Note: Descriptions are shown in the official language in which they were submitted.
MOBILE FRACTURING PUMP TRANSPORT FOR HYDRAULIC FRACTURING OF
SUBSURFACE GEOLOGICAL FORMATIONS
BACKGROUND
[0001] Hydraulic fracturing has been commonly used by the oil and gas
industry to stimulate
production of hydrocarbon wells, such as oil and/or gas wells. Hydraulic
fracturing, sometimes
called "fracing" or `Tracking" is the process of injecting fracturing fluid,
which is typically a mixture
of water, sand, and chemicals, into the subsurface to fracture the subsurface
geological formations
and release otherwise encapsulated hydrocarbon reserves. The fracturing fluid
is typically pumped
into a wellbore at a relatively high pressure sufficient to cause fissures
within the underground
geological formations. Specifically, once inside the wellbore, the pressurized
fracturing fluid is
pressure pumped down and then out into the subsurface geological formation to
fracture the
underground formation. A fluid mixture that may include water, various
chemical additives, and
proppants (e.g., sand or ceramic materials) can be pumped into the underground
formation to fracture
and promote the extraction of the hydrocarbon reserves, such as oil and/or
gas. For example, the
fracturing fluid may comprise a liquid petroleum gas, linear gelled water,
gelled water, gelled oil,
slick water, slick oil, poly emulsion, foam/emulsion, liquid carbon dioxide
(CO2), nitrogen gas (N2),
and/or binary fluid and acid.
[0002] Implementing large-scale fracturing operations at well sites
typically requires extensive
investment in equipment, labor, and fuel. For instance, a typical fracturing
operation uses a variety
of fracturing equipment, numerous personnel to operate and maintain the
fracturing equipment,
relatively large amounts of fuel to power the fracturing operations, and
relatively large volumes of
fracturing fluids. As such, planning for fracturing operations is often
complex and encompasses a
variety of logistical challenges that include minimizing the on-site area or
"footprint" of the
fracturing operations, providing adequate power and/or fuel to continuously
power the fracturing
operations, increasing the efficiency of the hydraulic fracturing equipment,
and reducing any
environmental impact resulting from fracturing operations. Thus, numerous
innovations and
improvements of existing fracturing technology are needed to address the
variety of complex and
logistical challenges faced in today's fracturing operations.
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Date Recue/Date Received 2021-06-24
SUMMARY
[00011 The following presents a simplified summary of the disclosed subject
matter in order to
provide a basic understanding of some aspects of the subject matter disclosed
herein. This summary
is not an exhaustive overview of the technology disclosed herein. It is not
intended to identify key
or critical elements of the invention or to delineate the scope of the
invention. Its sole purpose is to
present some concepts in a simplified form as a prelude to the more detailed
description that is
discussed later.
[00021 A system for pumping and pressurizing fracturing fluid, the system
comprising: a mobile
transport, an electric prime mover that comprises a shaft and mounted on the
mobile transport, a
drive line assembly, a fracturing pump mounted on the mobile transport that is
coupled to an end of
the shaft via the drive line assembly. The drive line assembly comprises an
engagement coupling
configured to selectively engage and/or disengage the fracturing pump and the
electric prime mover,
and an engagement panel mounted on the mobile transport and configured to
receive a remote
command and trigger, in response to the remote command, engagement and/or
disengagement of the
fracturing pump and the electric prime mover.
[00031 A fracturing pump transport comprising: a first fracturing pump, a
second fracturing
pump, a dual shaft electric motor that comprises a shaft having a first end
and a second end, a first
drive line assembly that comprises a first engagement coupling that allows for
selective
engagement and/or disengagement of the first fracturing pump with the first
end of the shaft, a
second drive line assembly that comprises a second engagement coupling that
allows for selective
engagement and/or disengagement of the second fracturing pump with the second
end of the shaft,
and an engagement panel that allows for selective engagement and/or
disengagement at the first
engagement coupling, selective engagement and/or disengagement of at the
second engagement
coupling, or both based on receiving a remote command.
[00041 A method for pumping and pressurizing fracturing fluid, the method
comprising:
receiving an engagement and/or disengagement command from a location remote to
a fracturing
pump transport, engaging and/or dis-engaging, in response to receiving the
engagement command,
a first fracturing pump mounted on the fracturing pump transport with a dual
shaft electric prime
mover mounted on the fracturing pump transport using a first drive line
assembly, wherein the first
drive line assembly comprises an engagement coupling that allows for selective
engagement
between the first fracturing pump and the dual shaft electric prime mover, and
driving a second
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Date Recue/Date Received 2021-06-24
fracturing pump mounted on the fracturing pump transport with the dual shaft
electric prime mover
after either engaging and/or disengaging the first fracturing pump from the
dual shaft electric prime
mover using the first drive line assembly.
BRIEF DESCRIPTION OF THE DRAWINGS
[0005] For a more complete understanding of this disclosure, reference is
now made to the
following brief description, taken in connection with the accompanying
drawings and detailed
description, wherein like reference numerals represent like parts.
[0006] FIG. 1 is a schematic diagram of an embodiment of a well site, where
various
embodiments may operate within.
[0007] FIG. 2 is a schematic diagram an embodiment of a well site that
includes a mobile
source of electricity that comprises three transports for a mobile fracturing
system.
[0008] FIG. 3 is a schematic diagram an embodiment of a well site that
includes two wellheads
and two data vans.
[0009] FIG. 4A is a schematic diagram of an embodiment of the gas turbine
generator
transport.
[0010] FIG. 4B is a schematic diagram of an embodiment of the gas turbine
generator
transport.
[0011] FIG. 5A is a schematic diagram of an embodiment of an inlet and
exhaust transport.
[0012] FIG. 5B is a schematic diagram of an embodiment of an inlet and
exhaust transport.
[0013] FIG. 5C is a schematic diagram of an embodiment of an inlet and
exhaust transport that
includes a sliding air inlet filter housing.
[0014] FIG. 6 is a schematic diagram of an embodiment of the two transport
mobile electric
power source when in operational mode.
[0015] FIG. 7A is a schematic diagram of an embodiment of a fracturing pump
transport
powered by the mobile source of electricity.
[0016] FIG. 7B is a schematic diagram of an embodiment of a fracturing pump
transport
powered by the mobile source of electricity.
[0017] FIG. 8A is a schematic diagram of an embodiment of a blender
transport that includes
an electric blender.
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Date Recue/Date Received 2021-06-24
[0018] FIG. 8B is a schematic diagram of an embodiment of a blender
transport that includes
an electric blender.
[0019] FIG. 9A of an embodiment of a blender transport that includes an
electric blender with
enclosed mixer hoppers.
[0020] FIG. 9B of an embodiment of a blender transport that includes an
electric blender with
enclosed mixer hoppers.
[0021] FIG. 10 is a schematic diagram of an embodiment of a control network
system used to
monitor, control, and communicate with a variety of control systems located at
one or more well
sites.
[0022] FIG. 11 is a flow chart of an embodiment of a method to provide a
mobile source of
electricity for fracturing operations.
[0023] FIG. 12 is a flow chart of an embodiment of a method to pump
fracturing fluid into a
wellhead.
[0024] FIG. 13 is a schematic diagram of an embodiment of a fracturing pump
transport
configured to remotely engage and/or disengage one or more pumps from the
prime mover.
[0025] FIG. 14A is a schematic diagram of an embodiment of a drive line
assembly that
includes an engagement coupling located in an engagement position.
[0026] FIG. 14B is a schematic diagram of an embodiment of a drive line
assembly that
includes an engagement coupling located in a disengagement position.
[0027] FIG. 15A is a schematic diagram of an embodiment of an engagement
panel configured
to cause remote engagement and/or disengagement of one or more pumps with a
prime mover.
[0028] FIG. 15B is a schematic diagram of an embodiment of a hydraulic
control bank located
within an engagement panel.
[0029] While certain embodiments will be described in connection with the
illustrative
embodiments shown herein, the invention is not limited to those embodiments.
On the contrary,
all alternatives, modifications, and equivalents are included within the
spirit and scope of the
invention as defined by the claims. In the drawing figures, which are not to
scale, the same
reference numerals are used throughout the description and in the drawing
figures for components
and elements having the same structure, and primed reference numerals are used
for components
and elements having a similar function and construction to those components
and elements having
the same unprimed reference numerals.
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Date Recue/Date Received 2021-06-24
DETAILED DESCRIPTION
[0030] As used herein, the term "transport" refers to any transportation
assembly, including, but
not limited to, a trailer, truck, skid, and/or barge used to transport
relatively heavy structures, such
as fracturing equipment.
[0031] As used herein, the term "trailer" refers to a transportation
assembly used to transport
relatively heavy structures, such as fracturing equipment that can be attached
and/or detached from
a transportation vehicle used to pull or move the trailer. In one embodiment,
the trailer may include
the mounts and manifold systems to connect the trailer to other fracturing
equipment within a
fracturing system or fleet.
[0032] As used herein, the term "lay-down trailer" refers to a trailer that
includes two sections
with different vertical heights. One of the sections or the upper section is
positioned at or above the
trailer axles and another section or the lower section is positioned at or
below the trailer axles. In one
embodiment the main trailer beams of the lay-down trailer may be resting on
the ground when in
operational mode and/or when uncoupled from a transportation vehicle, such as
a tractor.
[0033] As used herein, the term "gas turbine generator" refers to both the
gas turbine and the
generator sections of a gas-turbine generator transport. The gas turbine
generator receives
hydrocarbon fuel, such as natural gas, and converts the hydrocarbon fuel into
electricity.
[0034] As used herein, the term "inlet plenum" may be interchanged and
generally referred to
as "inlet", "air intake," and "intake plenum," throughout this disclosure.
