U.S. patent application number 16/968958 was filed with the patent office on 2022-08-25 for automated modular wellhead mounted wireline for unmanned extended real time data monitoring.
This patent application is currently assigned to Halliburton Energy Services, Inc.. The applicant listed for this patent is Halliburton Energy Services, Inc.. Invention is credited to James Robert Longbottom.
Application Number | 20220268150 16/968958 |
Document ID | / |
Family ID | 1000006374679 |
Filed Date | 2022-08-25 |
United States Patent
Application |
20220268150 |
Kind Code |
A1 |
Longbottom; James Robert |
August 25, 2022 |
Automated Modular Wellhead Mounted Wireline For Unmanned Extended
Real Time Data Monitoring
Abstract
A system for communicating downhole measurements may comprise a
remote wireline system connected to a wellhead. The remote
wirelines system may further comprise a base support, a spool frame
attached to the base support, a spool attached to the spool frame
and a conveyance attached to the spool, an acoustic receiver node
attached at a second end of the conveyance, a control box attached
to the base support and connected to the spool, and a communication
device disposed in the control box. A method for communicating
downhole measurements may comprise attaching a remote wireline
system to a wellhead, lowering the acoustic receiver node through
one or more production tubing sections to a heel of a wellbore,
communicating with one or more nodes, and transmitting one or more
data packets uphole from the one or more nodes to the acoustic
receiver node.
Inventors: |
Longbottom; James Robert;
(Magnolia, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Halliburton Energy Services, Inc. |
Houston |
TX |
US |
|
|
Assignee: |
Halliburton Energy Services,
Inc.
Houston
TX
|
Family ID: |
1000006374679 |
Appl. No.: |
16/968958 |
Filed: |
November 13, 2019 |
PCT Filed: |
November 13, 2019 |
PCT NO: |
PCT/US2019/061082 |
371 Date: |
August 11, 2020 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 47/14 20130101;
E21B 47/10 20130101; E21B 47/135 20200501 |
International
Class: |
E21B 47/135 20060101
E21B047/135; E21B 47/14 20060101 E21B047/14; E21B 47/10 20060101
E21B047/10 |
Claims
1. A system for communicating downhole measurements comprising: a
remote wireline system comprising: a base support; a spool frame
attached to the base support; a spool attached to the spool frame
and a conveyance attached to the spool at a first end and wound
around the spool; an acoustic receiver node attached at a second
end of the conveyance opposite the first end of the conveyance; a
control box attached to the base support and connected to the
spool; and a communication device disposed in the control box; and
a wellhead, wherein the conveyance is configured to lower the
acoustic receiver node into one or more production tubing sections
through the wellhead.
2. The system of claim 1, further comprising one or more nodes
disposed on the casing.
3. The system of claim 2, wherein the one or more nodes are
configured to communicate with each other and the acoustic receiver
node.
4. The system of claim 3, wherein the one or more nodes are
configured to measure fluid flow within the one or more production
tubing sections.
5. The system of claim 1, wherein the acoustic receiver node is
communicatively coupled to the communication device.
6. The system of claim 5, wherein the communication device is
configured to communicate with an offsite location.
7. The system of claim 1, wherein the base support is configured to
connect the remote wireline system to the wellhead through one or
more connection devices.
8. The system of claim 1, wherein the base support is configured to
connect the remote wireline system to a surface through one or more
connection devices.
9. The system of claim 1, further comprising one or more quick
connects that are configured to connect the remote wireline system
to a power source, hydraulic fluid, or a data connection through
one or more connection ports disposed on the control box.
10. The system of claim 9, wherein the power source, the hydraulic
fluid, or the data connection is disposed on a vehicle or a
skid.
11. A method for communicating downhole measurements comprising:
attaching a remote wireline system to a wellhead, wherein the
remote wireline system comprises: a base support that is configured
to connect the remote wireline system to the wellhead; a spool
frame attached to the base support and a spool attached to the
spool frame and a power source, wherein the power source is
configured to power the spool; a conveyance attached to the spool
at a first end and wound around the spool; an acoustic receiver
node attached at a second end of the conveyance opposite the first
end of the conveyance; a control box attached to the base support
and connected to the spool; and a communication device disposed in
the control box; and lowering the acoustic receiver node through
one or more production tubing sections to a heel of a wellbore;
communicating with one or more nodes disposed in the one or more
production tubing section with the acoustic receiver node; and
transmitting one or more data packets uphole from the one or more
nodes to the acoustic receiver node.
