Note: Descriptions are shown in the official language in which they were submitted.
POWER MONITORING SYSTEMS AND METHODS
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This paragraph has intentionally been deleted.
BACKGROUND
[0002] Power is generated, transmitted, and distributed to a plurality of
endpoints,
such as for example, customer or consumer premises (hereinafter referred to as
"consumer
premises"). Consumer premises may include multiple-family residences (e.g.,
apartment
buildings, retirement homes), single-family residences, office buildings,
event complexes
(e.g., coliseums or multi-purpose indoor arenas, hotels, sports complexes),
shopping
complexes, or any other type of building or area to which power is delivered.
[0003] The power delivered to the consumer premises is typically
generated at a
power station. A power station is any type of facility that generates power by
converting
mechanical power of a generator into electrical power. Energy to operate the
generator
may be derived from a number of different types of energy sources, including
fossil fuels
(e.g., coal, oil, natural gas), nuclear, solar, wind, wave, or hydroelectric.
Further, the power
station typically generates alternating current (AC) power.
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[0004] The AC power generated at the power station is typically increased
(the
voltage is "stepped up") and transmitted via transmission lines typically to
one or more
transmission substations. The transmission substations are interconnected with
a plurality
of distribution substations to which the transmission substations transmit the
AC power.
The distribution substations typically decrease the voltage of the AC power
received (the
voltage is "stepped down") and transmit the reduced voltage AC power to
distribution
transformers that are electrically connected to a plurality of consumer
premises. Thus, the
reduced voltage AC power is delivered to a plurality of consumer premises.
Such a web or
network of interconnected power components, transmission lines, and
distribution lines is
often times referred to as a power grid.
[0005] Throughout the power grid, measureable power is generated,
transmitted,
and distributed. In this regard, at particular midpoints or endpoints
throughout the grid,
measurements of power received and/or distributed may indicate information
related to
the power grid. For example, if power distributed at the endpoints on the grid
is
considerably less than the power received at, for example, distribution
transformers, then
there may be a system issue that is impeding delivery of power or power may be
being
diverted through malice. Such power data collection at any of the described
points in the
power grid and analysis of such data may further aid power suppliers in
generating,
transmitting, and distributing power to consumer premises.
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SUMMARY
[0006] The present disclosure is a system for monitoring power that has a
polyphase
distribution transformer monitoring (PDTM) device that interfaces with at
least three
electrical conductors electrically connected to a transformer. The PDTM device
further
measures a current and a voltage of each of the three electrical conductors.
The system
further has logic that calculates values indicative of power corresponding to
the transformer
based upon the current and the voltage measured and transmit data indicative
of the
calculated values.
BRIEF DESCRIPTION OF THE DRAWINGS
[0007] The present disclosure can be better understood with reference to
the
following drawings. The elements of the drawings are not necessarily to scale
relative to
each other, emphasis instead being placed upon clearly illustrating the
principles of the
disclosure. Furthermore, like reference numerals designate corresponding parts
throughout the several views.
[0008] FIG. 1 is a diagram depicting an exemplary power transmission and
distribution system in accordance with an embodiment of the present
disclosure.
[0009] FIG. 2A is a diagram depicting a transformer and meter power usage
data
collection system in accordance with an embodiment of the present disclosure.
[0010] FIG. 2B is a diagram depicting a line power usage data collection
system in
accordance with an embodiment of the present disclosure.
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[0011] FIG. 3 is a drawing of a general purpose transformer monitoring
device, such
as is depicted by FIG. 2A.
[0012] FIG. 4 is a block diagram depicting an exemplary operations
computing
device, such as is depicted in FIG. 2A.
[0013] FIG. 5 is a block diagram depicting an exemplary transformer
monitoring
device, such as is depicted in FIG. 2A.
[0014] FIG. 6 is a drawing of a transformer can in accordance with an
embodiment
of the present disclosure.
[0015] FIG. 7 is a drawing showing a satellite unit of the transformer
monitoring
device depicted in FIG. 3 being installed on the transformer can depicted in
FIG. 6.
[0016] FIG. 8 is a drawing showing the satellite unit of the transformer
monitoring
device depicted in FIG. 3 installed on the transformer can depicted in FIG. 6.
[0017] FIG. 9 is a drawing showing a main unit of the transformer
monitoring device
depicted in FIG. 3 installed on the transformer can depicted in FIG. 6.
[0018] FIG. 10 is a drawing showing a main unit of the transformer
monitoring
device depicted in FIG. 8 installed on the transformer can depicted in FIG. 6.
[0019] FIG. 11 is a diagram depicting a method of monitoring power in
accordance
with the system such as is depicted in FIG. 1 for a wye transformer
configuration.
[0020] FIG. 12 is a diagram depicting a method of monitoring power in
accordance
with the system such as is depicted in FIG. 1 for a Delta transformer
configuration.
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[0021] FIG. 13 is a diagram depicting a method of monitoring power in
accordance
with the system such as is depicted in FIG. 1 for an Open Delta transformer
configuration.
[0022] FIG. 14 is depicts a polyphase distribution transformer monitoring
(PDTM)
device in accordance with an embodiment of the present disclosure.
[0023] FIG. 15A is block diagram depicting an exemplary PDTM device, such
as is
depicted in FIG. 14.
[0024] FIG. 15B is a block diagram depicting another exemplary PDTM
device, such
as is depicted in 14.
[0025] FIG. 16 is a diagram depicting a method of monitoring power with a
PDTM of
FIG. 14 in accordance with the system such as is depicted in FIG. 1 for a wye
transformer
configuration.
[0026] FIG. 17 is a diagram depicting a method of monitoring power with a
PDTM of
FIG. 14 in accordance with the system such as is depicted in FIG. 1 for a
Delta transformer
configuration.
[0027] FIG. 18 is a diagram depicting a method of monitoring power with a
PDTM of
FIG. 14 in accordance with the system such as is depicted in FIG. 1 for a
Delta transformer
configuration having a center-tapped leg.
[0028] FIG. 19 is a flowchart depicting exemplary architecture and
functionality of
the power transmission and distribution system such as is depicted in FIG. 1.
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[0029] FIG. 20 is a flowchart depicting exemplary architecture and
functionality of
monitoring the power transmission and distribution system such as is depicted
in FIG. 1
with a PDTM of FIG. 14.
DETAILED DESCRIPTION
[0030] FIG. 1 is a block diagram illustrating a power transmission and
distribution
system 100 for delivering electrical power to one or more consumer premises
106-111.
The one or more consumer premises 106-111 may be business consumer premises,
residential consumer premises, or any other type of consumer premise. A
consumer
premise is any structure or area to which power is delivered.
[0031] The power transmission and distribution system 100 comprises at
least one
transmission network 118, at least one distribution network 119, and the
consumer
premises 106-111 (described hereinabove) interconnected via a plurality of
power lines
101a-101j.
[0032] In this regard, the power transmission and distribution system 100
is an
electric "grid" for delivering electricity generated by a power station 10 to
the one or more
consumer premises 106-111 via the transmission network 118 and the
distribution
network 119.
[0033] Note that the power lines 101a and 101b are exemplary transmission
lines,
while power lines 101c, 101d, are exemplary distribution lines. In one
embodiment, the
transmission lines 101a and 101b transmit electricity at high voltage (110kV
or above) and
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often via overhead power lines. At distribution transformers, the AC power is
transmitted
over the distribution lines at lower voltage (e.g., 25kV or less). Note that
in such an
embodiment, the power transmission described uses three-phase alternating
current (AC).
However, other types of power and/or power transmission may be used in other
embodiments.
[0034] The transmission network 118 comprises one or more transmission
substation 102 (only one is shown for simplicity). The power station 10 is
electrically
coupled to the transmission substation 102 via the power lines 101a, and the
transmission
substation 102 is electrically connected to the distribution network 119 via
the power lines
101b. As described hereinabove, the power station 10 (transformers not shown
located at
the power station 10) increases the voltage of the power generated prior to
transmission
over the transmission lines 101a to the transmission substation 102. Note that
three wires
are shown making up the power lines 101a indicating that the power transmitted
to the
transmission substation 102 is three-phase AC power. However, other types of
power may
be transmitted in other embodiments.
[0035] In this regard, at the power station 10, electricity is generated,
and the
voltage level of the generated electricity is "stepped up," i.e., the voltage
of the generated
power is increased to high voltage (e.g., 110 kV or greater), to decrease the
amount of
losses that may occur during transmission of the generated electricity through
the
transmission network 118.
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[0036] Note that the transmission network 118 depicted in FIG. 1 comprises
only
two sets of transmission lines 101a and 101b (three lines each for three-phase
power
transmissions as indicated hereinabove) and one transmission substation 102.
The
configuration of FIG. 1 is merely an exemplary configuration. The transmission
network
118 may comprise additional transmission substations interconnected via a
plurality of
additional transmission lines. The configuration of the transmission network
118 may
depend upon the distance that the voltage-increased electricity may need to
travel to reach
the desired distribution network 119.
[0037] The distribution network 119 transmits electricity from the
transmission
network 118 to the consumer premises 106-111. In this regard, the distribution
network
119 comprises a distribution substation transformer 103 and one or more
distribution
transformers 104 and 121. Note that the configuration shown in FIG. 1
comprising the
distribution substation transformer 103 and two distribution transformers 104
and 121
and showing the distribution substation transformer 103 physically separated
from the
two distribution transformers 104 and 121 is an exemplary configuration. Other
configurations are possible in other embodiments.
[0038] As an example, the distribution substation transformer 103 and the
distribution transformer 104 may be housed or combined together in other
configurations
of the distribution network 119 (as well as distribution substation
transformer 103 and
distribution transformer 121). In addition, one or more transformers may be
used to
condition the electricity, i.e., transform the voltage of the electricity, to
an acceptable
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voltage level for delivery to the consumer premises 106-111. The distribution
substation
transformer 103 and the distribution transformer 104 may "step down," i.e.,
decrease the
voltage of the electricity received from the transmission network 118, before
the
distribution substation transformer 103 and the distribution transformers 104,
121
transmit the electricity to its intended destinations, e.g., the consumer
premises 106-111.