Additionally, the term
"exhaust collector" may be interchanged throughout and generally referred to
as "exhaust diffuser"
and "exhaust plenum" throughout this disclosure.
[0035] As used herein, the term "gas turbine inlet filter" may be
interchanged and generally
referred to as "inlet filter" and "inlet filter assembly." The term "air inlet
filter housing" may also be
interchanged and generally referred to as "filter housing" and "air filter
assembly housing"
throughout this disclosure. Furthermore, the term "exhaust stack" may also be
interchanged and
generally referred to as "turbine exhaust stack" throughout this disclosure.
[0036] Various example embodiments are disclosed herein that provide mobile
electric
fracturing operations for one or more well sites. To provide fracturing
operations, a mobile source
of electricity may be configured to provide electric power to a variety of
fracturing equipment located
at the well sites. The mobile source of electricity may be implemented using
at least two transports
to reduce its "footprint" at a site. One transport, the power generation
transport, may comprise a gas
Date Recue/Date Received 2021-06-24
turbine and generator along with ancillary equipment that supplies electric
power to the well sites.
For example, the power generation transport may produce electric power in the
ranges of about 15-
35 megawatt (MW) when providing electric power to a single well site. A second
transport, the inlet
and exhaust transport, may comprise one or more gas turbine inlet air filters
and a gas turbine exhaust
stack. The power generation transport and the inlet and exhaust transport may
be arranged such that
the inlet and exhaust are connected at the side of the gas turbine enclosure
rather than through the
top of the gas turbine enclosure. In one embodiment, the mobile source of
electricity may comprise
a third supplemental transport, an auxiliary gas turbine generator transport,
that provides power to
ignite, start, or power on the power generation transport and/or provide
ancillary power where peak
electric power demand exceeds the electric power output of the gas turbine
generator transport. The
auxiliary gas turbine generator transport may comprise a smaller gas turbine
generator than the one
used in the power generation transport (e.g., provides about 1-8 MW of
electric power).
[0037] Also disclosed herein are various example embodiments of
implementing mobile
fracturing operations using a fracturing pump transport that comprises a dual
shaft electric motor
configured to drive at least two pumps. The dual shaft electric motor may be
an electric motor
configured to operate within a desired mechanical power range, such as about
1,500 horsepower
(HP) to about 10,000 HP. Each of the pumps may be configured to operate within
a desired
mechanical power range, such as about 1,500 HP to about 5,000 HP, to discharge
fracturing fluid at
relatively high pressures (e.g., about 10,000 pounds per square inch (PSI)).
In one embodiment, the
pumps may be plunger-style pumps that comprise one or more plungers to
generate the high-pressure
fracturing fluid. The fracturing pump transport may mount and couple the dual
shaft electric motor
to the pumps using sub-assemblies that isolate and allow operators to remove
the pumps and/or the
dual shaft electric motor individually and without disconnecting the
fracturing pump transport from
the mobile fracturing system.
[0038] The disclosure also includes various example embodiments of a
control network system
that monitors and controls one or more hydraulic fracturing equipment
remotely. The different
fracturing equipment, which include, but are not limited to, a blender,
hydration unit, sand handling
equipment, chemical additive system, and the mobile source of electricity, may
be configured to
operate remotely using a network topology, such as an Ethernet ring topology
network. The control
network system may remove implementing control stations located on and/or in
close proximity to
the fracturing equipment. Instead, a designated location, such as a data van
and/or a remote location
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Date Recue/Date Received 2021-06-24
away from the vicinity of the fracturing equipment may remotely control the
hydraulic fracturing
equipment.
[0039] FIG. 1 is a schematic diagram of an embodiment of a well site 100
that comprises a
wellhead 101 and a mobile fracturing system 103. Generally, a mobile
fracturing system 103 may
perform fracturing operations to complete a well and/or transform a drilled
well into a production
well. For example, the well site 100 may be a site where operators are in the
process of drilling and
completing a well. Operators may start the well completion process with
vertical drilling, running
production casing, and cementing within the wellbore. The operators may also
insert a variety of
downhole tools into the wellbore and/or as part of a tool string used to drill
the wellbore. After the
operators drill the well to a certain depth, a horizontal portion of the well
may also be drilled and
subsequently encased in cement. The operators may be subsequently pack the
rig, and a mobile
fracturing system 103 may be moved onto the well site 100 to perform
fracturing operations that
force relatively high pressure fracturing fluid through wellhead 101 into
subsurface geological
formations to create fissures and cracks within the rock. The fracturing
system 103 may be moved
off the well site 100 once the operators complete fracturing operations.
Typically, fracturing
operations for well site 100 may last several days.
[0040] To provide an environmentally cleaner and more transportable
fracturing fleet, the
mobile fracturing system 103 may comprise a mobile source of electricity 102
configured to generate
electricity by converting hydrocarbon fuel, such as natural gas, obtained from
one or more other
sources (e.g., a producing wellhead) at well site 100, from a remote offsite
location, and/or another
relatively convenient location near the mobile source of electricity 102.
Improving mobility of the
mobile fracturing system 103 may be beneficial because fracturing operations
at a well site typically
last for several days and the fracturing equipment is subsequently removed
from the well site after
completing the fracturing operation. Rather than using fuel that significantly
impacts air quality (e.g.,
diesel fuel) as a source of power and/or receiving electric power from a grid
or other type of
stationary power generation facility (e.g., located at the well site or
offsite), the mobile fracturing
system 103 utilizes a mobile source of electricity 102 as a power source that
burns cleaner while
being transportable along with other fracturing equipment. The generated
electricity from the mobile
source of electricity 102 may be supplied to fracturing equipment to power
fracturing operations at
one or more well sites. As shown in FIG. 1, the mobile source of electricity
102 may be implemented
using two transports in order to reduce the well site footprint and the
ability for operators to move
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Date Recue/Date Received 2021-06-24
the mobile source of electricity 102 to different well sites and/or different
fracturing jobs. Details
regarding implementing the mobile source of electricity 102 are discussed in
more detail in FIGS.
4A-6.
[0041] The mobile source of electricity 102 may supply electric power to
fracturing equipment
within the mobile fracturing system 103 that may include, but is not limited
to, at least one switch
gear transport 112, a plurality of drive power transports 104, at least one
auxiliary power transport
106, at least one blender transport 110, at least one data van 114 and a
plurality of fracturing pump
transports 108 that deliver fracturing fluid through wellhead 101 to
subsurface geological formations.
The switch gear transport 112 may receive the electricity generated from the
mobile source of electric
power 102 via one or more electrical connections. In one embodiment, the
switch gear transport 112
may use 13.8 kilovolts (KV) electrical connections to receive power from the
mobile source of
electric power 102. The switch gear transport 112 may comprise a plurality of
electrical disconnect
switches, fuses, transformers, and/or circuit protectors to protect the
fracturing equipment. The
switch gear transport 112 may transfer the electricity received from the
mobile source of electricity
102 to the drive power transports 104 and auxiliary power transports 106.
[0042] The auxiliary power transport 106 may comprise a transformer and a
control system to
control, monitor, and provide power to the electrically connected fracturing
equipment. In one
embodiment, the auxiliary power transport 106 may receive the 13.8 KV
electrical connection and
step down the voltage to 4.8 KV, which is provided to other fracturing
equipment, such as the
fracturing pump transport 108, the blender transport 110, sand storage and
conveyor, hydration
equipment, chemical equipment, data van 114, lighting equipment, and any
additional auxiliary
equipment used for the fracturing operations. The auxiliary power transport
106 may step down the
voltage to 4.8 KV rather than other voltage levels, such as 600 V, in order to
reduce cable size for
the electrical connections and the amount of cabling used to connect the
mobile fracturing system
103. The control system may be configured to connect to a control network
system such that the
auxiliary power transport 106 may be monitored and/or controlled from a
distant location, such as
the data van 114 or some other type of control center.
[0043] The drive power transports 104 may be configured to monitor and
control one or more
electrical motors located on the fracturing pump transports 108 via a
plurality of connections, such
as electrical connections (e.g., copper wires), fiber optics, wireless, and/or
combinations thereof The
connections are omitted from FIG. 1 for clarity of the drawing. The drive
power transports 104 may
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Date Recue/Date Received 2021-06-24
be part of the control network system, where each of the drive power
transports 104 comprise one
or more variable frequency drives (VFDs) used to monitor and control the prime
movers on the
fracturing pump transports 108. The control network system may communicate
with each of the
drive power transports 104 to monitor and/or control each of the VFDs. The
VFDs may be
configured to control the speed and torque of the prime movers by varying the
input frequency and
voltage to the prime movers. Using FIG. 1 as an example, each of the drive
power transports 104
may be configured to drive a plurality of the fracturing pump transports 108.
Other drive power
transport to fracturing pump transport ratios may be used as desired. In one
embodiment, the drive
power transports 104 may comprise air filters and blowers that intake ambient
air to cool the VFDs.
Other embodiments of the drive power transports 104 may use an air
conditioning units and/or water
cooling to regulate the temperature of the VFDs.
[0044] The fracturing pump transport 108 may receive the electric power
received from the drive
power transport 104 to power a prime mover. The prime mover converts electric
power to
mechanical power for driving one or more pumps. In one embodiment, the prime
mover may be a
dual shaft electric motor that drives two different pumps. The fracturing pump
transport 108 may be
arranged such that one pump is coupled to opposite ends of the dual shaft
electric motor and avoids
coupling the pumps in series. By avoiding coupling the pump in series, the
fracturing pump transport
108 may continue to operate when either one of the pumps fails or have been
removed from the
fracturing pump transport 108. Additionally, repairs to the pumps may be
performed without
disconnecting the system manifolds that connect the fracturing pump transport
108 to other
fracturing equipment within the mobile fracturing system 103 and wellhead 101.