12. The method of claim 11, further comprising measuring fluid flow
within the one or more production tubing sections to form the data
packets.
13. The method of claim 11, further comprising transmitting the
data packets to an offsite location.
14. The method of claim 11, wherein the remote wireline system
further comprises one or more quick connects.
15. The method of claim 14, further comprising connecting the
remote wireline system to the power source, hydraulic fluid, or a
data connection through the one or more quick connects through one
or more connection ports disposed on the control box.
16. The method of claim 15, wherein the power source, the hydraulic
fluid, or the data connection is disposed on a vehicle or skid.
17. The method of claim 11, further comprising activating the
remote wireline system wireless with a remote that is wirelessly
communicating with the communication device.
18. The method of claim 17, further comprising locking the remote
wireline system wireless with the remote, wherein the remote
activates a lock bar connected to the spool frame and the
spool.
19. The method of claim 11, further comprising removing the remote
wireline system from the wellhead.
20. The method of claim 11, wherein the conveyance comprises a
fiber optic cable.
Description
BACKGROUND
[0001] Boreholes drilled into subterranean formations may enable
recovery of desirable fluids (e.g., hydrocarbons) using a number of
different techniques. Currently after the conclusion of drilling
operations, production operations may begin. Generally, production
operations may include fracturing the subterranean formation. When
fracturing the subterranean formation, it may be beneficial to
measure the characteristics, properties, and/or movement of
fracturing fluid between production tubing and the subterranean
formation. Currently, to measure downhole data may take a wireline
operation that includes the use of personnel and semi-permanent
structures and support that may need to be setup for obtaining
measurements for downhole operations. This may increase cost, slow
production operations, and increase the number of personnel at a
well site.
BRIEF DESCRIPTION OF THE DRAWINGS
[0002] These drawings illustrate certain aspects of some examples
of the present disclosure and should not be used to limit or define
the disclosure.
[0003] FIG. 1 illustrates an example of a remote wireline system
disposed on a wellhead;
[0004] FIG. 2 illustrates an example of the remote wireline
system;
[0005] FIG. 3 illustrates an example of an acoustic receiver node
communicating with one or more nodes in a production tubing;
and
[0006] FIG. 4 illustrates another example of the acoustic receiver
node connected to the production tubing.
DETAILED DESCRIPTION
[0007] Provided are systems and methods for taking downhole
measurement during production operations. Specifically,
communicating measurements uphole to a permanent or temporary
remote wireline system that may transmit the measurements to an
offsite location. For example, during production operations for
fracturing a subterranean formation, measurements of fracturing
fluids may be taken to determine fracture efficiency. Wireless
nodes in production tubing may measure the data at each fracture
cluster, store the data on the node and relay the data from node to
node to an acoustic receiver node at the heel of a wellbore. The
acoustic receiver node may pick up the data and relays from the
other nodes and transmit the information to the surface for
analysis.
[0008] Additionally, the remote wireline system may be a modular
automated wireline unit that is adapted to the wellhead, so the
acoustic receiver node is deployed automatically on a predetermined
schedule or it is anchored in place to retrieve data from the
nodes. The acoustic receiver node may be retracted and out of flow
while not in use and be isolated above a barrier, temporarily
suspended in the well, or anchored near the top node to talk to
downhole tools in the horizontal section.
[0009] FIG. 1 illustrates an example of wellhead system 100 capping
a wellbore 102, where wellhead system 100 is disposed at a surface
104. In examples, wellhead system 100 may include a wellhead 106, a
stuffing box 108, one or more valves 110, and a remote wireline
system 112. In examples, wellhead 106 may control the outflow of
desirable fluids from wellbore 102 and may also control in the
input of tools, fluids, implements, and/or the like to into
wellbore 102 for production operations, measurement operations,
stimulation operations, and/or the like. For example, FIG. 1
illustrates a remote measurement operation which may utilize remote
wireline system 112.
[0010] During measurement operations, remote wireline system 112
may operate to move a conveyance 114 up and down production tubing
116 disposed in wellbore 102. Stuffing box 108 may be provided at
the top of wellhead 106 in order to seal the interior of production
tubing 116 and prevent foreign matter from entering. Stuffing box
108 may be a packing gland or chamber to hold packing material (not
shown) compressed around conveyance 114 to prevent the escape of
gas and/or liquid.