[0039] As described hereinabove, in operation the power station 10 is
electrically
coupled to the transmission substation 102 via the power lines 101a. The power
station 10
generates electricity and transmits the generated electricity via the power
lines 101a to the
transmission substation 102. Prior to transmission, the power station 10
increases the
voltage of the electricity so that it may be transmitted over greater
distances efficiently
without loss that affects the quality of the electricity delivered. As further
indicated
hereinabove, the voltage of the electricity may need to be increased in order
to minimize
energy losses as the electricity is being transmitted on the power lines 101b.
The
transmission substation 102 forwards the electricity to the distribution
substation
transformer 103 of the distribution network 119.
[0040] When the electricity is received, the distribution substation
transformer 103
decreases the voltage of the electricity to a range that is useable by the
distribution
transformers 104, 121. Likewise, the distribution transformers 104, 121 may
further
decrease the voltage of the electricity received to a range that is useable by
the respective
electrical systems (not shown) of the consumer premises 106-111.
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[0041] In one embodiment of the present disclosure, the distribution
transformers
104, 121 are electrically coupled to a distribution transformer data
collection system 105.
The distribution transformer data collection system 105 of the present
disclosure comprises
one or more electrical devices (the number of devices may be determined based
upon the
number of transformers being monitored) (not shown) that measure operational
data via
one or more electrical interfaces with the distribution transformers 104, 121.
Exemplary
operational data includes data related to electricity that is being delivered
to or
transmitted from the distribution transformers 104, 121, e.g., power
measurements,
energy measurements, voltage measurements, current measurements, etc. In
addition, the
distribution transformer data collection system 105 may collect operational
data related to
the environment in which the distribution transformers 104, 121 are situated,
e.g.,
operating temperature of the distribution transformers 104, 121.
[0042] In accordance with one embodiment of the present disclosure, the
distribution transformer data collection system 105 electrically interfaces
with power lines
101e-101j (e.g., a set of three power lines delivering power to consumer
premises 106-111,
if the power is three-phase). Thus, the distribution transformer data
collection system 105
collects the data, which represents the amount of electricity (i.e., power
being used) that is
being delivered to the consumer premises 106-111. In another embodiment, the
distribution transformer data collection system 105 may electrically interface
with the
power lines 101c-101d (i.e., the power lines delivering receiving power from
the
transmission network 118).
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[0043] Furthermore, each consumer premise 106-111 comprises an electrical
system (not shown) for delivering electricity received from the distribution
transformers
104, 121 to one or more electrical ports (not shown) of the consumer premise
106-111.
Note that the electrical ports may be internal or external ports.
[0044] The electrical system of each consumer premise 106-111 interfaces
with a
corresponding consumer premise's electrical meter 112-117, respectively. Each
electrical
meter 112-117 measures the amount of electricity consumed by the consumer
premises'
electrical system to which it is coupled. In order to charge a customer who is
responsible
for the consumer premise, a power company (e.g., a utility company or a
metering
company) retrieves data indicative of the measurements made by the electrical
meters
112-117 and uses such measurements to determine the consumer's invoice dollar
amount
representative of how much electricity has been consumed at the consumer
premise 106-
111. Notably, readings taken from the meters 112-117 reflect the actual amount
of power
consumed by the respective consumer premise electrical system. Thus, in one
embodiment
of the present disclosure, the meters 112-117 store data indicative of the
power consumed
by the consumers.
[0045] During operation, the meters 112-117 may be queried using any
number of
methods in order to retrieve and store data indicative of the amount of power
being
consumed by the meter's respective consumer premise electrical system. In this
regard,
utility personnel may physically go to the consumer premises 106-111 and read
the consumer
premise's respective meter 112-117. In such a scenario, the personnel may
enter data
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indicative of the readings into an electronic system, e.g., a hand-held
device, a personal
computer (PC), or a laptop computer. Periodically, the data entered may be
transmitted to an
analysis repository. Additionally, meter data retrieval may be electronic and
automated. For
example, the meters 112-117 may be communicatively coupled to a network (not
shown), e.g.,
a wireless network, and periodically the meters 112-117 may automatically
transmit data to a
repository, described herein with reference to FIG. 2A.
[0046] As will be described further herein, meter data (not shown) (i.e.,
data indicative
of readings taken by the meters 112-117) and transformer data (not shown)
(i.e., data
indicative of readings taken by the transformer monitoring data collection
system 105) may
be stored, compared, and analyzed in order to determine whether particular
events have
occurred, for example, whether electricity theft is occurring or has occurred
between the
distribution transformers 104, 121 and the consumer premises 106-111 or to
determine
whether power usage trends indicate a need or necessity for additional power
supply
equipment. In this regard, with respect to the theft analysis, if the amount
of electricity being
received at the distribution transformers 104, 121 is much greater than the
cumulative (or
aggregate) total of the electricity that is being delivered to the consumer
premises 106-117,
then there is a possibility that an offender may be stealing electricity from
the utility providing
the power.
[0047] In another embodiment, power usage data is compiled over time. The
compilation of the power usage data may be used in a number of different ways.
For example,
it may be predetermined that a particular power usage signature, e.g., power
usage which can
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be illustrated as a graphed footprint over a period of time, indicates
nefarious activity. Such is
described further herein.
[0048] In one embodiment, the power transmission and distribution system
100
further comprises a line data collection system (LDCS) 290. The LDCS 290
collects line data
from the transmission lines 101b-101d. The line data is data indicative of
power/electricity measured. Such data may be compared, for example, to meter
data
(collected at consumer premises 106-111 described further herein) and/or the
transformer data (collected at the distribution transformers 104, 121
described further
herein) in order to determine losses of electricity along the power grid,
electricity usage,
power need, or power consumption metrics of the power grid. In one embodiment,
data
collected may be used to determine whether electricity theft is occurring or
has occurred
between a transmission substation and a distribution substation or a
distribution
substation and a distribution transformer (i.e., the distribution transformer
that transmits
power to the consumer premise). Note that the LDCS 290 is coupled to the
transmission
lines 101b, 101c, and 101d, respectively, thus coupling to medium voltage (MV)
power
lines. The LDCS 290 measures and collects operational data, as described
hereinabove. In
one embodiment, the LDCS may transmit operational data, such as, for example,
power,
energy, voltage, and/or current, related to the MV power lines 101b, 101c, and
101d.
[0049] FIG. 2A depicts the transformer data collection system 105 in
accordance with
an embodiment of the present disclosure and a plurality of meter data
collection devices 986-
991. The transformer data collection system 105 comprises one or more
transformer
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monitoring devices 243, 244 (FIG. 1). Note that only two transformer
monitoring devices 243,
244 are shown in FIG. 2A but additional transformer monitoring devices may be
used in other
embodiments, one or a plurality transformer monitoring devices for each
distribution
transformer 104, 121 (FIG. 1) being monitored, which is described in more
detail herein.
[0050] Notably, in one embodiment of the present disclosure, the
transformer
monitoring devices 243, 244 are coupled to secondary side of the distribution
transformers,
104, 121 respectively. Thus, measurements taken by the transformer monitoring
devices
243, 244 are taken, in effect, at the distribution transformers 104, 121
between the
distribution transformers 243, 244 and the consumer premises 106-111 (FIG. 1).
[0051] Additionally, the transformer monitoring devices 243, 244, the
meter data
collection devices 986-991, and an operations computing device 287 may
communicate via a
network 280. The network 280 may be any type of network over which devices may
transmit
data, including, but not limited to, a wireless network, a wide area network,
a large area
network, or any type of network known in the art or future-developed.
[0052] In another embodiment, the meter data 935-940 and the transformer
data 240,
241, may be transmitted via a direct connection to the operations computing
device 287 or
manually transferred to the operations computing device 287. As an example,
the meter data
collection devices 986-991 may be directly connected to the operations
computing device 287
via a direction connection, such as for example a T-carrier 1 (Ti) line. Also,
the meter data
935-940 may be collected on by a portable electronic device (not shown) that
is then
connected to the operations computing device 287 for transfer of the meter
data collected to
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the operations computing device 287. In addition, meter data 935-940 may be
collected
manually through visual inspection by utility personnel and provided to the
operations
computing device 287 in a particular format, e.g., comma separated values
(CSV).
[0053] Note that in other embodiments of the present disclosure, the meter
data
collection devices 986-991 may be the meters 112-117 (FIG. 1) themselves, and
the meters
112-117 may be equipped with network communication equipment (not shown) and
logic
(not shown) configured to retrieve readings, store readings, and transmit
readings taken by
the meters 112-117 to the operations computing device 287.
[0054] The transformer monitoring devices 243, 244 are electrically
coupled to the
distribution transformers 104, 121, respectively. In one embodiment, the
devices 243, 244
are electrically coupled to the distribution transformers 104, 121,
respectively, on a
secondary side of the distribution transformers 104, 121.
[0055] The transformer monitoring devices 243, 244 each comprise one or
more
sensors (not shown) that interface with one or more power lines (not shown)
connecting the
distribution transformers 104, 121 to the consumer premises 106-111 (FIG. 1).
Thus, the one
or more sensors of the transformer monitoring devices 243, 244 senses
electrical
characteristics, e.g., voltage and/or current, present in the power lines as
power is delivered
to the consumer premises 106-111 through the power lines 101e-101f.
Periodically, the
transformer monitoring devices 243, 244 sense such electrical characteristics,
translate the
sensed characteristics into transformer data 240, 241 indicative of electrical
characteristics,
such as, for example power, and transmit transformer data 240, 241 to the
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computing device 287 via the network 280. Upon receipt, the operations
computing device
287 stores the transformer data 240, 241 received.
[0056] Note that there is a transformer monitoring device depicted for
each
distribution transformer in the exemplary system, i.e., transformer monitoring
device 243 for
monitoring transformer 104 (FIG. 1) and transformer monitoring device 244 for
monitoring
transformer 121 (FIG. 1). There may be additional transformer monitoring
devices for
monitoring additional transformers in other embodiments.
[0057] The meter data collection devices 986-991 are communicatively
coupled to the
network 280. During operation, each meter data collection device 986-991
senses electrical
characteristics of the electricity, e.g., voltage and/or current, that is
transmitted by the
distribution transformers 104, 121. Each meter data collection device 986-991
translates the
sensed characteristics into meter data 935-940, respectively. The meter data
935-940 is data
indicative of electrical characteristics, such as, for example power consumed
in addition to
specific voltage and/or current measurements. Further, each meter data
collection device
986-991 transmits the meter data 935-940, respectively, to the operations
computing device
287 via the network 280. Upon receipt, the operations computing device 287
stores the
meter data 935-940 received from the meter data collection devices 986-991
indexed (or
keyed) with a unique identifier corresponding to the meter data collection
device 986-991
that transmits the meter data 935-940.