Details regarding
implementing the fracturing pump transport 108 are discussed in more detail in
FIGS. 7A-7B.
[0045] The blender transport 110 may receive the electric power fed through
the auxiliary power
transport 106 to power a plurality of electric blenders A plurality of prime
movers may drive one or
more pumps that pump source fluid and blender additives (e.g., sand) into a
blending tub, mix the
source fluid and blender additives together to form fracturing fluid, and
discharge the fracturing fluid
to the fracturing pump transport 108. In one embodiment, the electric blender
may be a dual
configuration blender that comprises electric motors for the rotating
machinery that are located on a
single transport, which is described in more detail in U.S. Patent Application
Publication No.
2012/0255734, filed April 6, 2012 by Todd Coli et al. and entitled "Mobile,
Modular, Electrically
Powered System for use in Fracturing Underground Formations".
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Date Ma4e6E9Lte/Illateitenti20{212061C246-02
In another embodiment, a plurality of enclosed mixer hoppers may be used
to supply the proppants and additives into a plurality of blending tubs. The
electric blender that
comprises the enclosed mixer hoppers are discussed in more detail in FIGS. 9A
and 9B.
[00461 The data van 114 may be part of a control network system, where the
data van 114 acts
as a control center configured to monitor and provide operating instructions
in order remotely operate
the blender transport 110, the mobile source of electricity 102, and
fracturing pump transport 108
and/or other fracturing equipment within the mobile fracturing system 103. For
example, the data
van 114 may communicate via the control network system with the VFDs located
within the drive
power transports 104 that operate and monitor the health of the electric
motors used to drive the
pumps on the fracturing pump transports 108. In one embodiment, the data van
114 may
communicate with the variety of fracturing equipment using a control network
system that has a ring
topology. A ring topology may reduce the amount of control cabling used for
fracturing operations
and increase the capacity and speed of data transfers and communication.
Details regarding
implementing the control network system are discussed in more detail in FIG
10.
[00471 Other fracturing equipment shown in FIG. 1, such as gas conditioning
transport, water
tanks, chemical storage of chemical additives, hydration unit, sand conveyor,
and sandbox storage
are known by persons of ordinary skill in the art, and therefore are not
discussed in further detail. In
one or more embodiments of the mobile fracturing system 103, one or more of
the other fracturing
equipment shown in FIG. 1 may be configured to receive power generated from
the mobile source
of electricity 102. Additionally, as shown in FIG. 1, one or more embodiments
of the mobile
fracturing system 103 may not include the use of a missile that receives low-
pressure fluid and
releases high-pressure fluid towards the wellhead 101. The control network
system for the mobile
fracturing system 103 may remotely synchronizes and/or slaves the electric
blender of the blender
transport 110 with the electric motors of the fracturing pump transports 108
Unlike a conventional
diesel powered blender, the electric blenders may perform rate changes to the
pump rate change
mounted on the fracturing pump transports 108. In other words, if the pumps
within the fracturing
pump transports 108 perform a rate change increase, the electric blender
within a blender transport
110 may also automatically compensate its rate and ancillary equipment, such
as the sand conveyor,
to accommodate the rate change. Manual commands from an operator may not be
used to perform
the rate change.
Date Ma4e6E9Lte/Illateitenti20{212061C246-02
[0048] FIG. 2 is a schematic diagram an embodiment of a well site 200 that
includes a mobile
source of electricity 204 that comprises three transports for the mobile
fracturing system 202. The
mobile fracturing system 202 may be substantially similar to mobile fracturing
system 103, except
that mobile fracturing system comprises an auxiliary gas turbine generator
transport 206. The
auxiliary gas turbine generator transport 206 may be configured to provide
power to ignite, start, or
power on the mobile source of electricity 204 and/or provide ancillary power
where peak electric
power demand exceeds the electric power output of a gas turbine generator
transport. The auxiliary
gas turbine generator transport may comprise a smaller, gas turbine or diesel
generator that generates
less power (e.g., provides about 1-8 MW of electric power) than the one used
in the gas turbine
generator transport. Additionally or alternatively, the auxiliary gas turbine
generator transport 206
may provide testing, standby, peaking, and/or other emergency backup power
functionality for the
mobile fracturing system 202.
[0049] FIG. 2 illustrates that the mobile fracturing system 202 arranges
and positions the drive
power transport 104 and the auxiliary power transport 106 in an orientation
that is about parallel to
the switch gear transport 112 and the fracturing pump transports 108.
Positioning the drive power
transport 104 and the auxiliary power transport 106 in a parallel orientation
rather than about a
perpendicular orientation as shown in FIG. 1 may be beneficial, for example
reducing the foot print
of the mobile fracturing system 202. Moreover, FIG. 2 also illustrates that a
fuel source 208, such as
natural gas from a producing wellhead, may be located at the well site and be
used by the mobile
source of electricity 204 to generate electricity.
[0050] Although FIGS. 1 and 2 illustrate a specific configuration for a
mobile fracturing system
103 at a well site 100, the disclosure is not limited to that application
and/or the specific embodiment
illustrated in FIGS. 1 and 2. For instance, embodiments of the present
disclosure may include a
plurality of wellheads 101, a plurality of blender transports 110, and a
plurality of auxiliary power
transports 106 Additionally, the mobile source of electricity 102 is not
limited for use in a fracturing
operation and may be applicable to power other types of equipment and devices
not typically used
in a fracturing operation. The use and discussion of FIGS. 1 and 2 is only an
example to facilitate
ease of description and explanation.
[0051] FIG. 3 is a schematic diagram an embodiment of a well site 300 that
includes two
wellheads 101 and two data vans 114. The two data vans 114 may be part of the
control network
system that simultaneously monitors and provides operating instructions to the
two different
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Date Recue/Date Received 2021-06-24
wellheads 101. An additional blender transport 110 may be added to provide
fracturing fluid to
fracturing pump transports 108 used to fracture the subsurface geological
structure underneath the
second wellhead 101. Although FIG. 3 illustrates that both wellheads 101 are
located on the same
well site 300, other embodiments may have the wellheads 101 located at
different well sites.
[0052] Mobile Source of Electricity
[0053] The mobile source of electricity may be part of the mobile
fracturing system used at a
well site as described in FIGS. 1-3. ln other words, the mobile source of
electricity may be configured
to be transportable to different locations (e.g., different well sites) along
with other fracturing
equipment (e.g., fracturing pump transports) that are part of the mobile
fracturing system and may
not be left behind after completing fracturing operations. The mobile source
of electricity may
include at least two different transports that improve mobility of the
dedicated electric power by
simplifying and minimizing the operations for the mobilization and de-
mobilization process. For
example, the mobile source of electricity may improve mobility by enabling a
mobilization and de-
mobilization time period of about 24 hours. The mobile source of electricity
also incorporates a two
transport footprint, where the same two transport system may be used for
transportation and
operation modes. Although FIGS. 4A-6 illustrate embodiments of implementing a
mobile source of
electricity using two different transports, other embodiments of the mobile
source of electricity may
mount the gas turbine generator, air inlet filter housing, gas turbine exhaust
stack, and other
components shown in FIGS. 4A-6 on a different number of transports (e.g., all
on one transport or
more than two transports). To provide electric power for fracturing operations
at one or more
locations (e.g., well sites), the mobile source of electricity be designed to
unitize and mobilize a gas-
turbine and generator adapted to convert hydrocarbon fuel, such as natural
gas, into electricity.
[0054] FIGS. 4A and 4B are schematic diagrams of an embodiment of the gas
turbine generator
transport 400. FIG 4A illustrates a side-profile view of the gas turbine
generator transport 400 with
a turbine enclosure 402 that surrounds components within the gas turbine
generator transport 400
and includes cavities for the inlet plenum 404, exhaust collector 406, and an
enclosure ventilation
inlet 418. FIG. 4B illustrates a side-profile view of the gas turbine
generator transport 400 that depicts
the components within the turbine enclosure 402. As shown in FIG. 4B, the gas
turbine generator
transport 400 may comprise the following equipment: (1) an inlet plenum 404;
(2) a gas turbine 407
(e.g., General Electric (GE) 2500); (3) an exhaust collector 406; (4) a
generator 408; (5) a generator
breaker 410; and (6) a control system 412. Other components not shown in FIG.
4B, but which may
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Date Recue/Date Received 2021-06-24
also be located on the gas turbine generator transport 400 include a turbine
lube oil system, a fire
suppression system, and a generator lube oil system.
[0055] The gas turbine generator transport 400 includes the gas turbine 407
to generate
mechanical energy (i.e., rotation of a shaft) from a hydrocarbon fuel source,
such as natural gas,
liquefied natural gas, condensate, and/or other liquid fuels. As shown in FIG.
4B, the gas turbine
shaft is connected to the generator 408 such that the generator 408 converts
the supplied mechanical
energy from the rotation of the shaft to produce electric power. The gas
turbine 407 may be a gas
turbine, such as the GE LM2500 family of gas turbines, the Pratt and Whitney
FT8 gas turbines, or
any other gas turbine that generates enough mechanical power for a generator
408 to power
fracturing operations at one or more well sites. The generator 408 may be a
Brush BDAX 62-170ER
generator or any other generator configured to generate electric power for
fracturing operations at
one or more well sites. For example, the gas turbine 407 and generator 408
combination within a gas
turbine generator transport 400 may generate electric power from a range of at
least about 15
megawatt (MW) to about 35 MW. Other types of gas-turbine generators with power
ranges greater
than about 35 MW or less than about 15 MW may also be used depending on the
amount of power
needed at the well sites. In one embodiment, to increase mobility of the gas
turbine generator
transport 400, the gas turbine 407 may be configured to fit within a dimension
of about 14.5 feet
long and about four feet in diameter and/or the generator 408 may be
configured to fit within a
dimension of about 18 feet long and about 7 feet wide.