[0011] Conveyance 114 may include, but not limited to, wireline,
slickline, pipe, drill pipe, downhole tractor, or the like. In some
examples, the conveyance may provide mechanical suspension, as well
as electrical connectivity, for an acoustic receiver node,
discussed further below. Conveyance 114 may comprise, in some
instances, a plurality of electrical conductors extending from
surface 104. Additionally, conveyance 114 may comprise an inner
core of one to seven electrical conductors covered by an insulating
wrap. An inner and outer steel armor sheath may be wrapped in a
helix in opposite directions around the conductors. The electrical
conductors may be used for communicating power and telemetry to and
from surface 104. In examples, conveyance 114 may be a fiber optic
cable deployed independently or in a distributed acoustic system.
Information from the acoustic receiver node may be gathered and/or
processed at a surface 104, discussed below. Conveyance 114 may be
a part of remote wireline system 112.
[0012] FIG. 2 illustrates an example of remote wireline system 112.
Remote wireline system 112 may include a spool 118 in which
conveyance 114 may be wound around. Additionally, spool 118 may be
supported by structural support 120. Structural support 120 may
connect spool 118 to wellhead 106 as illustrated in FIG. 1. In
examples, structural support 120 may not be connected to wellhead
106 and may be connected to surface 104, providing a base for spool
118 to operate. Without limitation, structural support 120 may
include a base support 200. Base support 200 may connect to
wellhead 106 or surface 104 through connection devices 201. Without
limitation, connection devices 201 may be latches, quick connects,
a cutout for nuts and bolts, pegs, and/or the like. Connection
devices 201 may support the weight of remote wirelines system 112
when attached to wellhead 106 or surface 104 through base support
200.
[0013] Base support 200 may include one or more frames or may be a
sheet of metal. Base support 200 may form a foundation for which
spool frame 202 may attach. Without limitation, spool frame 202, as
illustrated in FIG. 2, may include bars or sheets of metal. Spool
frame 202 may function and operate to support spool 118.
Additionally, it may allow spool 118 to rotate during operations. A
lock bar 204 may span between spool frame 202. Lock bar 204 may
operate and function to prevent the movement of spool 118. In
examples, lock bar 204 may be controlled by control box 206.
Control box 206 may connect to base support 200 and/or spool frame
202. Without limitation, control box 206 may house motors, gears,
power supplies, an information handling system 124, discussed
below, and/or the like. This may allow control box 206 to rotate
spool 118 clockwise or counterclockwise and operate lock bar 204,
which may prevent rotation of spool 118.
[0014] Mechanisms within control box 206 may be powered by onsite
power source or transit power source that may be brought to remote
wireline system 112, further discussed below. Control box 206
includes one or more connection ports 208, which may allow power to
enter control box 206 and power the mechanisms within. Connection
ports 208 may allow for the connection of electrical power or
hydraulic power.
[0015] Additionally, remote wireline system 112 may include a
communication device 122, that may be wireless, as illustrated in
FIG. 1, or a wired connection. In examples, communication device
122 may be disposed on control box 206 or within control box 206.
Communication device 122 may also be powered by onsite power source
or transit power source that may be brought to remote wireline
system 112. In examples, communication device 122 may connect to a
remote 210 either wirelessly or through wired communication. Remote
210 may operate remote wireline system 112, specifically sending
commands to rotate spool 118 either clockwise or counterclockwise,
which may raise and/or lower conveyance 114. Additionally, remote
210 may include a counter 212, which may indicate the length of
conveyance 114 that may be released from spool 118 during
operations. Conveyance 114 may release from spool 118 through one
or more guides 214, which may operate and function to prevent
entanglement of conveyance 114. Referring back to FIG. 1, one or
more counter wheels 216 may be used to determine the length of
conveyance 114 that may be release from spool 118. The measurement
of length may be communicated from counter wheels 216 to control
box 206. Communication device 122 may communicate the length to
remote 210, which may display the length on counter 212.
[0016] During operations communication device 122 may transmit
measurements from control box 206 to an offsite information
handling system 124 either wirelessly or through wired
communication. Without limitation, information handling system 124
may be disposed at an offsite location or in a vehicle or skid, not
illustrated.