[0058] In one embodiment, each meter data collection device 986-991 may
comprise
Automatic Meter Reading (AMR) technology, i.e., logic (not shown) and/or
hardware, or
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Automatic Metering Infrastructure (AMI) technology, e.g., logic (not shown)
and/or hardware
for collecting and transmitting data to a central repository, (or more central
repositories,) e.g.,
the operations computing device 287.
[0059] In such an embodiment, the AMR technology and/or AMI technology of
each
device 986-991 collects data indicative of electricity consumption by its
respective consumer
premise power system and various other diagnostics information. The meter
logic of each
meter data collection device 986-991 transmits the data to the operations
computing device
287 via the network 280, as described hereinabove. Note that the AMR
technology
implementation may include hardware such as, for example, handheld devices,
mobile
devices and network devices based on telephony platforms (wired and wireless),
radio
frequency (RF), or power line communications (PLC).
[0060] Upon receipt, the operations computing device 287 compares
aggregate meter
data of those meters corresponding to a single transformer with the
transformer data 240,
241 received from the transformer that provided the transformer data 240, 241.
[0061] Thus, assume that meter data collection devices 986-988 are coupled
to meters
112-114 (FIG. 1) and transmit meter data 935-937, respectively, and
distribution transformer
104 is coupled to transformer monitoring device 243. In such a scenario, the
meters 112-114
meter electricity provided by the distribution transformer 104 and consumed by
the electrical
system of the respective consumer premise 106-108. Therefore, the operations
computing
device 287 aggregates (e.g., sums) data contained in meter data 935-937 (e.g.,
power usage
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recorded by each meter 112-114) and compares the aggregate with the
transformer data 240
provided by transformer monitoring device 243.
[0062] If the operations computing device 287 determines that the quantity
of power
that is being delivered to the consumer premises 106-108 connected to the
distribution
transformer 104 is substantially less than the quantity of power that is being
transmitted to
the distribution transformer 104, the operations computing device 287 may
determine that
power (or electricity) theft is occurring between the distribution transformer
104 and the
consumer premises 106-108 to which the distribution transformer 104, is
connected.
[0063] In one embodiment, the operations computing device 287 may store
data
indicating theft of electricity. In another embodiment, the operations
computing device 287
may be monitored by a user (not shown), and the operations computing device
287 may
initiate a visual or audible warning that power (or electricity) theft is
occurring. This process
is described further herein.
[0064] In one embodiment, the operations computing device 287 identifies,
stores, and
analyzes meter data 935-940 based on a particular unique identifier associated
with the
meter 112-117 to which the meter data collection devices 986-991 are coupled.
Further, the
operations computing device 287 identifies, stores, and analyzes transformer
data 240, 241
based on a unique identifier associated with the distribution transformers
104, 121 that
transmitted the transformer data 240, 241 to the operations computing device
287.
[0065] Thus, in one embodiment, prior to transmitting data to the
operations
computing device 287, both the meter data collection devices 986-991 and the
transformer
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monitoring devices 243, 244 are populated internally with a unique identifier
(i.e., a unique
identifier identifying the meter data collection device 986-991 and a unique
identifier
identifying the transformer monitoring device 243, 244). Further, each meter
data collection
device 986-991 may be populated with the unique identifier of the transformer
104, 121 to
which the meter data collection device 986-991 is connected.
[0066] In such an embodiment, when the meter data collection device 986-
991
transmits the meter data 935-940 to the operations computing device 287, the
operations
computing device 287 can determine which distribution transformer 104 or 121
services the
particular consumer premises 106-111. As an example, during setup of a portion
of the grid
(i.e., power transmission and distribution system 100) that comprises the
distribution
transformers 104, 121 and the meters 112-117, the operations computing device
287 may
receive set up data from the distribution transformers 104, 121 and the meter
data collection
devices 986-991 identifying the device from which it was sent and a unique
identifier
identifying the component to which the meter data collection device 986-990 is
connected.
[0067] FIG. 2B depicts the line data collection system 290 in accordance
with an
embodiment of the present disclosure. The line data collection system 290
comprises a
plurality of line monitoring devices 270-272 and the operations computing
device 287. Each
line monitoring device 270-272 communicates with the operations computing
device 287 via
the network 280.
[0068] With reference to FIG. 1, the line monitoring devices 270-272 are
electrically
coupled to the transmission lines 101b, 101c, and 101d, respectively. In one
embodiment,
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each line monitoring device 270-272 comprises one or more sensors (not shown)
that
interface with the transmission lines 101b, 101c, and 101d connecting the
transmission
substation 102 downstream to the distribution substation transformer 103 or
connecting the
distribution substation transformer103 downstream to the distribution
transformers 104,
121.
[0069] The one or more sensors of the line monitoring devices 270-272 sense
electrical characteristics, e.g., voltage and/or current, present as current
flows through
transmission lines 101b, 101c, and 101d, respectively. Periodically, each line
monitoring
device 270-272 senses such electrical characteristics, translates the sensed
characteristics
into line data 273-275, respectively, indicative of such characteristics, and
transmits the line
data 273-275 to the operations computing device 287 via the network 280. Upon
receipt, the
operations computing device 287 stores the line data 273-275 received from the
line
monitoring devices 270-272.
[0070] FIG. 3 depicts an embodiment of a general purpose transformer
monitoring
device 1000 that may be used as the transformer monitoring devices 243, 244
depicted in FIG.
2A and/or line monitoring devices 270-272 (FIG. 2B). The transformer
monitoring device
1000 may be installed on conductor cables (not shown) and used to collect data
indicative of
voltage and/or current from the conductor cables to which it is coupled.
[0071] The general purpose transformer monitoring device 1000 comprises a
satellite
unit 1021 that is electrically coupled to a main unit 1001. In one embodiment,
the satellite
unit 1021 is coupled via a cable 1011. However, the satellite unit 1021 may be
coupled other
ways in other embodiments, e.g., wirelessly. The general purpose transformer
monitoring
device 1000 may be used in a number of different methods in order to collect
voltage and/or
current data (i.e., transformer data 240, 241 (FIG. 2A) from the distribution
transformers 104,
121 (FIG. 1) and from the power lines 101b-101j,
[0072] In order to collect voltage and/or current data, the satellite
unit 1021 and/or
the main unit 1001 is installed around a conductor cable or connectors of
conductor cables
(also known as a "bushing").
[0073] In this regard, the satellite unit 1021 of the general purpose
transformer
monitoring device 1000 comprises two sections 1088 and 1089 that are hingally
coupled at
hinge 1040. When installed and in a closed position (as shown in FIG. 3), the
sections 1088
and 1089 connect together via a latch 1006 and the conductor cable runs
through an opening
1019 formed by coupling the sections 1088 and 1089.
[0074] The satellite unit 1021 further comprises a sensing unit housing
1005 that
houses a current detection device (not shown) for sensing current flowing
through the
conductor cable around which the sections 1088 and 1089 are installed, In one
embodiment,
the current detection device comprises an implementation ofone or more
coreless current
sensor as described in U.S. Patent No. 7,940,039.
[0075] The main unit 1001 comprises sections 1016 and 1017 that are
hingedly
coupled at hinge 1015. When installed and in a closed position (as shown in
FIG. 3), the
sections 1016 and 1017 connect together via a latch 1002 and a conductor cable
runs through
an opening 1020 formed by coupling the sections 1016 and 1017,
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[0076] The main unit 1001 comprises a sensing unit housing section 1018
that houses
a current detection device (not shown) for sensing current flowing through the
conductor
cable around which the sections 1016 and 1017 are installed. As described
hereinabove with
respect to the satellite unit 1021, the current detection device comprises an
implementation
of one or more Ragowski coils as described in U.S. Patent No. 7,940,039.
[0077] Unlike the satellite unit 1021, the main unit section 1017
comprises an
extended boxlike housing section 1012. Within the housing section 1012 resides
one or more
printed circuit boards (PCB) (not shown), semiconductor chips (not shown),
and/or other
electronics (not shown) for performing operations related to the general
purpose transformer
monitoring device 1000. In one embodiment, the housing section 1012 is a
substantially
rectangular housing; however, differently sized and differently shaped
housings may be used
in other embodiments.
[0078] Additionally, the main unit 1001 further comprises one or more
cables 1004,
1007. The cables 1004, 1007 may be coupled to a conductor cable or
corresponding bus bars
(not shown) and ground or reference voltage conductor (not shown),
respectively, for the
corresponding conductor cable, which will be described further herein,
[00791 Note that methods in accordance with an embodiment of the present
disclosure
use the described monitoring device 1000 for collecting current and/or voltage
data. Further
note that the monitoring device 1000 described is portable and easily
connected and/or
coupled to an electrical conductor and/or transformer posts. Due to the
noninvasive method
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of installing the satellite unit and main unit around a conductor and
connecting the leads
1004, 1007 to connection points, an operator (or utility personnel) need not
de-energize a
transformer 104, 121 for connection or coupling thereto. Further, no piercing
(or other
invasive technique) of the electrical line is needed during deployment to the
power grid.
Thus, the monitoring device 1000 is easy to install. Thus, deployment to the
power grid is
easy to effectuate.
[0080] During operation, the satellite unit 1021 and/or the main unit 1001
collects
data indicative of current through a conductor cable. The satellite unit 1021
transmits its
collected data via the cable 1011 to the main unit 1001. Additionally, the
cables 1004, 1007
may be used to collect data indicative of voltage corresponding to a conductor
cable about
which the satellite unit is installed. The data indicative of the current and
voltage sensed
corresponding to the conductor may be used to calculate power usage.
[0081] As indicated hereinabove, there are a number of different methods
that may be
employed using the general purpose monitoring device 1000 in order to collect
current
and/or voltage data and calculate power usage.
[0082] In one embodiment, the general purpose transformer monitoring
device 1000
may be used to collect voltage and current data from a three phase system (if
multiple general
purpose transformer monitoring devices 100 are used) or a single phase system.