[0056] The generator 408 may be housed within the turbine enclosure 402
that includes air
ventilation fans internal to the generator 408 that draws air into the air
inlet located on the front
and/or back of the generator 408 and discharges air out on the sides via the
air outlets 414. Other
embodiments may have the air outlets positioned on different locations of the
enclosure for the
generator 408. In one embodiment, the air inlet may be inlet louvres and the
air outlets may be outlet
louvres that protect the generator from the weather elements A separate
generator ventilation stack
unit may be mounted on the top of the gas turbine generator transport 400.
[0057] The turbine enclosure 402 may also comprise gas turbine inlet
filter(s) configured to
provide ventilation air and combustion air via one or more inlet plenums 404
to the gas turbine 407.
Additionally, enclosure ventilation inlets 418 may be added to increase the
amount of ventilation air.
The ventilation air may be air used to cool the gas turbine 407 and ventilate
the gas turbine enclosure
402. The combustion air may be the air that is supplied to the gas turbine 407
to aid in the production
13
Date Recue/Date Received 2021-06-24
of the mechanical energy. The inlet plenum 404 may be configured to collect
the intake air from the
gas turbine inlet filter and supply the intake air to the gas turbine. The
exhaust collector 406 may be
configured to collect the air exhaust from the gas turbine and supply the
exhaust air to the gas turbine
exhaust stack.
[0058] To improve mobility of the gas turbine generator transport 400, the
air inlet filter housing
and the gas turbine exhaust stack are configured to be connected from at least
one of the sides of the
turbine enclosure 402, as opposed to connecting both the air inlet filter
housing and the gas turbine
exhaust stack on the top of the turbine enclosure 402 or connecting the air
inlet filter housing at one
end of the gas turbine generator transport 400 and connecting the exhaust
collector from the side of
the turbine enclosure 402. The air inlet filter housing and gas turbine
exhaust stack from the inlet
and exhaust transport may connect with the turbine enclosure 402 using one or
more expansion
connections that extend from one or both of the transports, located at the
sides of the turbine
enclosure 402. Any form of connection may be used that provides coupling
between the turbine
enclosure 402 and the air inlet filter housing and gas turbine exhaust stack
without using a crane,
forklift, and/or any other external mechanical means to connect the expansion
connections in place
and/or to connect the air inlet filter housing and gas turbine exhaust stack
to the side of the turbine
enclosure 402. The expansion connections may comprise a duct and/or an
expansion joint to connect
the air inlet filter housing and gas turbine exhaust stack to the turbine
enclosure 402. Additionally,
the routing of the air inlet filter housing and gas turbine exhaust stack via
the sides of the turbine
enclosure 402 may provide a complete aerodynamic modeling where the inlet air
flow and the
exhaust air flow are used to achieve the gas turbine nameplate output rating.
The inlet and exhaust
transport is discussed in more detail later in FIGS. 5A and 5B.
[0059] To improve mobility over a variety of roadways, the gas turbine
generator transport 400
in FIGS 4A and 4B may have a maximum height of about 13 feet and 6 inches, a
maximum width
of about 8 feet and 6 inches, and a maximum length of about 66 feet Further,
the gas turbine
generator transport 400 may comprise at least three axles used to support and
distribute the weight
on the gas turbine generator transport 400. Other embodiments of the gas
turbine generator transport
400 may be transports that exceed three axles depending on the total transport
weight. The
dimensions and the number of axles may be adjusted to allow for the transport
over roadways that
typically mandate certain height, length, and weight restrictions.
14
Date Recue/Date Received 2021-06-24
[0060] In one embodiment, the gas turbine 407 and generator 408 may be
mounted to an
engineered transport frame 416, a sub-base, sub-skid, or any other sub-
structure used to support the
mounting of gas turbine 407 and generator 408. The single engineered transport
frame may be used
to align the connections between the gas turbine 407, the generator 408, the
inlet plenum 404 and
the exhaust collector 406 and/or lower the gas turbine and generator by
configuring for a flush mount
to the single engineered transport frame 416. The single engineered transport
frame 416 may allow
for easier alignment and connection of the gas turbine 407 and generator 408
compared to using
separate sub-base for the gas turbine 407 and generator 408. Other embodiments
of the gas turbine
generator transport 400 may use a plurality of sub-bases, for example,
mounting the gas turbine 407
on one sub-base and mounting the generator 408 on another sub-base.
[0061] FIG. 4B illustrates that the generator breaker 410 and control
systems 412 may be located
on the gas turbine generator transport 400. The generator breaker 410 may
comprise one or more
circuit breakers that are configured to protect the generator 408 from current
and/or voltage fault
conditions. The generator breaker 410 may be a medium voltage (MV) circuit
breaker switchboard.
In one embodiment, the generator breaker may be about three panels, two for
the generator and one
for a feeder that protect relays on the circuit breaker. In one embodiment,
the generator breaker 410
may be vacuum circuit breaker. The control system 412 may be configured to
control, monitor,
regulate, and adjust the power output of the gas turbine 407 and generator
408. For example, the
control system 412 may monitor and balance the load produced by the fracturing
operations by
generating enough electric power to match the load demands. The control system
412 may also be
configured to synchronize and communicate with a control network system that
allows a data van or
other computing systems located in a remote location (e.g., off the well site)
to control, monitor,
regulate, and adjust power output of the generator 408. Although FIG. 4B
illustrates that the
generator breaker 410 and/or control system 412 may be mounted on the gas
turbine generator
transport 400, other embodiments of the mobile source of electricity may mount
the generator
breaker 410 and/or control system 412 in other locations (e.g. switch gear
transport)
[0062] Other equipment that may also be located on the gas turbine
generator transport 400, but
are not shown in FIGS. 4A and 4B include the turbine lube oil system, gas fuel
valves, generator
lube oil system, and fire suppression system. The lube oil systems or
consoles, which generally refer
to both the turbine lube oil system and generator lube oil system within this
disclosure, may be
configured to provide a generator and turbine lube oil filtering and cooling
systems. In one
Date Recue/Date Received 2021-06-24
embodiment, the turbine lube oil console area of the transport may also
contain the fire suppression
system, which may comprise sprinklers, water mist, clean agent, foam
sprinkler, carbon dioxide,
and/or other equipment used to suppress a fire or provide fire protection for
the gas turbine 407. The
mounting of the turbine lube oil consoles and the fire suppression system onto
the gas turbine
generator transport 400 reduces this transport's footprint by eliminating the
need for an auxiliary
transport and connections for the turbine and generator lube oil, filtering,
cooling systems and the
fire suppression system to the gas turbine generator transport. The turbine
and generator lube oil
systems may be mounted on a skid that is located underneath the generator 408
or any other location
on the gas turbine generator transport 400.
[0063] FIGS. 5A and 5B are schematic diagrams of embodiments of an inlet
and exhaust
transport 500. Specifically, FIG. 5A depicts the inlet and exhaust transport
500 while in
transportation mode and FIG. 5B depicts the inlet and exhaust transport 500
while in operational
mode. As shown in FIGS. 5A and 5B, the inlet and exhaust transports 500
include an air inlet filter
housing 502 and a gas turbine exhaust stack 504. Although not shown in FIGS.
5A and 5B, one or
more gas turbine inlet filters and ventilation fans may be located within or
housed in the air inlet
filter housing 302.
[0064] FIGS. 5A and 5B illustrate that the air inlet filter housing 502 may
be mounted on the
inlet and exhaust transport 500 at a fixed location. Other embodiments of the
inlet and exhaust
transport 500 may mount the air inlet filter housing 502 with a configuration
such that the air inlet
filter housing 502 may slide in one or more directions when transitioning
between operational
mode and transportation mode. For example, as shown in FIG. 5C, the air inlet
filter housing 502
may slide out for operational mode and slide back for transport mode. Sliding
the air inlet filter
housing 502 may be used to align the air inlet filter housing 502 with the
inlet plenum of the gas
turbine enclosure mounted on the gas turbine generator transport In another
embodiment, the air
inlet filter housing 502 may be mounted on a turntable with the ability to
engage the inlet plenum
of the gas turbine enclosure mounted on the gas turbine generator transport.
The air inlet filter
housing 502 may comprise a plurality of silencers that reduce noise. The
different embodiments
for mounting the air inlet filter housing 502 may depend on the amount of
clean air and the air
flow dynamics needed to supply the gas turbine for combustion.
[0065] The gas turbine exhaust stack 504 may comprise the gas turbine
exhaust 508, an exhaust
extension 506 configured for noise control, and an exhaust end connector 510.
The exhaust extension
16
Date Recue/Date Received 2021-06-24
506 may comprise a plurality of silencers that reduce noise from the inlet and
exhaust transport 500.
As shown in FIG. 5A, the gas turbine exhaust stack 504 may be mounted to
initially lie on its side
during transportation mode. In operational mode, the gas turbine exhaust stack
504 may be rotated
up without using external mechanical means such that the gas turbine exhaust
stack 504 is mounted
to the inlet and exhaust transport 500 on its base and in the upright
position. In operational mode,
the gas turbine exhaust stack 504 may be positioned using hydraulics,
pneumatics, and/or electric
motors such that it aligns and connects with the exhaust end connector 510 and
exhaust collector of
the gas turbine enclosure shown in FIGS. 4A and 4B.
