by
hydrous pyrolysis/partial oxidation of constrained organics, such
as petroleum and petroleum products, including fuel hydrocarbons,
polycyclic aromatic hydrocarbons, chlorinated hydrocarbons, and
other volatile materials. The materials are contained in
groundwater in the formation 100. When oxidized, the organic
material produces intermediate oxygenated organic compounds, e.g.,
surfactants and precursors thereof. The intermediate oxygenated
organic compounds, as noted above, have oxygen-containing
functional groups, such as aldehydes, ketones, alcohols, and
carboxylic acids. The surfactants are formed in situ by introducing
into the formation 100 an oxidant, such as steam (or air) and/or
mineral oxidants, a catalyst of the organic partial oxidation (such
as manganese dioxide or ferric oxide), and thermal energy in the
form of electromagnetic radiation.
[0102] In another alternative embodiment, the various elements
noted above, namely electromagnetic radiative heating, acoustic
energy stimulation, and surfactant injection are used alone or in
any combination to stimulate the reservoir.
[0103] The present invention, in various embodiments, includes
components, methods, processes, systems and/or apparatus
substantially as depicted and described herein, including various
embodiments, subcombinations, and subsets thereof. Those of skill
in the art will understand how to make and use the present
invention after understanding the present disclosure. The present
invention, in various embodiments, includes providing devices and
processes in the absence of items not depicted and/or described
herein or in various embodiments hereof, including in the absence
of such items as may have been used in previous devices or
processes, e.g., for improving performance, achieving ease and\or
reducing cost of implementation.
[0104] The foregoing discussion of the invention has been presented
for purposes of illustration and description. The foregoing is not
intended to limit the invention to the form or forms disclosed
herein. In the foregoing Detailed Description for example, various
features of the invention are grouped together in one or more
embodiments for the purpose of streamlining the disclosure. This
method of disclosure is not to be interpreted as reflecting an
intention that the claimed invention requires more features than
are expressly recited in each claim. Rather, as the following
claims reflect, inventive aspects lie in less than all features of
a single foregoing disclosed embodiment. Thus, the following claims
are hereby incorporated into this Detailed Description, with each
claim standing on its own as a separate preferred embodiment of the
invention.
[0105] Moreover, though the description of the invention has
included description of one or more embodiments and certain
variations and modifications, other variations and modifications
are within the scope of the invention, e.g., as may be within the
skill and knowledge of those in the art, after understanding the
present disclosure. It is intended to obtain rights which include
alternative embodiments to the extent permitted, including
alternate, interchangeable and/or equivalent structures, functions,
ranges or steps to those claimed, whether or not such alternate,
interchangeable and/or equivalent structures, functions, ranges or
steps are disclosed herein, and without intending to publicly
dedicate any patentable subject matter.
* * * * *