[0083] With respect to a single phase system, the single phase system has
two
conductor cables and a neutral cable. For example, electricity supplied to a
typical home in
the United States has two conductor cables (or hot cables) and a neutral
cable. Note that the
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voltage across the conductor cables in such an example is 240 Volts (the total
voltage
supplied) and the voltage across one of the conductor cables and the neutral
is 120 Volts.
Such an example is typically viewed as a single phase system.
[0084] In a three phase system, there are typically three conductor cables
and a
neutral cable (sometimes there may not be a neutral cable). In one system,
voltage measured
in each conductor cable is 120 out of phase from the voltage in the other two
conductor
cables. Multiple general purpose transformer monitoring devices 1000 can
obtain current
readings from each conductor cable and voltage readings between each of the
conductor
cables and the neutral (or obtain voltage readings between each of the
conductor cables).
Such readings may then be used to calculate power usage.
[0085] Note that the main unit 1001 of the general purpose transformer
monitoring
device 1000 further comprises one or more light emitting diodes (LEDs) 1003.
The LEDs may
be used by logic (not shown but referred to herein with reference to FIG. 4 as
analytic logic
308) to indicate status, operations, or other functions performed by the
general purpose
transformer monitoring device 1000.
[0086] FIG. 4 depicts an exemplary embodiment of the operations computing
device
287 depicted in FIG. 2A. As shown by FIG. 4, the operations computing device
287 comprises
analytic logic 308, meter data 390, transformer data 391, line data 392, and
configuration data
312 all stored in memory 300.
[0087] The analytics logic 308 generally controls the functionality of the
operations
computing device 287, as will be described in more detail hereafter. It should
be noted that
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the analytics logic 308 can be implemented in software, hardware, firmware or
any
combination thereof. In an exemplary embodiment illustrated in FIG. 4, the
analytics logic
308 is implemented in software and stored in memory 300.
[0088] Note that the analytics logic 308, when implemented in software,
can be stored
and transported on any computer-readable medium for use by or in connection
with an
instruction execution apparatus that can fetch and execute instructions. In
the context of
this document, a "computer-readable medium" can be any means that can contain
or store
a computer program for use by or in connection with an instruction execution
apparatus.
[0089] The exemplary embodiment of the operations computing device 287
depicted
by FIG. 4 comprises at least one conventional processing element 302, such as
a digital signal
processor (DSP) or a central processing unit (CPU), that communicates to and
drives the other
elements within the operations computing device 287 via a local interface 301,
which can
include at least one bus. Further, the processing element 302 is configured to
execute
instructions of software, such as the analytics logic 308.
[0090] An input interface 303, for example, a keyboard, keypad, or mouse,
can be used
to input data from a user of the operations computing device 287, and an
output interface
304, for example, a printer or display screen (e.g., a liquid crystal display
(LCD)), can be used
to output data to the user. In addition, a network interface 305, such as a
modem, enables the
operations computing device 287 to communicate via the network 280 (FIG. 2A)
to other
devices in communication with the network 280.
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[0091] As
indicated hereinabove, the meter data 390, the transformer data 391, the
line data 392, and the configuration data 312 are stored in memory 300. The
meter data 390
is data indicative of power usage measurements and/or other electrical
characteristics
obtained from each of the meters 112-117 (FIG. 1). In this regard, the meter
data 390 is an
aggregate representation of the meter data 935-940 (FIG. 2A) received from the
meter data
collection devices 986-991 (FIG. 2A).
[0092] In one
embodiment, the analytics logic 308 receives the meter data 935-940
and stores the meter data 935-940 (as meter data 390) such that the meter data
935-940 may
be retrieved based upon the transformer 104 or 121 (FIG. 1) to which the meter
data's
corresponding meter 112-117 is coupled. Note that meter data 390 is dynamic
and is
collected periodically by the meter data collection devices 986-991 from the
meters 112-117.
For example, the meter data 390 may include, but is not limited to, data
indicative of current
measurements, voltage measurements, and/or power calculations over a period of
time per
meter 112-117 and/or per transformer 104 or 121. The analytic logic 308 may
use the
collected meter data 390 to determine whether the amount of electricity
supplied by the
corresponding transformer 104 or 121 is substantially equal to the electricity
that is received
at the consumer premises 106-111.
[0093] In one
embodiment, each entry of the meter data 935-940 in the meter data
390 is associated with an identifier (not shown) identifying the meter 112-117
(FIG. 1) from
which the meter data 935-940 is collected. Such identifier may be randomly
generated at the
meter 112-117 via logic (not shown) executed on the meter 112-117.
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[0094] In such a scenario, data indicative of the identifier generated by
the logic at the
meter 112-117 may be communicated, or otherwise transmitted, to the
transformer
monitoring device 243 or 244 to which the meter is coupled. Thus, when the
transformer
monitoring devices 243, 244 transmit transformer data 240, 241, each
transformer
monitoring device 243, 244 can also transmit its unique meter identifier
(and/or the unique
identifier of the meter that sent the transformer monitoring device 243, 244
the meter data).
Upon receipt, the analytics logic 308 may store the received transformer data
240, 241 (as
transformer data 391) and the unique identifier of the transformer monitoring
device 243,
244 and/or the meter unique identifier such that the transformer data 391 may
be searched
on the unique identifiers when performing calculations. In addition, the
analytics logic 308
may store the unique identifiers of the transformer monitoring devices 243,
244
corresponding to the unique identifiers of the meters 112-117 from which the
corresponding
transformer monitoring devices 243, 244 receive meter data. Thus, the
analytics logic 308
can use the configuration data 312 when performing operations, such as
aggregating
particular meter data entries in meter data 390 to compare to transformer data
391.
[0095] The transformer data 391 is data indicative of aggregated power
usage
measurements obtained from the distribution transformers 104, 121. Such data
is dynamic
and is collected periodically. Note that the transformer data 240, 241
comprises data
indicative of current measurements, voltage measurements, and/or power
calculations over a
period of time that indicates the amount of aggregate power provided to the
consumer
premises 106-111. Notably, the transformer data 391 comprises data indicative
of the
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aggregate power that is being sent to a "group," i.e., two or more consumer
premises being
monitored by the transformer monitoring devices 243, 244, although the
transformer data
391 can comprise power data that is being sent to only one consumer premises
being
monitoried by the transformer monitoring device.
[0096] In one embodiment, during setup of a distribution network 119 (FIG.
1), the
analytic logic 308 may receive data identifying the unique identifier for one
or more
transformers 104, 121. In addition, when a transformer monitoring device 243,
244 is
installed and electrically coupled to one or more transformers 104, 121, data
indicative of the
unique identifier of the transformers 104, 121 may be provided to the meters
112-117 and/or
to the operations computing device 287, as described hereinabove. The
operations
computing device 287 may store the unique identifiers (i.e., the unique
identifier for the
transformers) in configuration data 312 such that each meter 112-117 is
correlated in
memory with a unique identifier identifying the distribution transformer from
which the
consumer premises 106-111 associated with the meter 112-117 receives power.
[0097] The line data 273-275 is data indicative of power usage
measurements
obtained from the line data collection system 290 along transmission lines
101b-101d in the
system 100. Such data is dynamic and is collected periodically. Note that the
line data 273-
274 comprises data indicative of current measurements, voltage measurements,
and/or
power calculations over a period of time that indicates the amount of
aggregate power
provided to the distribution substation transformer 103 and the distribution
transformers
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104, 121. Notably, the line data 392 comprises data indicative of the
aggregate power that is
being sent to a "group," i.e., one or more distribution substation
transformers 103.
[0098] During operation, the analytic logic 308 receives meter data 935-
940 via the
network interface 305 from the network 280 (FIG. 2) and stores the meter data
935-940 as
meter data 390 in memory 300. The meter data 390 is stored such that it may be
retrieved
corresponding to the distribution transformer 104, 121 supplying the consumer
premise 106-
111 to which the meter data corresponds. Note there are various methods that
may be
employed for storing such data including using unique identifiers, as
described hereinabove,
or configuration data 312, also described hereinabove.
[0099] The analytic logic 308 may perform a variety of functions to
further analyze the
power transmission and distribution system 100 (FIG. 1). As an example, and as
discussed
hereinabove, the analytic logic 308 may use the collected transformer data
391, line data 392,
and/or meter data 390 to determine whether electricity theft is occurring
along the
transmission lines 101a, 101b or the distribution lines 101c-101j. In this
regard, the analytic
logic 308 may compare the aggregate power consumed by the group of consumer
premises
(e.g., consumer premises 106-108 or 109-111) and compare the calculated
aggregate with the
actual power supplied by the corresponding distribution transformer 104 or
121. In addition,
the analytic logic 308 may compare the power transmitted to the distribution
substation
transformer 103 and the aggregate power received by the distribution
transformers 104, 121,
or the analytic logic 308 may compare the power transmitted to the
transmission substation
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102 and the aggregate power received by one or more distribution substation
transformers
103.
[00100] If comparisons indicate that electricity theft is occurring
anywhere in the
power and distribution system 100, the analytics logic 308 may notify a user
of the
operations computing device 287 that there may be a problem. In addition, the
analytics logic
308 can pinpoint a location in the power transmission and distribution system
100 where
theft may be occurring. In this regard, the analytic logic 308 may have a
visual or audible alert
to the user, which can include a map of the system 100 and a visual identifier
locating the
problem.
[00101] As indicated hereinabove, the analytics logic 308 may perform a
variety of
operations and analysis based upon the data received. As an example, the
analytic logic 308
may perform a system capacity contribution analysis. In this regard, the
analytic logic 308
may determine when one or more of the consumer premises 106-111 have
coincident peak
power usage (and/or requirements). The analytics logic 308 determines, based
upon this
data, priorities associated with the plurality of consumer premises 106-111,
e.g. what
consumer premises requires a particular peak load and at what time. Loads
required by the
consumer premises 106-111 may necessarily affect system capacity charges;
thus, the priority
may be used to determine which consumer premises 106-111 may benefit from
demand
management.