[0066] The exhaust end connector 510 may be adjusted to accommodate and
align the gas
turbine exhaust stack 504 with the exhaust collector of the gas turbine
enclosure. In operational
mode, the exhaust end connector 510 may move forward in a side direction,
which is in the direction
toward the gas turbine enclosure. The exhaust end connector 510 may move
backward in the side
direction, which is in the direction away from the gas turbine enclosure, when
transitioning to the
transportation mode. Other embodiments of the gas turbine exhaust stack 504
may have the gas
turbine exhaust 508 and the exhaust end connector 510 connected as a single
component such that
the exhaust end connector 510 and the gas turbine exhaust stack 504 are
rotated together when
transitioning between the transportation and operational modes.
[0067] In another embodiment, during transport, the gas turbine exhaust
stack 504 may be
sectioned into a first section and a second section. For example, the first
section may correspond to
the gas turbine exhaust 508 and the second section may correspond to the
exhaust extension 506.
The first section of the gas turbine exhaust stack 508 may be in the upright
position and the second
section of the gas turbine exhaust stack 506 may be mounted adjacent to the
first section of the gas
turbine exhaust for transport. The first section and the second section may be
hinged together such
that the second section may be rotated up to stack on top of the first section
for operation. In another
embodiment, the gas turbine exhaust stack 504 may be configured such that the
entire gas turbine
exhaust stack 504 may be lowered or raised while mounted on the inlet and
exhaust transport 500.
[0068] Typically, the air inlet filter housing 502 and gas turbine exhaust
stack 504 may be
transported on separate transports and subsequently crane lifted onto the top
of gas turbine enclosure
and mounted on the gas turbine generator transport during operation mode. The
separate transports
to carry the air inlet filter housing 502 and gas turbine exhaust stack 504
may not be used during
operational mode. However, by adapting the air inlet filter housing 502 and
gas turbine exhaust stack
17
Date Recue/Date Received 2021-06-24
504 to be mounted on a single transport and to connect to at least one of the
sides of the gas turbine
enclosure mounted on the gas turbine generator transport, the inlet and
exhaust transport may be
positioned alongside the gas turbine generator transport and subsequently
connect the air inlet and
exhaust plenums for operations. The result is having a relatively quick rig-up
and/or rig-down that
eliminates the use of heavy lift cranes, forklifts, and/or any other external
mechanical means at the
operational site.
[0069] FIG. 6 is a schematic diagram of an embodiment of the two transport
mobile electric
power source 600 when in operational mode. FIG. 6 illustrates a top-down-view
of the coupling
between the inlet and exhaust transport 500 and the gas turbine transport 400
during operational
mode. The exhaust expansion connection 602 may move and connect (e.g., using
hydraulics) to the
exhaust end connector 510 without using external mechanical means in order to
connect the gas
turbine exhaust stack of the inlet and exhaust transport with the exhaust
collector of the gas turbine
generator transport. The inlet expansion connections 604 may move and connect
the air inlet filter
housing of the inlet and exhaust transport and the inlet plenum of the gas
turbine generator transport.
The two transports 400 and 500 may be parked at a predetermined orientation
and distance such that
the exhaust expansion connection 602 and inlet expansion connections 604 are
able to connect the
two transports 400 and 500.
[0070] In one embodiment, to adjust the positioning, alignment, and
distance in order to
connect the two transports 400 and 500, each of the transports 400 and 500 may
include a hydraulic
walking system. For example, the hydraulic walking system may move and align
transport 500
into a position without attaching the two transports 400 and 500 to
transportation vehicles (e.g., a
tractor or other type of motor vehicle). Using FIGS. 4 and 5 as an example,
the hydraulic walking
system may comprise a plurality of outriggers and/or support feet 412 used to
move transport 400
and/or transport 500 back and forth and/or sideways At each outrigger and/or
support feet 412,
the hydraulic walking system may comprise a first hydraulic cylinder that
lifts the transport and a
second hydraulic cylinder that moves the transport in the designated
orientation or direction. A
hydraulic walking system on the transport increases mobility by reducing the
precision needed
when parking the two transports next to each other.
[0071] FIG. 11 is a flow chart of an embodiment of a method 1100 to provide
a mobile source
of electricity for fracturing operations. Method 1100 may start at block 1102
by transporting a mobile
source of electricity with other fracturing equipment to a well site that
comprises a non-producing
18
Date Recue/Date Received 2021-06-24
well. Method 1100 may then move to block 1104 and convert the mobile source of
electricity from
transportation mode to operational mode. The same transports may be used
during the conversation
from transportation mode to operational mode. In other words, transports are
not added and/or
removed when setting up the mobile source of electricity for operational mode.
Additionally, method
1100 be performed without the use of a forklift, crane, and/or other external
mechanical means to
transition the mobile source of electricity into operational mode. The
conversion process for a two
transport trailer is described in more detail in FIGS. 4A-6.
[0072] Method 1100 may then move to block 1106 and generate electricity
using the mobile
source of electricity to power fracturing operations at one or more well
sites. In one embodiment,
method 1100 may generate electricity by converting hydrocarbon fuel into
electricity using a gas
turbine generator. Method 1100 may then move to block 1108 and convert the
mobile source of
electricity from operational mode to transportation mode. Similar to block
1104, the conversion
process for block 1108 may use the same transports without using a forklift,
crane, and/or other
external mechanical means to transition the mobile source of electricity back
to transportation mode.
Method 1100 may then move to block 1110 to remove the mobile source of
electricity along with
other fracturing equipment from the well site once fracturing operations are
completed.
[0073] Fracturing Pump Transport
[0074] FIGS. 7A and 7B are schematic diagrams of embodiments of a
fracturing pump transport
700 powered by the mobile source of electricity as described in FIGS. 4A-6.
The fracturing pump
transport 700 may include a prime mover 704 powering two separate pumps 702A
and 702B. By
combining a single prime mover 704 attached to two separate pumps 702A and
702B on a transport,
a fracturing operation may reduce the amount of pump transports, prime movers,
variable frequency
drives (VFD' s), ground iron, suction hoses, and/or manifold transports.
Although FIGS. 7A and 7B
illustrates that the fracturing pump transport 700 supports a single prime
mover 704 power two
separate pumps 702A and 702B, other embodiments of the fracturing pump
transport 700 may
include a plurality of prime movers 704 that each power the pumps 702A and
702B.
[0075] A "lay-down" trailer 710 design may provide mobility, improved
safety, and enhanced
ergonomics for crew members to perform routine maintenance and operations of
the pumps as the
"lay-down" arrangement positions the pumps lower to the ground as the main
trailer beams are
resting on the ground for operational mode. As shown in FIGS. 7A and 7B, the
"lay-down" trailer
710 has an upper section above the trailer axles that could hold or have
mounted the fracturing pump
19
Date Recue/Date Received 2021-06-24
trailer power and control systems 708. The fracturing pump trailer power and
control system 708
may comprise one or more electric drives, transformers, controls (e.g., a
programmable logic
controller (PLC) located on the fracturing pump transport 700), and cables for
connection to the
drive power trailers and/or a separate electric pumper system. The electric
drives may provide
control, monitoring, and reliability functionality, such as preventing damage
to a grounded or shorted
prime mover 704 and/or preventing overheating of components (e.g.,
semiconductor chips) within
the electric drives. The lower section, which may be positioned lower than the
trailer axles, may hold
or have mounted the prime mover 704 and the pumps 702A and 702B attached on
opposite sides of
each other.
[0076] In one embodiment, the prime mover 704 may be a dual shaft electric
motor that has a
motor shaft that protrudes on opposite sides of the electric motor. The dual
shaft electric motor may
be any desired type of alternating current (AC) or direct current (DC) motor.
In one embodiment,
the dual shaft electric motor may be an induction motor and in another
embodiment the dual shaft
electric motor may be a permanent magnet motor. Other embodiments of the prime
mover 704 may
include other electric motors that are configured to provide about 5,000 HP or
more. For example,
the dual shaft electric motor may deliver motor power in a range from about
1,500 HP to about
10,000 HP. Specific to some embodiments, the dual shaft electric motor may be
about a 5,000 HP
rated electric motor or about a 10,000 HP electric motor. The prime mover 704
may be driven by at
least one variable frequency drive that is rated to a maximum of about 5,000
HP and may receive
electric power generated from the mobile source of electric power.
[0077] As shown in FIGS. 7A and 7B, one side of the prime mover 704 drives
one pump 702A
and the opposite side of the prime mover 704 drives a second pump 702B. The
pumps 702A and
702B are not configured in a series configuration in relation to the prime
mover 704. In other words,
the prime mover 704 independently drives each pump 702A and 702B such that if
one pump fails,
it can be disconnected and the other pump can continue to operate. The prime
mover 704, which
could be a dual shaft electric motor, eliminates the use of diesel engines and
transmissions.
Moreover, using a dual shaft electric motor on a transport may prevent
dissonance or feedback when
transferring power to the pumps. In one embodiment, the prime mover 704 may be
configured to
deliver at least about 5,000 HP distributed between the two pumps 702A and
702B. For instance,
prime mover 704, which may be a dual shaft electric motor, may provide about
2,500 HP to one of
the pumps 702A and about 2,500 HP to the other pump 702B in order to deliver a
total of about
Date Recue/Date Received 2021-06-24
5,000 HP. Other embodiments may have the prime mover 704 deliver less than
5,000 HP or more
than 5,000 HP. For example, the prime mover 704 may deliver a total of about
3,000 HP by
delivering about 1,500 HP to one of the pumps and about 1,500 HP to the other
pump. Another
example may have the prime mover 704 deliver a total of about 10,000 HP by
delivering about 5,000
HP to one of the pumps 702A and about 5,000 HP to another pump 702B.