[0017] Information handling system 124 may include any
instrumentality or aggregate of instrumentalities operable to
compute, estimate, classify, process, transmit, receive, retrieve,
originate, switch, store, display, manifest, detect, record,
reproduce, handle, or utilize any form of information,
intelligence, or data for business, scientific, control, or other
purposes. For example, an information handling system 124 may be a
personal computer, a network storage device, or any other suitable
device and may vary in size, shape, performance, functionality, and
price. Information handling system 124 may include random access
memory (RAM), one or more processing resources such as a central
processing unit 126 (CPU) or hardware or software control logic,
ROM, and/or other types of nonvolatile memory. Additional
components of the information handling system 124 may include one
or more disk drives 128, output devices 130, such as a video
display, and one or more network ports for communication with
external devices as well as an input device 132 (e.g., keyboard,
mouse, etc.). Information handling system 124 may also include one
or more buses operable to transmit communications between the
various hardware components.
[0018] Alternatively, systems and methods of the present disclosure
may be implemented, at least in part, with non-transitory
computer-readable media. Non-transitory computer-readable media may
include any instrumentality or aggregation of instrumentalities
that may retain data and/or instructions for a period of time.
Non-transitory computer-readable media may include, for example,
storage media such as a direct access storage device (e.g., a hard
disk drive or floppy disk drive), a sequential access storage
device (e.g., a tape disk drive), compact disk, CD-ROM, DVD, RAM,
ROM, electrically erasable programmable read-only memory (EEPROM),
and/or flash memory; as well as communications media such wires,
optical fibers, microwaves, radio waves, and other electromagnetic
and/or optical carriers; and/or any combination of the
foregoing.
[0019] During operations, remote wireline system 112 may be
controlled by information handling system 124. For example,
personnel may activate remote wireline system 112 from an offsite
location by information handling system 124. Remote wireline system
112 may function to transmit measurements from wellbore 102 to
information handling system 124. As illustrated in FIG. 1,
measurements may be taken by production operation by measuring the
flow of desirable fluids from perforations 134 through casing 136
to production tubing 116.
[0020] FIG. 3 illustrates a cutaway of example production tubing
116 to show nodes 300 which may be utilized to take different
measurement for operations within wellbore 102. In examples, nodes
300 may operate by any number of communication modes to move data,
which may also be referred to as data packets, from wellbore 102 to
surface 104. In examples, each node 300 may be disposed at and/or
near perforation 134. This may allow each node 300 to measure fluid
flow into production tubing 116. Measurements taken by each node
300 may be simultaneously conveyed uphole as uplink data to
acoustic receiver node 302. As discussed above, acoustic receiver
node 302 may be lowered into production tubing 116 using remote
wireline system 112 (e.g., referring to FIG. 1). Additionally,
acoustic receiver node 302 may transmit downlink data to nodes 300
to request measurement data and/or change modes on nodes 300.
Without limitation, nodes 300 may include transducers, receivers,
transmitters and/or the like to communication between nodes 300 and
acoustic receiver node 302. Without limitation, transducers,
receivers, transmitters and/or the like may be embedded into node
300 at various location within node 300. Additionally, nodes 300
may be tubular in nature and/or a ring as illustrated in FIG. 3. In
other examples, as illustrated in FIG. 4, nodes 300 may be an
elongated device attached to the exterior surface of casing 136
using one or more attachment devices 400, such as bands and/or
clamps. This may allow each node 300 to connect to the outside of
casing 136.
[0021] Referring again to FIG. 3, nodes 300 may be attached to
casing 136 in close proximity to perforations 134. One or more
packers 140 may block an internal diameter of casing 136, which may
force fluids to flow up an internal diameter of production tubing
116 within the end of tubing 138 placed above the uppermost
perforation 142. Nodes 300 may operate by sending uplink data and
receiving downlink data on any carrier frequency. In examples,
individual nodes 300 may be operating simultaneously on different
carrier frequencies to reduce interference and/or receiver
saturation. Additionally, acoustic channel(s) may support
unidirectional transmission paths to reduce interference and/or
receiver saturation. Further, the position of transducers
(transmitters/receivers) may be selected to reduce interference
and/or receiver saturation. For example, a receiver and a
transmitter may be on opposite sides of node 300 (e.g., a
180.degree. offset). In examples, transducers may be positioned on
different sides of node 300 (e.g., a 90.degree. offset or some
other offset), but not on opposite sides. Furthermore, nodes 300
may provide different types of acoustic waves, namely shear waves
and compressional waves in a different communication mode.
[0022] In examples, nodes 300 may include controllers, not
illustrated, which may provide power, data storage/buffering, and
mode control for the respective node 300. During operations, nodes
300 may operate, for example, for six months to one year with
supplied power from the controllers or a separate power source.