[00102] Additionally, the analytic logic 308 may use the meter data 390
(FIG. 4), the
transformer data 391, the line data 392, and the configuration data 312
(collectively referred
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to as "operations computing device data") to determine asset loading. For
example, analyses
may be performed for substation and feeder loading, transformer loading,
feeder section
loading, line section loading, and cable loading. Also, the operations
computing device data
may be used to produce detailed voltage calculations and analysis of the
system 100 and/or
technical loss calculations for the components of the system 100, and to
compare voltages
experienced at each distribution transformer with the distribution transformer
manufacturer
minimum/maximum voltage ratings and identify such distribution transformer(s)
which are
operating outside of the manufacturer's suggested voltages range thereby
helping to isolate
power sag and power swell instances, and identify distribution transformer
sizing and
longevity information.
[00103] In one embodiment, a utility company may install load control
devices (not
shown). In such an embodiment, the analytics logic 308 may use the operations
computing
device data to identify one or more locations of load control devices.
[00104] FIG. 5 depicts an exemplary embodiment of the transformer
monitoring device
1000 depicted in FIG. 3. As shown by FIG. 5, the transformer monitoring device
1000
comprises control logic 2003, voltage data 2001, current data 2002, and power
data 2020
stored in memory 2000.
[00105] The control logic 2003 controls the functionality of the operations
transformer
monitoring device 1000, as will be described in more detail hereafter. It
should be noted that
the control logic 2003 can be implemented in software, hardware, firmware or
any
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combination thereof. In an exemplary embodiment illustrated in FIG. 5, the
control logic
2003 is implemented in software and stored in memory 2000.
[00106] Note that the control logic 2003, when implemented in software, can
be stored
and transported on any computer-readable medium for use by or in connection
with an
instruction execution apparatus that can fetch and execute instructions. In
the context of
this document, a "computer-readable medium" can be any means that can contain
or store
a computer program for use by or in connection with an instruction execution
apparatus.
[00107] The exemplary embodiment of the transformer monitoring device 1000
depicted by FIG. 5 comprises at least one conventional processing element
2004, such as a
digital signal processor (DSP) or a central processing unit (CPU), that
communicates to and
drives the other elements within the transformer monitoring device 1000 via a
local interface
2005, which can include at least one bus. Further, the processing element 2004
is configured
to execute instructions of software, such as the control logic 2003.
[00108] An input interface 2006, for example, a keyboard, keypad, or mouse,
can be
used to input data from a user of the transformer monitoring device 1000, and
an output
interface 2007, for example, a printer or display screen (e.g., a liquid
crystal display (LCD)),
can be used to output data to the user. In addition, a network interface 2008,
such as a
modem or wireless transceiver, enables the transformer monitoring device 1000
to
communicate with the network 280 (FIG. 2A).
[00109] In one embodiment, the transformer monitoring device 1000 further
comprises
a communication interface 2050. The communication interface 2050 is any type
of interface
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that when accessed enables power data 2020, voltage data 2001, current data
2002, or any
other data collected or calculated by the transformer monitoring device 100 to
be
communicated to another system or device. As an example, the communication
interface may
be a serial bus interface that enables a device that communicates serially to
retrieve the
identified data from the transformer monitoring device 1000. As another
example, the
communication interface 2050 may be a universal serial bus (USB) that enables
a device
configured for USB communication to retrieve the identified data from the
transformer
monitoring device 1000. Other communication interfaces 2050 may use other
methods
and/or devices for communication including radio frequency (RF) communication,
cellular
communication, power line communication, and WiFi communications. The
transformer
monitoring device 1000 further comprises one or more voltage data collection
devices 2009
and one or more current data collection devices 2010. In this regard, with
respect to the
transformer monitoring device 1000 depicted in FIG. 3, the transformer
monitoring device
1000 comprises the voltage data collection device 2009 that may include the
cables 1004,
1007 (FIG. 3) that sense voltages at nodes (not shown) on a transformer to
which the cables
are attached. As will be described further herein, the control logic 2003
receives data via the
cables 1004, 1007 indicative of the voltages at the nodes and stores the data
as voltage data
2001. The control logic 2003 performs operations on and with the voltage data
2001,
including periodically transmitting the voltage data 2001 to, for example, the
operations
computing device 287 (FIG. 2A).
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[00110] Further, with respect to the transformer monitoring device 1000
depicted in
FIG. 3, the transformer monitoring device 1000 comprises the current sensors
(not shown)
contained in the sensing unit housing 1005 (FIG. 3) and the sensing unit
housing section 1018
(FIG. 3), which are described hereinabove. The current sensors sense current
traveling
through conductor cables (or neutral cables) around which the sensing unit
housings 1005,
1018 are coupled. As will be described further herein, the control logic 2003
receives data
indicative of current from the satellite sensing unit 1021 (FIG. 3) via the
cable 1011 and data
indicative of the current from the current sensor of the main unit 1001
contained in the
sensing unit housing section 1018. The control logic 2003 stores the data
indicative of the
currents sensed as the current data 2002. The control logic 2003 performs
operations on and
with the current data 2002, including periodically transmitting the voltage
data 2001 to, for
example, the operations computing device 287 (FIG. 2A).
[00111] Note that the control logic 2003 may perform calculations with the
voltage data
2001 and the current data 2002 prior to transmitting the voltage data 2001 and
the current
data 2002 to the operations computing device 287. In this regard, for example,
the control
logic 2003 may calculate power usage using the voltage data 2001 and current
data 2002 over
time and periodically store resulting values as power data 2020.
[00112] During operations, the control logic 2003 may transmit data to the
operations
computing device 287 via the cables via a power line communication (PLC)
method. In other
embodiments, the control logic 2003 may transmit the data via the network 280
(FIG. 2A)
wirelessly or otherwise.
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[00113] FIGS. 6-10 depict one exemplary practical application, use, and
operation of the
transformer monitoring device 1000 shown in the drawing in FIG. 3. In this
regard, FIG. 6 is a
transformer can 1022, which houses a transformer (not shown), mounted on a
utility pole
1036. One or more cables 1024-1026 carry current from the transformer can 1022
to a
destination (not shown), e.g., consumer premises 106-111 (FIG. 1). The cables
1024-1026 are
connected to the transformer can at nodes 1064-1066. Each node 1064-1066
comprises a
conductive connector (part of which is sometimes referred to as a bus bar).
[00114] FIG. 7 depicts the satellite unit 1021 of the transformer
monitoring device 1000
being placed on one of the nodes 1064-1066 (FIG. 6), i.e., in an open
position. A technician
(not shown), e.g., an employee of a utility company (not shown), decouples the
latch 1006
(FIG. 3), made up by decoupled sections 1006a and 1006b, and places the
sections 1088 and
1089 around a portion of the node 1064-1066 such that the sensor unit (not
shown)
interfaces with the node and senses a current flowing through the node. FIG. 8
depicts the
satellite unit 1021 of the transformer monitoring device 1000 latched around
the node 1064-
1066 in a closed position.
[00115] FIG. 9 depicts the main unit 1001 of the transformer monitoring
device 1000
being placed on one of the nodes 1064-1066, i.e., in an open position. The
technician
decouples the latch 1002, made up by decoupled sections 1002a and 1002b, and
places the
sections 1016 and 1017 around a portion of the node 1064-1066 such that the
sensor unit
(not shown) interfaces with the node and senses a current flowing through the
node. FIG. 10
is a drawing of the transformer monitoring device 1000 latched around the node
1064-1066.
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FIG. 10 depicts the main unit 1001 of the transformer monitoring device 1000
latched around
the node 1064-1066 and in a closed position.
[00116] In one embodiment, the cables 1004, 1007 (FIG. 3) of the main unit
1001 may
be connected to one of the nodes 1064-1066 about which the respective
satellite unit 1021 is
coupled and one of the nodes 1064-1066 about which the main unit 1001 is
coupled. In this
regard, as described hereinabove, the cable 1004 comprises a plurality of
separate and
distinct cables. One cable is connected to the node about which the satellite
unit 1021 is
coupled, and one cable is connected to the node about which the main unit 1001
is coupled.
[00117] During operation, the current detection device contained in the
sensing unit
housings 1005, 1018 (FIG. 3) sense current from the respective nodes to which
they are
coupled. Further, the connections made by the cables 1004, 1007 to the nodes
and reference
conductor sense the voltage at the respective nodes, i.e., the node around
which the main unit
is coupled and the node around which the satellite unit is coupled.
[00118] In one embodiment, the analytic logic 308 receives current data
for each node
and voltage data from each node based upon the current sensors and the voltage
connections.
The analytics logic 308 uses the collected data to calculate power over a
period of time, which
the analytic logic 308 transmits to the operations computing device 287 (FIG.
2A). In another
embodiment, the analytic logic 308 may transmit the voltage data and the
current data
directly to the operations computing device 287 without performing any
calculations.
[00119] FIGS. 11-13 further illustrate methods that may be employed using
the
monitoring device 1000 FIG. 3 in a system 100 (FIG. 1). As described
hereinabove, the
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monitoring device 1000 may be coupled to a conductor cable (not shown) or a
bushing (not
shown) that attaches the conductor cable to a transformer can 1022 (FIG. 6).
In operation, the
transformer monitoring device 1000 obtains a current and voltage reading
associated with
the conductor cable to which it is coupled, as described hereinabove, and the
main unit 1001
(FIG. 3) uses the current reading and the voltage reading to calculate power
usage.
[00120] Note for purposes of the discussion hereinafter, a transformer
monitoring
device 1000 (FIG. 3) comprises two current sensing devices, including one
contained in
housing 1005 (FIG. 3) and one contained in the housing 1018 (FIG. 3) of the
satellite unit 1021
(FIG. 3) and the main unit 1001 (FIG. 3), respectively.
[00121] FIG. 11 is a diagram depicting a distribution transformer 1200 for
distributing
three-phase power, which is indicative of a "wye" configuration. In this
regard, three-phase
power comprises three conductors providing AC power such that the AC voltage
waveform
on each conductor is 120 apart relative to each other, where 360 is
approximately one
sixtieth of a second. As described hereinabove, three-phase power is
transmitted on three
conductor cables and is delivered to distribution substation transformer 103
(FIG. 1) and
distribution transformer 104 (FIG. 1) on three conductor cables. Thus, the
receiving
distribution transformer 104 has three winding pairs (one for each phase input
voltage
received) to transform the voltage of the power received to a level of voltage
needed for
delivery to the consumers 106-108 (FIG. 1).
[00122] In the distribution transformer 1200, three single-phase
transformers 1201-
1203 are connected to a common (neutral) lead 1204. For purposes of
illustration, each
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transformer connection is identified as a phase, e.g., Phase A/transformer
1201, Phase B/
transformer 1202, and Phase C/ transformer 1203.