Specifically, in one or
more embodiments, the prime mover 704 may operate at HP ratings of about 3,000
HP, 3,500 HP,
4,000 HP, 4,500 HP, 5,000 HP, 5,200 HP, 5,400 HP, 6,000 HP, 7,000 HP, 8,000
HP, 9,000 HP,
and/or 10,000 HP.
[0078] The fracturing pump transport 700 may reduce the footprint of
fracturing equipment on
a well-site by placing two pumps 702A and 702B on a single transport. Larger
pumps may be
coupled to a dual shaft electric motor that operates with larger horse power
to produce additional
equipment footprint reductions. In one embodiment, each of the pumps 702A and
702B may be
quintiplex pumps located on a single transport. Other embodiments may include
other types of
plunger style pumps, such as triplex pumps. The pumps 702A and 702B may each
operate from a
range of about 1,500 HP to about 5,000 HP. Specifically, in one or more
embodiments, each of the
pumps 702A and 702B may operate at HP ratings of about 1,500 HP, 1,750 HP,
2,000 HP, 2,250
HP, 2,500 HP, 2,600 HP, 2,700 HP, 3,000 HP, 3,500 HP, 4,000 HP, 4,500 HP,
and/or 5,000 HP. The
pumps 702A and 702B may not be configured in a series configuration where the
prime mover 704
drives a first pump 702A and the first pump 702B subsequently drives a second
pump 702B.
[0079] FIG. 7A also illustrates that each pump 702A and 702B, which may
also be generally
referred to in this disclosure as pump 702, is mounted on the fracturing pump
transport 700 with the
same orientation. In particular, each pump 702 is mounted such that the fluid
end assembly 716 for
each pump 702 is facing the same side of the fracturing pump transport 700.
Additionally, in FIG.
7A, the power end assembly 718 for each pump 702 is facing the same side of
the fracturing pump
transport 700 In other words, for a given pump 702 (e.g., pump 702A), the
fluid end assembly 716
and power end assembly 718 are located on opposite sides of the fracturing
pump transport 700. As
shown in FIG. 7A, both the fluid end assembly 716 and power end assembly 718
of a pump 702 may
face sides of the fracturing pump transport 700 that are about orthogonal or
perpendicular to the front
end 720 and back end 722 of the fracturing pump transport 700. Having the
fluid end side 716 of
each pump 702 face the same side of the fracturing pump transport 700 may be
beneficial by
simplifying and reducing the amount of plumbing used to route both the low
pressure fluid line and
21
Date Recue/Date Received 2021-06-24
high pressure fluid line into and out of the fracturing pump transport 700.
For example, if pump
702A' s and 702B' s fluid end assembly 716 are facing opposite sides of the
fracturing pump transport
700, the fracturing pump transport 700 may include plumbing that routes both
the low pressure fluid
lines and high pressure fluid lines on both sides of the fracturing pump
transport 700. Alternatively,
if pump 702A' s and 702B' s fluid end assembly 716 are facing the same side of
the fracturing pump
transport 700, at least a majority of the plumbing that routes both the low
pressure fluid lines and
high pressure fluid lines could be located on one side of the fracturing pump
transport 700.
[0080] In one embodiment, to mount both pumps 702 where the fluid end
assemblies 716 are
facing the same side of the fracturing pump transport 700, one of the pumps
702 (e.g., pump 702B)
may be configured with a right-side pinion while the other pump 702 (e.g.,
pump 702A) is configured
with a pinion located on the opposite side of the pump 702, which can be
referred to as a left-side
pinion. In particular, a pump 702 with a right-side pinion may be designated
to mount to a specific
side of the prime mover 704, such as the side of the prime mover 704 facing
the back end 722 (e.g.,
the end with trailer axles), and the pump 702 with a left-side pinion may be
designated to mount on
the other side of the prime mover 704, such as the side of the prime mover 704
facing the front end
720 (e.g., trailer hitch). Because the pumps 702 are located on opposite sides
of the prime mover
704, placing pinions on different sides of the pumps 702 allows the fluid end
assembly 716 for each
pump 702 to face the same side of the fracturing pump transport 700.
[0081] In another embodiment, the fracturing pump transport 700 may include
one or more
pumps 702 configured with a dual pinion 724. A pump 702 with the dual pinion
configuration would
include both a left-side pinion and a right-side pinion. FIG. 7B illustrates
that each pump 702A and
702B has a dual pinion 724, where the two pinion ends are located on opposite
sides of each other.
Having pumps 702 configured with a dual pinion 724 provides additional
flexibility compared to
pumps 702 with either a right-side pinion or a left-side pinion. Specifically,
a pump 702 with a dual
pinion 724 may be able to mount on either side of the prime mover 704 while
having the fluid end
assembly 716 for each pump 702 face the same side of the fracturing pump
transport 700.
[0082] Another advantage of having the fluid end assemblies 716 face the
same side of the
fracturing pump transport 700 is to avoid damaging the pump 702 at different
loads and/or requiring
mounting of a custom fracturing pump. In embodiments where the fluid end
assemblies 716 are
facing opposite directions, the pinions for pumps 702A and 702B may be
rotating in opposite
directions when driven by the prime mover 704. A pinion, whether a right-
pinion, left-pinion, or a
22
Date Recue/Date Received 2021-06-24
dual pinion 724, may be located within the power end assembly 718 and includes
a pinion shaft and
one or more pinion gears configured to generate rotational movement of the
power end assembly
718. The rotational movement may generate torque that moves the plungers in
the fluid end assembly
716 used to pump and pressurize fracturing fluid. To produce torque,
typically, a pinion gear may
interface with a bull gear that drives a crankshaft, which in turn moves the
fluid end plungers. The
pinion gear and the bull gear are commonly helical gears configured to engage
with each other by
rotating in a specified direction. If the pinion shaft, pinion gear, and bull
gear are rotated in a direction
opposite to the designed direction, the pinion gear may turn the bull gear
until the pinion gear
generates enough torque to break the bull gear and damage the pump 702. To
avoid damaging the
pumps 702, one of the pumps 702 would need to be customized to provide torque
when the pinion
rotates in a direction opposite of conventional fracturing pumps. Including a
customized fracturing
pump on the fracturing pump transport 700 could not only lead to an increase
in manufacturing cost,
but also decrease operational and maintenance flexibility by requiring pumps
702A and 702B to be
mounted on designated sides of the prime mover 704.
[00831 The
prime mover 704 and each of the pumps 702A and 702B may be mounted on sub-
assemblies configured to be isolated and allow for individual removal from the
fracturing pump
transport. In other words, the prime mover 704 and each of the pumps 702A and
702B can be
removed from service and replaced without shutting down or compromising other
portions of the
fracturing system. The prime mover 704 and pumps 702A and 702B may be
connected to each other
via couplings that are disconnected when removed from the fracturing pump
transport 700. If the
prime mover 704 needs to be replaced or removed for repair, the prime mover
sub-assembly may be
detached from the fracturing pump transport 700 without removing the two pumps
702A and 702B
from the fracturing pump transport. For example, pump 702A can be isolated
from the fracturing
pump transport 700, removed and replaced by a new pump 702A If the prime mover
704 and/or the
pumps 702A and 702B requires service, an operator can isolate the different
components from the
fluid lines, and unplug, un-pin, and remove the prime mover 704 and/or the
pumps 702A and 702B
from the fracturing pump transport. Furthermore, each pump 702A and 702B sub-
assembly may be
detached and removed from the fracturing pump transport 700 without removal of
the other pump
and/or the prime mover 704. As such, the fracturing pump transport 700 may not
need to be
disconnected from the manifold system and driven out of the location. Instead,
replacement prime
23
Date Recue/Date Received 2021-06-24
mover 704 and/or the pumps 702A and 702B may be placed backed into the line
and reconnected to
the fracturing pump transport 700.
[0084] To implement the independent removal of the sub-assemblies, the two
pumps 702A and
702B may be coupled to the prime mover 704 using a drive line assembly 706
that is adapted to
provide remote operation that engages and/or disengages one or both pumps 702A
and 702B from
the prime mover 704. The drive line assembly 706 may comprise one or more
couplings and one or
more drive shafts. For example, the drive line assembly 706 may comprise a
fixed coupling that
connects to one of the pumps 702A or 702B, a keyed shaft 712, and an
engagement coupling (e.g.,
spline-tooth coupling 714). The keyed shaft 712 may interconnect the fixed
coupling (e.g., a flex
coupling or universal joint-based coupling) to a spline-tooth coupling 714
that attaches to the prime
mover 704. The fixed coupling may directly connect the keyed shaft 712 to the
pinion of the pump
or indirectly connect the keyed shaft 712 to the pinion of the pump using a
pump drive shaft. To
engage and/or disengage one or both pumps 702A and 702B from the prime mover
704, the spline-
tooth coupling 714 may include a splined sliding sleeve coupling and a motor
coupling that provides
motor shaft alignment with the keyed shaft 712. Hydraulic fluid and/or
mechanical power may be
used to adjust the splined sliding sleeve coupling to engage and/or disengage
the pumps 702A and
702B from the prime mover 704. Other embodiments of couplings that may be used
to engage and/or
disengage the keyed shaft 712 from the prime mover 704 may include torque
tubes, air clutches,
electro-magnetic clutches, hydraulic clutches, and/or other clutches and
disconnects that have
manual and/or remote operated disconnect devices.
[0085] FIG. 13 is a schematic diagram of an embodiment of a fracturing pump
transport 1300
configured to remotely engage and/or disengage one or more pumps 702 from the
prime mover
704. Although FIG. 13 illustrates that the prime mover 704 is a dual-shaft
electric motor, other
embodiments of the fracturing pump transport 1300 may use other types of
electric motors, such
an electric motor that has only one shaft extending outward As shown in FIG.