During this time, nodes 300 may actively take measurements and send
them uphole using remote wireline system 112 (e.g., referring to
FIG. 1). For example, nodes 300 may collect point data regarding
the movement of the fracturing fluid into formation 304 through
perforations 134. Data may also include where production is
originating. For example, production data which may be found in the
first week and up to nine months of production operations. Data
collected by nodes 300 may be transmitted to surface from heel 306
of wellbore 102. Heel 306 may be defined as the area at which
wellbore 102 transfers from vertical to horizontal. As illustrated
in FIG. 3, conveyance 114 may be lowered into wellbore 102 to heel
306, within production tubing 116, by remote wireline system 112.
In examples, conveyance 114 may be a digital acoustic sensing fiber
optic cable. While FIGS. 1 and 2 illustrates remote wireline system
112 that may be semi-permanent and operating to move conveyance 114
up and down production tubing 116, conveyance 114 may be removable,
semi-permanent, or permanently installed.
[0023] As discussed above, remote wireline system 112 may be a
temporary installation on wellhead 106. In examples, remote
wireline system 112 may be powered by local power source at
wellhead 106. However, remote wireline system 112 may not have a
power source but may be powered by personnel during measurement
operations. For example, remote wireline system 112 may have quick
disconnects, e.g. connection ports 208, for power, hydraulic fluid,
and/or the like that may be necessary to operate remote wireline
system 112. During an operation, a vehicle or skid (not
illustrated) may attached to remote wireline system 112 through one
or more quick connects to power, operate, or send and receive data
from nodes 300. Without limitation, an information handling system
124 may be disposed within the vehicle or skid and connected to
acoustic receiver node 302 through the quick connects and
conveyance 114. This may allow for the operator to collect data
from the one or more nodes 300. Without limitation, information
handling system may connect to remote wireline system 112
wirelessly through communication device 122 and not through a quick
connect.
[0024] In examples, remote wireline system 112 may be connected to
on site power source at wellhead 106. This may allow remote
wireline system 112 to be operated remotely. For example, remote
wireline system 112 may communicate with an offsite information
handling system 124 that may be at an offsite facility, a vehicle,
or a skid. Additionally, in a producing oil field, there may be any
number of remote wireline systems 112 that may be controlled
remotely with an offsite information handling system 124.
[0025] Accordingly, the systems and methods disclosed herein may be
directed to a method for receiving measurement data from a remote
wireline system. The systems and methods may include any of the
various features of the systems and methods disclosed herein,
including one or more of the following statements.
[0026] Statement 1. A system for communicating downhole
measurements may comprise a remote wireline system. The remote
wireline system may further comprise a base support, a spool frame
attached to the base support, a spool attached to the spool frame
and a conveyance attached to the spool at a first end and wound
around the spool, an acoustic receiver node attached at a second
end of the conveyance opposite the first end of the conveyance, a
control box attached to the base support and connected to the
spool, and a communication device disposed in the control box. The
system may further comprise a wellhead, wherein the conveyance is
configured to lower the acoustic receiver node into one or more
production tubing sections through the wellhead.
[0027] Statement 2. The system of statement 1, further comprising
one or more nodes disposed on the casing.
[0028] Statement 3. The system of statement 2, wherein the one or
more nodes are configured to communicate with each other and the
acoustic receiver node.
[0029] Statement 4. The system of statement 3, wherein the one or
more nodes are configured to measure fluid flow within the one or
more production tubing sections.
[0030] Statement 5. The system of statements 1 or 2, wherein the
acoustic receiver node is communicatively coupled to the
communication device.
[0031] Statement 6. The system of statement 5, wherein the
communication device is configured to communicate with an offsite
location.
[0032] Statement 7. The system of statements 1, 2, or 5, wherein
the base support is configured to connect the remote wireline
system to the wellhead through one or more connection devices.
[0033] Statement 8. The system of statements 1, 2, 5, or 7 wherein
the base support is configured to connect the remote wireline
system to a surface through one or more connection devices.
[0034] Statement 9. The system of statements 1, 2, 5, 7, or 8
further comprising one or more quick connects that are configured
to connect the remote wireline system to a power source, hydraulic
fluid, or a data connection through one or more connection ports
disposed on the control box.
[0035] Statement 10. The system of statement 9, wherein the power
source, the hydraulic fluid, or the data connection is disposed on
a vehicle or a skid.