[00123] In the embodiment depicted in FIG. 11, three monitoring devices
1000a,
1000b, and 1000c (each configured substantially similar to monitoring device
1000 (FIG.
3)) are employed to obtain data (e.g., voltage and current data) used to
calculate the power
at the distribution transformer 1200.
[00124] In this regard, at least one of current sensing devices 1217 of
monitoring
device 1000a is used to collect current data for Phase A. Notably, the sensing
device 1217
of the monitoring device 1000a used to collect current data may be housed in
the satellite
unit 1021 (FIG. 3) or the main unit 1001 (FIG. 3). The voltage lead 1004a of
the monitoring
device 1000a is connected across the Phase A conductor cable and common 1204
in order
to obtain voltage data. Note that in one embodiment both current sensing
devices in the
satellite unit 1021 and the main unit 1001 (current sensing device 1217) may
be coupled
around the Phase A conductor cable.
[00125] Further, a current sensing device 1218 of monitoring device 1000b
is used to
collect current data for Phase B. As described above with reference to Phase
A, the sensing
device 1218 of the monitoring device 1000b used to collect current data may be
housed in
the satellite unit 1021 (FIG. 3) or the main unit 1001 (FIG. 3). The voltage
lead 1004b of
the monitoring device 1000b is connected across the Phase B conductor cable
and common
1204 in order to obtain voltage data. Similar to the Phase A implementation
described
above, in one embodiment both current sensing device in the satellite unit
1021 and the
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main unit 1001 (current sensing device 1218) may be coupled around the Phase B
conductor cable.
[00126] Additionally, a current sensing device 1219 of monitoring device
1000c is
used to collect voltage and current data for Phase C. As described above with
reference to
Phase A, the sensing device 1219 of the monitoring device 1000c that is used
to collect
current data may be housed in the satellite unit 1021 (FIG. 3) or the main
unit 1001 (FIG.
3). The voltage lead 1004c of the monitoring device 1000c is connected across
the Phase C
conductor cable and common 1204 in order to obtain voltage data. Similar to
the Phase A
implementation described above, in one embodiment both current sensing devices
in the
satellite unit 1021 and the main unit 1001 (current sensing device 1219) may
be coupled
around the Phase C conductor cable.
[00127] During monitoring, control logic 2003 (FIG. 5) of the monitoring
devices
1000a-1000c use current measurements and voltage measurements to calculate
total
power. As described hereinabove, the power calculated from the measurements
made by the
transformer monitoring devices 1000a, 1000b, and 1000c may be used in various
applications to provide information related to the power transmission and
distribution
system 100 (FIG. 1).
[00128] FIG. 12 is a diagram depicting a distribution transformer 1300 for
distributing
three-phase power, which is indicative of a delta configuration. Such
distribution transformer
1300 may be used as the distribution transformer 104 (FIG. 1). The
distribution transformer
1300 (similar to the distribution transformer 1200 (FIG. 11)) has three single
phase
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transformers to transform the voltage of the power received on three conductor
cables (i.e.,
three-phase power) to a level of voltage needed for delivery to the consumers
106-108 (FIG.
1).
[00129] The distribution transformer 1300 comprises three single-phase
transformers 1301-1303. For purposes of illustration, each transformer
connection is
identified as a phase, e.g., Phase A/transformer 1301-transformer 1303, Phase
B/
transformer 1302-transformer 1301, and Phase C/ transformer 1303-transformer
1302.
[00130] In the embodiment depicted in FIG. 12, two transformer monitoring
devices
1000d and 1000e are employed to obtain voltage and current data, which are
used to
calculate power at the distribution transformer 1300. In this regard,
transformer
monitoring device 1000d is coupled about one of three incoming conductor
cables,
identified in FIG. 12 as Phase B, and transformer monitoring device 1000e is
coupled about
another one of the three incoming conductor cables, identified in FIG. 12 as
Phase C. The
monitoring devices 1000d and 1000e (each configured substantially similar to
monitoring
device 1000 (FIG. 3)) are employed to obtain data (e.g., voltage and current
data) used to
calculate the power at the distribution transformer 1300.
[00131] In this regard, a current sensing device 1318 of monitoring device
1000d is
used to collect current data for Phase B. Notably, the sensing device 1318 of
the
monitoring device 1000d used to collect current data may be housed in the
satellite unit
1021 (FIG. 3) or the main unit 1001 (FIG. 3). The voltage leads 1004d of the
monitoring
device 1000d are connected across the Phase B conductor cable and the Phase A
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cable which measures a voltage differential. Note that in one embodiment both
current
sensing devices in the satellite unit 1021 and the main unit 1001 (current
sensing device
1318) may be coupled around the Phase B conductor cable. Further note that in
the delta
configuration, Phase A may be arbitrarily designated as a "common" such that
power may
be calculated based on the voltage differentials between the current-sensed
conductor
cables and the designated "common," which in the present embodiment is Phase
A.
[00132] Further, similar to Phase B measurements, a current sensing device
1319 of
monitoring device 1000e is used to collect current data for Phase C. As
described above
with reference to Phase B, the sensing device 1319 of the monitoring device
1000e used to
collect current data may be housed in the satellite unit 1021 (FIG. 3) or the
main unit 1001
(FIG. 3). The voltage leads 1004e of the monitoring device 1000e are connected
across the
Phase C conductor cable and Phase A conductor cable. Notably, in one
embodiment both
current sensing devices in the satellite unit 1021 and the main unit 1001
(current sensing
device 1319) may be coupled around the Phase C conductor cable.
[00133] During monitoring, control logic 2003 (FIG. 5) of the monitoring
devices
1000d and 1000e use current measurements and voltage measurements to calculate
total
power. As described hereinabove, the power calculated from the measurements
made by the
transformer monitoring devices 1000f and 1000g may be used in various
applications to
provide information related to the power transmission and distribution system
100 (FIG. 1).
[00134] FIG. 13 is a diagram depicting a distribution transformer 1400 for
distributing
power, which is indicative of an open delta configuration. The distribution
transformer 1400
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has two single phase transformers to transform the voltage received to a level
of voltage
needed for delivery to the consumers 106-108 (FIG. 1).
[00135] The distribution transformer 1400 comprises two single-phase
transformers
1401-1402. In the embodiment depicted in FIG. 13, two transformer monitoring
devices
1000f and 1000g are employed to obtain voltage and current data, which are
used to
calculate power at the distribution transformer 1400.
[00136] Transformer monitoring device 1000f is coupled about one of three
conductor cables identified in FIG. 13 as Phase A and transformer monitoring
device 1000g
is coupled about another one of the conductor cables identified in FIG. 13 as
Phase B. The
monitoring devices 1000f and 1000g (each configured substantially similar to
monitoring
device 1000 (FIG. 3)) are employed to obtain data (e.g., voltage and current
data) used to
calculate the power at the distribution transformer 1400.
[00137] In this regard, at least one of the current sensing devices 1418 or
1419 of
monitoring device 1000f is used to collect voltage and current data for Phase
A. While both
sensing devices are shown coupled about Phase A, both are not necessarily
needed in other
embodiments. Notably, a sensing device of the monitoring device 1000f used to
collect
current data may be housed in the satellite unit 1021 (FIG. 3) or the main
unit 1001 (FIG.
3). The voltage leads 1004f of the monitoring device 1000f are connected
across the Phase
A conductor cable and ground. Note that in one embodiment both current sensing
devices
in the satellite unit 1021 and the main unit 1001 may be coupled around the
Phase A
conductor cable, as shown.
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[00138] Further, current sensing device 1420 housed in the main unit 1001
(FIG. 3)
of monitoring device 1000g and current sensing device 1421 housed in the
satellite unit
1021 (FIG. 3) of monitoring device 1000g is used to collect current data for
Phase B. The
voltage lead 1004g of the monitoring device 1000g is connected across the
voltage outputs
of the secondary of transformer 1402.
[00139] During monitoring, control logic 2003 (FIG. 5) of the transformer
monitoring
devices 1000f and 1000g uses current measurements and voltage measurements to
calculate total power. As described hereinabove, the power calculated from the
measurements made by the transformer monitoring devices 1000f and 1000g may be
used in
various applications to provide information related to the power transmission
and
distribution system 100 (FIG. 1).
[00140] FIG. 14 depicts an exemplary polyphase distribution transformer
monitor
(PDTM) 1499 in accordance with an embodiment of the present disclosure. For
purposes
of this disclosure, in one embodiment, polyphase refers to a system for
distributing
alternating current electrical power and has three or more electrical
conductors wherein
each carries alternating currents having time offsets one from the others.
Note that while
the PDTM 1499 is configured to monitor up to four conductors (not shown), the
PDTM may
be used to monitor one or more conductors, e.g., single phase or two-phase
power, which is
substantially similar to monitoring three-phase power, which is described
further herein.
[00141] Notably, with reference to FIG. 2A, the PDTM 1499 may serve the
purpose
and functionality and is a type of transformer monitoring device 244, 243
(FIG. 2A). Thus,
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the PDTM collects power and electrical characteristic data related to a
particular
distribution transformer 104, 121 (FIG. 1).
[00142] The PDTM 1499 comprises a control box 1498, which is a housing that
conceals a plurality of electronic components, discussed further herein, that
control the
PDTM 1499. Additionally, the PDTM comprises a plurality of satellite current
sensors
1490-1493.
[00143] The satellite current sensors 1490-1493 are structurally and
functionally
substantially similar to the satellite unit 1021 described with reference to
FIGS. 3, 7, and 8.
In this regard, the satellite current sensors 1490-1493 detect a current
through an
electrical cable, bus bar, or any other type of node through which current
passes into
and/or from a distribution transformer, such as the distribution transformer
shown in FIG.
6.
[00144] Further, the satellite current sensors 1490-1493 are electrically
connected to
the control box 1498 (and to the electronics (not shown) contained therein).
In this regard,
the satellite current sensor 1490 may be electrically connected via connectors
1464, 1460
on the satellite current sensor 1490 and the control box 1498, respectively,
by a voltage
current cable 1480. Similarly, the satellite current sensor 1491 is
electrically connected via
connectors 1465, 1461 on the satellite current sensor 1491 and the control box
1498,
respectively, by a voltage current cable 1481, the satellite current sensor
1492 is
electrically connected via connectors 1466, 1462 on the satellite current
sensor 1492 and
the control box 1498, respectively, by a voltage current cable 1482, and the
satellite
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current sensor 1493 is electrically connected via connectors 1467, 1463 on the
satellite
current sensor 1493 and the control box 1498, respectively, by a voltage
current cable
1483.