13, the fracturing
pump transport 1300 may comprise an engagement panel 1302 and a monitoring
station 1304,
such as a human monitoring interface (HMI) station. The engagement panel 1302
may include a
control system that adjusts an engagement coupling to transition between an
engaged and a
disengaged position. In one embodiment, the engagement panel 1302 may include
levers or
switches that an operator may manually operate to engage or disengage the
keyed shaft 712 from
the motor shaft using the engagement coupling. Additionally or alternatively,
the engagement
24
Date Recue/Date Received 2021-06-24
panel 1302 may include electronic controllers that receive instructions from
remote locations, such
as a monitoring station 1304, another location at the well site (e.g., data
van), and/or off-site to
engage and/or disengage the pumps 702 from the prime mover 704. In response to
receiving a
remote command, the engagement panel 1302 may trigger the engagement and/or
disengagement
of one or more of the pumps from the prime mover 704. For instance, if pump
702A was
disengaged and pump 702B was engaged, in response to receiving the remote
command, the
engagement panel 1302 may trigger the engagement of pump 702A and
disengagement of pump
702B. The remote command may also produce a result where both pumps 702 are
disengaged or
engaged with the prime mover.
[00861 The engagement panel 1302 may vary its mounting location on the
fracturing pump
transport 1300 and the control mechanism used to engage and/or disengage the
pumps 702 from
the prime mover 704. Although FIG. 13 illustrates the engagement panel 1302 is
located at the
front end of the fracturing pump transport 1300, other embodiments could have
the engagement
panel 1302 located at other locations, such as being part of the trailer power
and control systems
708 and/or closer in proximity to the trailer power and control systems 708.
The control mechanism
implemented by the engagement panel 1302 may be based on the type of
engagement coupling
used to engage or disengage the pumps 702 and prime mover 704. For example,
the engagement
panel 1302 may be a hydraulic control bank, which is discussed in more detail
in FIGS. 15A and
15B that include hydraulic controllers (e.g., hydraulic and electronic control
valves) that manage
hydraulic fluid pressure when the engagement coupling is a splined tooth
coupling.
[0087] The monitoring station 1304, which may be part of the trailer power
and control
systems 708, may include hardware and/or software that allow an operator to
manage and control
(e.g., provide instructions) the engagement panel 1302 to engage and/or
disengage the pumps 702
from the prime mover 704. For example, the monitoring station 1304 may be
configured with a
safety control system that prevents the execution of engagement and/or
disengagement instructions
when the prime mover and/or pumps are operational. In one embodiment, the
monitoring station
1304 may also include network components for receiving remote engagement or
disengagement
instructions by connecting to a control network system that communicates with
other fracturing
equipment and/or control systems. The control network system is described in
more detail in FIG.
10.
Date Recue/Date Received 2021-06-24
[00881 The fracturing pump transport 1300 may also include proximity
sensors (not shown in
FIG. 13) used to determine whether the engagement coupling is in an engagement
or disengagement
position when performing remote monitoring at the monitoring station 1304,
another location at the
well site (e.g., data van), and/or off-site. In one embodiment, the proximity
sensors may be coupled
to the engagement coupling and/or located in close proximity to the engagement
coupling to
determine whether the pumps 702 are engaged and/or disengaged with the prime
mover 704.
Information obtained from the proximity sensors may also be useful in allowing
the monitoring
station 1304 and/or other control systems that are part of the control network
system (e.g., data van)
to determine the number of operating pumps (e.g., none, one, or two) for
fracturing pump transport
1300. An operator and/or control system may use the number of pumps to
accurately measure the
fluid pumping rate during operations.
[0089] FIGS. 14A and 14B are schematic diagrams of an embodiment of a drive
line assembly
1400 used to remotely engage and/or disengage a pump from a prime mover. FIG.
14A illustrates
that the engagement coupling 1410 is in an engagement position while FIG. 14B
illustrates that the
engagement coupling 1410 is in a disengagement position. When manual and/or
remote instructions
are sent to move the engagement coupling 1410 into an engaged position, the
engagement coupling
1410 may translate the rotational movement from the motor shaft 1408 of the
prime mover to the
keyed shaft (e.g., a driveline shaft or pump pinion). In a disengaged
position, the engagement
coupling 1410 disengages the keyed shaft from the motor shaft 1408 of the
prime mover such that
the rotational movement is not translated to the keyed shaft even though the
motor shaft 1408
continues to rotate. For FIGS. 14A and 14B, the keyed shaft would be located
underneath the shaft
cover 1406 used to mount the proximity sensors 1404A and 1404B.
[0090] FIGS. 14A and 14B also illustrate that the engagement coupling 1410
includes a spline-
tooth coupling with a sleeve that moves back in forth using hydraulic
cylinders 1402 (e.g., hydraulic
rams). When the hydraulic cylinders 1402 move the sleeve in a designated
direction (e.g., in the
direction of the pump) the spline-tooth coupling may engage the keyed shaft
and transfer rotational
movement from the motor shaft 1408 to the keyed shaft. When the hydraulic
cylinders 1402 move
the sleeve an opposite direction (e.g., in the direction of the prime mover),
the spline-tooth coupling
may disengage the keyed shaft and isolate the rotational movement the motor
shaft 1408 generates
from the keyed shaft. Other embodiments, may use mechanical power instead of
hydraulic power to
move the sleeves of the spline-tooth coupling. As shown in FIGS 14A and 14B,
the motor shaft 1408
26
Date Recue/Date Received 2021-06-24
may refer to one end of the dual shaft that protrudes out of the prime mover.
Other embodiments
could have the motor shaft 1408 be a drive line shaft that is coupled to one
end of the dual shaft of
the prime mover. In other words, the engagement coupling 1410 may directly or
indirectly connect
the keyed shaft engagement coupling 1410 to a prime mover.
[0091] The drive line assembly 1400 may also include one or more proximity
sensors 1404A
and 1404B to determine the position of the engagement coupling 1410, and one
or more fixed
couplings 1412 used to directly or indirectly couple the keyed shaft with a
pump pinion. In FIG.
14A, the proximity sensor 1404A may detect when the engagement coupling 1410
is in an
engagement position, and in FIG. 14B, the proximity sensor 1404B may detect
when the engagement
coupling 1410 has moved to a disengagement position FIGS. 14A and 14B also
depict fixed
couplings 1412 that couples the keyed shaft to a pump pinion. The drive line
assembly 1400 may
vary the number of fixed couplings 1412 and intermediate drive shafts based on
space availability,
misalignment tolerances, and whether vibrations from the pump need to be
deflected to avoid
affecting the operation of the prime mover. Additionally, in one or more
embodiments, the pump's
pinion may move or walk slightly axially (e.g., 1/16ths of an inch). Having
fixed couplings 1412 and
intermediate drive shafts may allow the pump's pinion shaft to move or walk
slightly without
damaging the motor shaft and/or bearings of the prime mover. Examples of fixed
couplings 1412
may include, but are not limited to, flex couplings and/or universal joint-
based coupling.
[0092] Although FIGS. 14A and 14B illustrate a specific embodiment of a
drive line assembly
1400, the disclosure is not limited to the specific embodiment illustrated in
FIGS. 14A and 14B.
For instance, engagement coupling 1410 may be implemented using other types of
coupling, such
as torque tubes, air clutches, electro-magnetic clutches, hydraulic clutches.
The type of
engagement coupling 1401 may then determine what powers the engagement and/or
disengagement operation, such as hydraulic, mechanical, and/or electric power.
Additionally, the
engagement coupling 1410 may be configured to statically and/or dynamically
engage and/or
disengage the keyed shaft from the motor shaft 1408. In a static engagement
and/or disengagement,
the pumps and/or prime mover may not be operational when engagement or
disengagement occurs.
For instance, the motor shaft 1408 is not rotating when performing static
engagement and/or
disengagement. In a dynamic engagement and/or disengagement, the pumps, prime
mover and/or
motor shaft 1408 are rotating when engagement and/or disengagement occurs. For
example, rather
than using a spline-tooth coupling, the drive line assembly 1400 may use an
air clutch to perform
27
Date Recue/Date Received 2021-06-24
dynamic engagement or disengagement. The use and discussion of FIGS. 14A and
14B is only an
example to facilitate ease of description and explanation.
[0093] FIG. 15A is a schematic diagram of an embodiment of an engagement
panel 1500
configured to cause remote engagement and/or disengagement of one or more
pumps with a prime
mover, and FIG. 15B is a schematic diagram of an embodiment of a hydraulic
control bank 1502
located within an engagement panel 1500. FIG. 15A illustrates that the
engagement panel 1500
includes a hydraulic control bank 1502 with one or more hydraulic levers 1504
that operators may
manually operate to trigger engagement and/or disengagement of one or more
pumps from a prime
mover. As shown in FIG. 15B, adjusting the hydraulic levers 1504 may activate
hydraulic control
valves 1506 that adjust hydraulic fluid pressures to move an engagement
coupling, such as a spline-
tooth coupling, to an engagement and/or disengagement position. The hydraulic
control bank 1502
may also include electronic control valves 1508 that adjust hydraulic fluid
pressures based on
instructions received from a remote location, such as a monitoring station,
another location at the
well site (e.g., data van), and/or off-site. In one embodiment, the electronic
control valves 1508
may include one or more electronic solenoids that adjust the hydraulic fluid
pressures to engage
and/or disengage one or more pumps from the prime mover. Additionally or
alternatively, the
engagement panel 1500 may also be configured to prevent engagement and/or
disengagement
while the motor shaft of the prime mover is rotating (e.g., when an operator
attempts to adjust the
hydraulic levers and/or remote instructions are received) in instances the
engagement coupling is
configured to only perform static engagement and/or disengagement.