[0036] Statement 11. A method for communicating downhole
measurements may comprise attaching a remote wireline system to a
wellhead. The remote wireline system may comprise a base support
that is configured to connect the remote wireline system to the
wellhead, a spool frame attached to the base support and a spool
attached to the spool frame and a power source, wherein the power
source is configured to power the spool, a conveyance attached to
the spool at a first end and wound around the spool, an acoustic
receiver node attached at a second end of the conveyance opposite
the first end of the conveyance, a control box attached to the base
support and connected to the spool, and a communication device
disposed in the control box. The method may further comprise
lowering the acoustic receiver node through one or more production
tubing sections to a heel of a wellbore, communicating with one or
more nodes disposed in the one or more production tubing section
with the acoustic receiver node, and transmitting one or more data
packets uphole from the one or more nodes to the acoustic receiver
node.
[0037] Statement 12. The method of statement 11, further comprising
measuring fluid flow within the one or more production tubing
sections to form the data packets.
[0038] Statement 13. The method of statements 11 or 12, further
comprising transmitting the data packets to an offsite
location.
[0039] Statement 14. The method of statements 11-13, wherein the
remote wireline system further comprises one or more quick
connects.
[0040] Statement 15. The method of statement 14, further comprising
connecting the remote wireline system to the power source,
hydraulic fluid, or a data connection through the one or more quick
connects through one or more connection ports disposed on the
control box.
[0041] Statement 16. The method of statement 15, wherein the power
source, the hydraulic fluid, or the data connection is disposed on
a vehicle or skid.
[0042] Statement 17. The method of statements 11-14, further
comprising activating the remote wireline system wireless with a
remote that is wirelessly communicating with the communication
device.
[0043] Statement 18. The method of statement 17, further comprising
locking the remote wireline system wireless with the remote,
wherein the remote activates a lock bar connected to the spool
frame and the spool
[0044] Statement 19. The method of statements 11-14 and 17, further
comprising removing the remote wireline system from the
wellhead.
[0045] Statement 20. The method of statements 11-14, 17, and 19,
wherein the conveyance comprises a fiber optic cable.
[0046] The preceding description provides various examples of the
systems and methods of use disclosed herein which may contain
different method steps and alternative combinations of components.
It should be understood that, although individual examples may be
discussed herein, the present disclosure covers all combinations of
the disclosed examples, including, without limitation, the
different component combinations, method step combinations, and
properties of the system. It should be understood that the
compositions and methods are described in terms of "comprising,"
"containing," or "including" various components or steps, the
compositions and methods can also "consist essentially of" or
"consist of" the various components and steps. Moreover, the
indefinite articles "a" or "an," as used in the claims, are defined
herein to mean one or more than one of the element that it
introduces.
[0047] For the sake of brevity, only certain ranges are explicitly
disclosed herein. However, ranges from any lower limit may be
combined with any upper limit to recite a range not explicitly
recited, as well as, ranges from any lower limit may be combined
with any other lower limit to recite a range not explicitly
recited, in the same way, ranges from any upper limit may be
combined with any other upper limit to recite a range not
explicitly recited. Additionally, whenever a numerical range with a
lower limit and an upper limit is disclosed, any number and any
included range falling within the range are specifically disclosed.
In particular, every range of values (of the form, "from about a to
about b," or, equivalently, "from approximately a to b," or,
equivalently, "from approximately a-b") disclosed herein is to be
understood to set forth every number and range encompassed within
the broader range of values even if not explicitly recited. Thus,
every point or individual value may serve as its own lower or upper
limit combined with any other point or individual value or any
other lower or upper limit, to recite a range not explicitly
recited.
[0048] Therefore, the present examples are well adapted to attain
the ends and advantages mentioned as well as those that are
inherent therein. The particular examples disclosed above are
illustrative only and may be modified and practiced in different
but equivalent manners apparent to those skilled in the art having
the benefit of the teachings herein. Although individual examples
are discussed, the disclosure covers all combinations of all of the
examples. Furthermore, no limitations are intended to the details
of construction or design herein shown, other than as described in
the claims below. Also, the terms in the claims have their plain,
ordinary meaning unless otherwise explicitly and clearly defined by
the patentee. It is therefore evident that the particular
illustrative examples disclosed above may be altered or modified
and all such variations are considered within the scope and spirit
of those examples. If there is any conflict in the usages of a word
or term in this specification and one or more patent(s) or other
documents that may be incorporated herein by reference, the
definitions that are consistent with this specification should be
adopted.
* * * * *