[00145] Note that the current cables 1480-1483 may be an American National
Standards Institute (ANSI) -type cable. In this regard, the current cables
1480-1483 may
be either insulated or non-insulated. The current cables 1480-1483 may be any
other type
of cable known in the art or future-developed from transferring data
indicative of current
measurements made by the satellite current sensors 1490-1493 to the control
box 1498.
[00146]
[00147] In addition, each current cable 1480-1483 is further associated and
electrically correlated with a voltage cable 1484-1487. In this regard, each
voltage cable
1484 extends from the connectors 1460-1463 on the control box 1498 and
terminates with
ring terminals 1476-1479, respectively.
[00148] Note that in one embodiment of the PDTM 1499, connectors 1460-1463
may
be unnecessary. In this regard, the conductors 1480-1483 and conductors 1484-
1487 may
be connected to electronics directly without use of the connectors 1460-1463.
[00149] During operation, one or more of the satellite current sensors 1490-
1493 are
installed about conductors (e.g., cables), bus bars, or other type of node
through which
current travels. In addition, each of the ring terminals 1476-1479,
respectively, are
coupled to the conductor, bus bar, or other type of node around which their
respective
satellite current sensor 1490-1493 is installed.
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[00150] More specifically, each satellite current sensor 1490-1493 takes
current
measurements over time of current that is flowing through the conductor cable,
bus bar, or
node around which it is installed. Also, over time, voltage measurements are
sensed via
each of the satellite current sensors' respective voltage cables 1484-1487. As
will be
described herein, the current measurements and voltage measurements taken over
time
are correlated and thus used in order to determine power usage corresponding
to the
particular conductor cable, bus bar, or particular node.
[00151] FIG.15A depicts an exemplary embodiment of a controller 1500 that
is housed
within the control box 1498. As shown by FIG. 15A, the controller 1500
comprises control
logic 1503, voltage data 1501, current data 1502, and power data 1520 stored
in memory
1522.
[00152] The control logic 1503 controls the functionality of the
controller 1500, as will
be described in more detail hereafter. It should be noted that the control
logic 1503 can be
implemented in software, hardware, firmware or any combination thereof. In an
exemplary
embodiment illustrated in FIG. 15, the control logic 1503 is implemented in
software and
stored in memory 1522.
[00153] Note that the control logic 1503, when implemented in software,
can be stored
and transported on any computer-readable medium for use by or in connection
with an
instruction execution apparatus that can fetch and execute instructions. In
the context of
this document, a "computer-readable medium" can be any means that can contain
or store
a computer program for use by or in connection with an instruction execution
apparatus.
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[00154] The exemplary embodiment of the controller 1500 depicted by FIG. 15
comprises at least one conventional processing element 1504, such as a digital
signal
processor (DSP) or a central processing unit (CPU), that communicates to and
drives the other
elements within the controller 1500 via a local interface 1505, which can
include at least one
bus. Further, the processing element 1504 is configured to execute
instructions of software,
such as the control logic 1503.
[00155] In addition, a network interface 1561, such as a modem or wireless
transceiver,
enables the controller 1500 to communicate with the network 280 (FIG. 2A).
[00156] In one embodiment, the controller 1500 further comprises a
communication
interface 1560. The communication interface 1560 is any type of interface that
when
accessed enables power data 1520, voltage data 1501, current data 1502, or any
other data
collected or calculated by the controller 1500 to be communicated to another
system or
device.
[00157] As an example, the communication interface 1560 may be a serial bus
interface
that enables a device that communicates serially to retrieve the identified
data from the
controller 1500. As another example, the communication interface 1560 may be a
universal
serial bus (USB) that enables a device configured for USB communication to
retrieve the
identified data from the controller 1500. Other communication interfaces may
use other
methods and/or devices for communication including radio frequency (RF)
communication,
cellular communication, power line communication, and Wi-Fi communications.
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[00158] The controller 1500 further comprises one or more current cable
interfaces
1550-1553 and voltage cable interfaces 1554-1557 that receive data transmitted
via the
current cables 1480-1483 and voltage cables 1484-1487, respectively. In this
regard, each
current cable interface/voltage cable interface pair is associated with a
single connector. For
example, connector 1460 receives cables 1480 (current) and 1484 (voltage), and
the current
cable interface 1550 receives data indicative of current and the voltage cable
interface 1554
receives data indicative of current associated with the conductor about which
the satellite
current sensor 1490 is installed.
[00159] Similarly, connector 1461receives cables 1481(current) and
1485(voltage),
and the current cable interface 1551 receives data indicative of current and
the voltage cable
interface 1555 receives data indicative of current associated with the
conductor about which
the satellite current sensor 1491 is installed. The connector 1462receives
cables
1482(current) and 1486(voltage), and the current cable interface 1552 receives
data
indicative of current and the voltage cable interface 1556 receives data
indicative of current
associated with the conductor about which the satellite current sensor 1492 is
installed.
Finally, connector 1463receives cables 1483(current) and 1487(voltage), and
the current
cable interface 1553 receives data indicative of current and the voltage cable
interface 1557
receives data indicative of current associated with the conductor about which
the satellite
current sensor 1493 is installed.
[00160] During operation, the control logic 1503 receives the voltage and
current data
from the interfaces 1550-1557 and stores the current data as current data 1502
and the
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voltage data as voltage data 1501. The control logic 1503 performs operations
on and with
the voltage data 1501 and current data 1502, including periodically
transmitting the voltage
data 1501 and current data 1502 to, for example, the operations computing
device 287 (FIG.
2A).
[00161] Note that the control logic 1503 may perform calculations with the
voltage data
1501 and the current data 1502 prior to transmitting the voltage data 1501 and
the current
data 1502 to the operations computing device 287. In this regard, for example,
the control
logic 2003 may calculate power usage using the voltage data 1501 and current
data 1502 over
time and periodically store resulting values as power data 1520.
[00162] During operations, the control logic 1503 may transmit data to the
operations
computing device 287 via the cables using a power line communication (PLC)
method. In
other embodiments, the control logic 1503 may transmit the data via the
network 280 (FIG.
2A) wirelessly or otherwise.
[00163] FIG. 158 depicts another embodiment of an exemplary controller
1593 that
may be housed within the control box 1498 (FIG. 14). As shown by FIG. 15B, the
controller
1593 comprises control logic 1586, which behaves similarly to the control
logic 1503(FIG.
15A) shown and described with reference to FIG. 15A. However, in the
embodiment depicted
in FIG. 158, the control logic 1586 resides on a microprocessor 1585 that
communicates with
an internal bus 1584. The control logic 1586 may be software, hardware, or any
combination
thereof.
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[00164] In one embodiment, the control logic 1586 is software and is stored
in a
memory module (not shown) on the microprocessor 1585. In such an embodiment,
the
control logic 1586 may be designed and written on a separate computing device
(not
shown) and loaded into the memory module on the microprocessor 1585.
[00165] Additionally, the controller 1593 comprises a microprocessor 1578
and
FLASH memory 1579 that communicate with the microprocessor 1585 over the
internal
bus 1584. Further, the controller 1593 comprises an input/output interface
1583 and a
communication module 1587that each communicates with the microprocessor 1585
directly. Note that the interface 1583 and the communication module 1587 may
communicate with the microprocessor 1585 indirectly, e.g., vie the buses 1584
or 1585, in
other embodiments.
[00166] The microprocessor 1578 is electrically coupled to four current
sensors
1570-1573 and four voltage inputs 1574-1577. Note that with reference to FIG.
14, such
current sensors 1570-1573 and voltage inputs 1574-1577 correlate with
satellite units
1490-1493 and voltage leads 1476-1479, respectively.
[00167] While four current sensors 1570-1573 and respective voltage inputs
1574-
1577 are depicted in FIG. 15B, there can be additional or fewer current
sensors 1570-1573
and respective voltage inputs 1574-1577 used in other embodiments. In this
regard, the
controller 1593 may be used to gather information related to a single phase or
two-phase
power using device, e.g., a transformer, in other embodiments.
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[00168] Note that the communication module 1587 is any type of
communication
module known in the art or future-developed. The communication module 1587
receives
data from the microprocessor 1585 and transmits the received data to another
computing
device. For example, with reference to FIG. 2A, the communication module 1587
may be
communicatively coupled to the operations computing device 287 (FIG. 2A) and
transmit
the data 1594 and 1595 to the operations computing device 187. In one
embodiment, the
communication module 187 may be wirelessly coupled to the operations computing
device
287; however, other types of communication are possible in other embodiments.
[00169] The controller 1593 further has electronically erasable
programmable read-
only memory (EEPROM) 1589, a real-time clock 1590, and a temperature sensor
1591. The
EEPROM 1589, the clock 1590, and the sensor 1591 communicate with the
microprocessor
1585 via another internal bus 1588.
[00170] Note that as shown in the embodiment of the controller 1593, the
controller
1593 may comprise two separately accessible internal buses, e.g., buses 1584
and 1588.
I Iowever, additional or fewer internal buses are possible in other
embodiments.
[00171] During operation, the microprocessor 1578 receives signals
indicative of
current and voltage from current sensors 1570-1573 and voltage inputs 1574-
1577,
respectively. When received, the signals are analog signals. The
microprocessor 1578
receives the analog signals, conditions the analog signals, e.g., through
filtering, and converts
the analog signals indicative of current and voltage measurements into
transient current data
1594 and transient voltage data 1595. The microprocessor transmits the data
1594 and 1595
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to the microprocessor 1585, and the control logic 1586 stores the data 1594
and 1595 as
current data 1582 and voltage data 1581, respectively, in the FLASH memory
1579. Note that
while FLASH memory 1579 is shown, other types of memory may be used in other
embodiments.
[00172] The control logic 1586 may further compute power usage based upon
the data
1594 and 1595 received from the microprocessor 1578. In this regard, the
control logic may
store the power computations in the FLASH memory 1579 as power data 1580.