[0094] FIG. 12 is a flow chart of an embodiment of a method 1200 to pump
fracturing fluid
into a wellhead. Method 1200 starts at block 1202 and receives electric power
to power at least
one prime mover. The prime mover may be a dual-shaft electric motor located on
a fracturing
pump transport as shown in FIGS. 7A and 7B. Method 1200 may then move to block
1204 and
receive fracturing fluid produced from one or more blenders. In one
embodiment, the blenders
may be electric blenders that includes enclosed mixer hoppers.
[0095] Method 1200 then moves to block 1206 and drives one or more pumps
using the at least
one prime mover to pressurize the fracturing fluid. In one embodiment, the
pumps may be positioned
on opposite sides and may be both driven by a single shaft from the dual-shaft
electric motor when
the engagement couplings for both pumps are in engagement position. In other
words, when two
28
Date Recue/Date Received 2021-06-24
pumps are operating and engaged, method 1200 may drive the two pumps in a
parallel configuration
instead of a serial configuration. If one of the pumps are removed and/or
disengaged, method 1200
may continue to drive the remaining pump. Method 1200 may receive engagement
and/or
disengagement instructions manually and/or from a remote location to engage
and/or disengaged the
pumps prior to or while driving the pumps. Method 1200 may then move to block
1208 and pump
the pressurized fracturing fluid into a wellhead.
[0096] Blender Transport
[0097] FIGS. 8A and 8B are schematic diagrams of an embodiment of a blender
transport 800
that includes an electric blender 806. FIG. 8A illustrates a top-down view of
the blender transport
800 and FIG. 8B illustrates a side-profile view of the blender transport 800.
The blender transport
800 may be powered by the mobile source of electricity as described in FIGS. 1-
6. The electric
blender 806 may be a dual configuration blender, as described in U.S. Patent
Application Publication
2012/0255734, with a blending capacity of about 240 bpm. The dual
configuration blender may
comprise electric motors for all rotating machinery and may be mounted on a
single transport. The
dual configuration blender may have two separate blending units that are
configured to be
independent and redundant. For example, any one or both the blending units may
receive a source
fluid via inlet manifolds of the blending units. The source fluid may
originate from the same source
or different sources. The source fluid may subsequently be blended by any one
or both of the
blending tub and subsequently discharged out of any one or both outlet
manifolds of the blending
units. Other embodiments of the blender transport 800 may be single
configuration blender that
includes a single blending unit.
[0098] FIGS. 8A and 8B illustrate a "lay-down" trailer 802 design that
provides mobility and
improves ergonomics for the crew members that perform routine maintenance and
operations of the
electric blender 806 as the "lay-down" positions the blender tubs, pumps and
piping lower to the
ground level and the main trailer beams are resting on the ground for
operational mode.
[0099] Similar to the "lay-down" trailer 710, the "lay-down" trailer 802
may comprise an upper
section above the trailer axles and a lower section below the trailer axles.
In one embodiment, the
electric blender 806 and associated equipment on the trailer may be controlled
and monitored
remotely via a control system network. As shown in FIGS. 8A and 8B, a blender
control system 804
that comprises a PLC, transformers and one or more variable frequency drives
are mounted on upper
section of the blender transport 800. To provide remote control and monitoring
functions, the
29
Date Recue/Date Received 2021-06-24
network may interface and communicate with the PLC (e.g., provide operating
instructions), and the
PLC may subsequently control one or more variable frequency drives mounted on
the blender trailer
to drive one or more electric motors of the blender. Operating the blender
transport 800 remotely
may eliminate equipment operators from being exposed to hazardous environment
and avoiding
potential exposure concentrated chemicals, silica dust, and rotating
machinery. For example, a
conventional blender transport typically includes a station for an operator to
manually operate the
blender. By remotely controlling using the control network and blender control
system 804, the
station may be removed from the blender transport 800. Recall that a data van
may act as a hub to
provide the remote control and monitoring functions and instructions to the
blender control system
804.
[00100] FIGS. 9A and 9B are schematic diagrams of an embodiment of a blender
transport 900
that includes an electric blender 902 with enclosed mixer hoppers 904. FIG. 9A
illustrates a top-
down view of the blender transport 900 and FIG. 9B illustrates a side-profile
view of the blender
transport 900. The electric blender 902 is substantially similar to the
electric blender 806 except that
the electric blender 902 uses enclosed mixer hoppers 904 to add proppants and
additives to the
blending tub. FIGS. 9A and 9B illustrate that the electric blender 902 is a
dual configuration blender
that includes two enclosed mixer hoppers 904 powered by two electric motors,
where each of the
electric motors may operate an enclosed mixer hopper 904.
[00101]
Blenders that comprises open hoppers and augers typically have the proppants
(e.g.,
sand) and/or additives exposed to the weather elements. In situations where
precipitation occurs at
the well site, operators may cover the open hoppers and augers with drapes,
tarps, and/or other
coverings to prevent the precipitation from contaminating the proppants and/or
additives. The
enclosed mixer hopper 904 replaces the open hopper and augers typically
included in a blender (e.g.,
electric blender 806 in FIGS. 8A and 8B) with enclosed mixer hoppers 904
(FIGS. 9A and 9B). By
replacing the open hopper and augers with enclosed mixer hoppers 904 the
blender transport 900
may have the advantages of dust free volumetric proppant measurement, dust
free mixing of
proppant and additives, moderate the transport of proppants, perform accurate
volumetric
measurements, increase proppant transport efficiency with low slip, prevent
proppant packing from
vibration, produce a consistent volume independent of angle of repose, and
meter and blend wet
sand. Other advantages include the removal of gearboxes and increasing safety
for operators with
the enclosed drum.
Date Recue/Date Received 2021-06-24
[00102] Control Network System
[00103] FIG. 10 is a schematic diagram of an embodiment of a control network
system 1000 used
to monitor, control, and communicate with a variety of control systems located
at one or more well
sites. FIG. 10 illustrates that the control network system 1000 may be in a
ring-topology that
interconnects the control center 1002, blender transports 1004, chemical
additive unit 1006,
hydration unit 1008, and fracturing pump transports 1012. A ring topology
network may reduce the
amount of control cabling used for fracturing operations and increase the
capacity and speed of data
transfers and communication. Additionally, the ring topology may allow for two
way
communication and control by the control center 1002 for equipment connected
to the control
network system 1000. For example, the control center may be able to monitor
and control the other
fracturing equipment 1010 and third party equipment 1014 when added to the
control network
system 1000, and for multiple pieces of equipment to communicate with each
other. In other network
topologies, such as a star or mesh topology, the other fracturing equipment
1010 and third party
equipment 1014 may be limited to one way communication where data is
transmitted from the
fracturing equipment 1010 and/or third party equipment 1014 to the control
center 1002, but not vice
versa or between different pieces of equipment.
[00104] In one embodiment, the control network system 1000 may be a network,
such as an
Ethernet network that connects and communications with the individual control
systems for each of
the fracturing equipment. The control center 1002 may be configured to
monitor, control, and
provide operating instructions to the different fracturing equipment. For
example, the control center
1002 may communicate with the VFDs located within the drive power transports
104 that operate
and monitor the health of the electric motors used to drive the pumps on the
fracturing pump
transports 108. In one embodiment, the control center 1002 may be one or more
data vans. More
data vans may be used when the fracturing operations include fracturing more
than two wellheads
simultaneously.
[00105] At least one embodiment is disclosed and variations, combinations,
and/or
modifications of the embodiment(s) and/or features of the embodiment(s) made
by a person having
ordinary skill in the art are within the scope of the disclosure. Alternative
embodiments that result
from combining, integrating, and/or omitting features of the embodiment(s) are
also within the
scope of the disclosure. Where numerical ranges or limitations are expressly
stated, such express
ranges or limitations may be understood to include iterative ranges or
limitations of like magnitude
31
Date Recue/Date Received 2021-06-24
falling within the expressly stated ranges or limitations (e.g., from about 1
to about 10 includes, 2,
3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). The use of the
term "about" means
10% of the subsequent number, unless otherwise stated.
[00106] Use of the term "optionally" with respect to any element of a claim
means that the
element is required, or alternatively, the element is not required, both
alternatives being within the
scope of the claim. Use of broader terms such as comprises, includes, and
having may be
understood to provide support for narrower terms such as consisting of,
consisting essentially of,
and comprised substantially of Accordingly, the scope of protection is not
limited by the
description set out above but is defined by the claims that follow, that scope
including all
equivalents of the subject matter of the claims. Each and every claim is
incorporated as further
disclosure into the specification and the claims are embodiment(s) of the
present disclosure.
[00107] While several embodiments have been provided in the present
disclosure, it should be
understood that the disclosed systems and methods might be embodied in many
other specific forms
without departing from the spirit or scope of the present disclosure. The
present examples are to be
considered as illustrative and not restrictive, and the intention is not to be
limited to the details given
herein. For example, the various elements or components may be combined or
integrated in another
system or certain features may be omitted, or not implemented.
[00108] In
addition, techniques, systems, subsystems, and methods described and
illustrated in
the various embodiments as discrete or separate may be combined or integrated
with other systems,
modules, techniques, or methods without departing from the scope of the
present disclosure. Other
items shown or discussed as coupled or directly coupled or communicating with
each other may be
indirectly coupled or communicating through some interface, device, or
intermediate component
whether electrically, mechanically, or otherwise.
32
Date Recue/Date Received 2021-06-24