[00173] Further, during operation, the control logic 1586 may receive real-
time time
stamps associated with a subset of the digital data 1594 and 1595 received
from the
microprocessor 1578. In such an embodiment, in addition to data indicative of
the current
and voltage readings taken by the current sensors 1570-1573 and the voltage
inputs 1574-
1577, the control logic 1586 may also store associated with the current and
voltage data
indicative of the time that the reading of the associated current and/or
voltage was obtained.
Thus the FLASH memory 1579 may store historical data for a particular given
time period.
[00174] During operation, a user (not shown) may desire to load an updated
version
or modified version of the control logic 1586 onto the microprocessor 1585. In
this
scenario, the user may transmit data (not shown) indicative of a modified
version of the
control logic 1586 via the communication module 1587. Upon receipt by the
control logic
1586, the control logic 1586 may store data 1599 indicative of the modified
version in the
FLASH memory 1579. The microprocessor 1585 may then replace the control logic
1586 with
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the modified control logic data 1599 and continue operation executing the
modified control
logic data 1599.
[00175] The EEPROM 1589 stores configuration data 1592. The configuration
data
1592 is any type of data that may be used by the control logic 1586 during
operation. For
example, the configuration data 1592 may store data indicative of scale
factors for use in
calibration of the controller 1592, offset, or other calibration data. The
configuration data
1592 may be stored in the EEPROM 1589 at manufacturing. In other embodiments,
the
configuration data 1592 may be updated via the communication module 1587 or
the interface
1583, as described hereinafter.
[00176] Additionally, the input/output interface 1583 may be, for example,
an optical
port that connects to a computing device (not shown) or other terminal for
interrogation of
the controller 1593. In such an embodiment, logic (not shown) on the computing
device may
request data, e.g., power data 1580, voltage data 1581, current data 1582, or
configuration
data 1592, via the interface 1583, and in response, the control logic 1586 may
transmit data
indicative of the data 1580-1582 or 1592 via the interface 1583 to the
computing device.
[00177] Further, the temperature sensor 1592 collects data indicative of a
temperature
of the environment in which the sensor resides. For example, the temperature
sensor 1592
may obtain temperature measurements within the housing 1498 (FIG. 14). The
control logic
1586 receives data indicative of the temperature readings and stores the data
as temperature
data 1598 in FLASH memory 1579. As described hereinabove with reference to
time stamp
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data, the temperature data 1598 may also be correlated with particular voltage
data 1581
and/or current data 1582.
[00178] FIGS. 16-18 depict exemplary installations on differing types of
electrical
service connections for three-phase electric power installations. In this
regard, FIG. 16
depicts a four-wire grounded "Wye" installation 1600, FIG. 17 depicts a three-
wire Delta
installation 1700, and FIG. 18 depicts a four-wire tapped Delta neutral
grounded
installation 1800. Each of these is discussed separately in the contact of
installing and
operating a PDTM 1499 for the collection of voltage and current data for the
calculation of
power usage date on the secondary windings (shown per FIGS. 16-18) for each
type of
installation.
[00179] In particular, FIG. 16 is a diagram depicting a Wye installation
1600 (also
referred to as a "star" three-phase configuration. While the Wye installation
can be a three-
wire configuration, the installation 1600 is implemented as a four-wire
configuration. The
installation comprises the secondary windings of a transformer, which are
designated
generally as 1601. The installation comprises four conductors, including
conductors A, B,
C, and N (or neutral), where N is connected to ground 1602. In the
installation 1600, the
magnitudes of the voltages between each phase conductor (e.g., A, B, and C)
are equal.
However, the Wye configuration that includes a neutral also provides a second
voltage
magnitude, which is between each phase and neutral, e.g., 208/120V systems.
[00180] During operation, the PDTM 1499 (FIG. 14) is connected to the
installation
1600 as indicated. In this regard, satellite current sensor 1490 is coupled
about conductor
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A, and its corresponding voltage ring terminal 1476 is electrically coupled to
conductor A.
Thus, the control logic 1503 receives data indicative of voltage and current
measured from
conductor A and stores the corresponding data as voltage data 1501 and current
data 1502.
Similarly, satellite current sensor 1491 is coupled about conductor B, and its
corresponding
voltage ring terminal 1477 is electrically coupled to conductor Bõ satellite
current sensor
1492 is coupled about N (neutral), and its corresponding voltage ring terminal
1478 is
electrically coupled to N, and, satellite current sensor 1493 is coupled about
conductor C,
and its corresponding voltage ring terminal 1479 is electrically coupled to
conductor C.
Thus, over time the control logic 1503 receives and collects data indicative
of voltage and
current measured from each conductor and neutral and stores the corresponding
data as
voltage data 1501 and current data 1502. The control logic 1503 may then use
the
collected data to calculate power usage over the period of time for which
voltage and
current data is received and collected.
[00181] Further, FIG. 17 is a diagram depicting a Delta installation 1700.
The Delta
installation 1700 shown is a three-wire configuration. The connections made in
the Delta
configuration are across each of the three phases, or the three secondary
windings of the
transformer. The installation comprises the secondary windings of a
transformer, which
are designated generally as 1701. The installation comprises three conductors
(i.e., three-
wire), including conductors A, B, and C. In the installation 1700, the
magnitudes of the
voltages between each phase conductor (e.g., A, B, and C) are equal.
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[00182] During operation, the PDTM 1499 (FIG. 14) is connected to the
installation
1700 as indicated. In this regard, satellite current sensor 1490 is coupled
about conductor
A, and its corresponding voltage ring terminal 1476 is electrically coupled to
conductor A.
Thus, the control logic 1503 receives data indicative of voltage and current
measured from
conductor A and stores the corresponding data as voltage data 1501 and current
data 1502.
Similarly, satellite current sensor 1491 is coupled about conductor B, and its
corresponding
voltage ring terminal 1477 is electrically coupled to conductor B, and
satellite current
sensor 1492 is coupled about C, and its corresponding voltage ring terminal
1478 is
electrically coupled to C. In regards to the fourth satellite current sensor
1492, because the
installation 1700 is a three-wire set up, the fourth satellite current sensor
1493 is not
needed, and may therefore not be coupled to a conductor. Similar to the
installation 1600,
over time the control logic 1503 receives and collects data indicative of
voltage and current
measured from each conductor (A, B, and C) and stores the corresponding data
as voltage
data 1501 and current data 1502. The control logic 1503 may then use the
collected data
to calculate power usage over the period of time for which voltage and current
data is
received and collected.
[00183] FIG. 18 is a diagram depicting a Delta installation 1800 in which
one winding
is center-tapped to ground 1802, which is often times referred to as a "high-
leg Delta
configuration." The Delta installation 1800 shown is a four-wire
configuration. The
connections made in the Delta installation 1800 are across each of the three
phases and
neutral (or ground), or the three secondary windings of the transformer and
ground. The
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installation 1800 comprises the secondary windings of a transformer, which are
designated
generally as 1801. The installation comprises three conductors, including
conductors A, B,
and C and the center-tapped N (neural) wire. The installation 1800 shown is
not
symmetrical and produces three available voltages.
[00184] During operation, the PDTM 1499 (FIG. 14) is connected to the
installation
1800 as indicated. In this regard, satellite current sensor 1490 is coupled
about conductor
A, and its corresponding voltage ring terminal 1476 is electrically coupled to
conductor A.
Thus, the control logic 1503 receives data indicative of voltage and current
measured from
conductor A and stores the corresponding data as voltage data 1501 and current
data
1502. Similarly, satellite current sensor 1491 is coupled about conductor B,
and its
corresponding voltage ring terminal 1477 is electrically coupled to conductor
B, satellite
current sensor 1492 is coupled about N, and its corresponding voltage ring
terminal 1478
is electrically coupled to N, and satellite current sensor 1493 is coupled
about conductor C,
and its corresponding voltage ring terminal 1479 is electrically coupled to C.
Similar to the
installation 1600, over time the control logic 1503 receives and collects data
indicative of
voltage and current measured from each conductor (A, B, C, and N) and stores
the
corresponding data as voltage data 1501 and current data 1502. The control
logic 1503
may then use the collected data to calculate power usage over the period of
time for which
voltage and current data is received and collected.
[00185] FIG. 19 is a flowchart depicting exemplary architecture and
functionality of
the system 100 depicted in FIG. 1.
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[00186] In step 1900, electrically interfacing a first transformer
monitoring device
1000 (FIG. 3) to a first electrical conductor of a transformer at a first
location on a power grid,
and in step 1901 measuring a first current through the first electrical
conductor and a first
voltage associated with the first electrical conductor.
[00187] In step 1902, electrically interfacing a second transformer
monitoring device
1000 with a second electrical conductor electrically connected to the
transformer, and in step
1903 measuring a second current through the second electrical conductor and a
second
voltage associated with the second electrical conductor.
[00188] Finally, in step 1904, calculating values indicative of power
corresponding to
the transformer based upon the first current and the first voltage and the
second current and
the second voltage.
[00189] FIG. 20 is a flowchart depicting exemplary architecture and
functionality of
the system 100 depicted in FIG. 1 in regards to the PDTM 1499 (FIG. 14).
[00190] In step 5000, electrically interfacing a first current sensing
device and a first
voltage lead to a first electrical conductor of a three-phase transformer.
With reference to FIG.
17, one exemplary installation includes coupling satellite current sensor 1490
to conductor A
and ring terminal 1476 to the same conductor A, for example.
[00191] In step 5001 electrically interfacing a second current sensing
device and a
second voltage lead to a second electrical conductor of a three-phase
transformer. With
reference to FIG. 17, one exemplary installation includes coupling satellite
current sensor
1491 to conductor B and ring terminal 1477 to the same conductor B, for
example.
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[00192] In step 5002 electrically interfacing a third current sensing
device and a third
voltage lead to a third electrical conductor of a three-phase transformer.
With reference to
FIG. 17, one exemplary installation includes coupling satellite current sensor
1492 to
conductor C and ring terminal 1478 to the same conductor C, for example.
[00193] In step 5003, receiving data indicative of current and voltage
measurements
via the sensing devices and the voltage leads by a single processor. Notably,
the data is
collected over a period of time by the processor 1504 (FIG. 15) and stored in
memory 1522
(FIG. 15).
[00194] Finally, in step 5004, calculating values indicative of power
corresponding to
the transformer based upon the voltage and current data received and stored
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